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197-219
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 Xl~ Diskettes, No..~) Other, No/Type 'OVERSIZED ~~'~ .Logs of vadous kinds Other COMMENTS: Scanned by: Beverly Mildred D'aretha~Lowell Date.: ,.~ ~//I TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is~ ALASKA OIL AND GAS CONSERVATION COPlPlISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 28, 2000 Gary Carlson, Vice President Forcenergy Inc. 310 K Street, Suite 700 Anchorage, AK 99501 Dear Mr. Carlson: A recent review of our well history database indicates that the Coffee Creek # 1 well has been plugged and abandoned but has not received Commission approval of final "location clearance" as required by 20 AAC 25.170. The attached list indicates that the location condition is unknown. Please arrange for any necessary location clearance work to be done and contact Blair Wondzell at (907) 793-1226 within 30 days to arrange for Commission inspection of the location condition. S ~aniel T. Seamunt, Jr. Commissioner Attachment CC: Jim Arlington - Landman Blair Wondzell 7/07/2000 ALASKA WELLS LOCATION CLEARANCE STATUS PAGE 1. PERMIT 197-219 LOC CLEAR 3-COND-UNKNOWN API NUMBER 283-20094-00 WELL NAME COFFEE CREEK WELL STATUS P&A STATUS DATE 6/26/1998 TALLY OPER3~TOR FORCENERGY IN ~V~li Compliance Report File on Left side of folder 197-219-0 MD~09757 TVD~9664 _ COFFEE CREEK 1 _ 50- 283-20094-00 Completion Date: ~'~6/98 Completed Status: P&A FORCENERGY Current: Name Interval L BHCS c~AL 159-9726 Sent Received T/C/D OH 5/12/98 5/12/98 4/16/98 4/16/98 5/12/98 5/12/98 5,'12/9g L CBL t.-~AL BL 800-6664 5/'l."b/~ CH 5 L CET b,,F'INAL BL 800-6686 Z/'Z'I/~'~ CH 5 L DIPMETER ~IN~L 1224-6718 3 jl~/~ ~ OH L LDT/CN/GR ~L .159-9698 ~ [[~/~j ~/~/~ OH OH 2 ~' 90-9~ [~/~ ~ OH 2 ~AL 90-9757 ~ OH 2 ~L ,S9-9,00 3/~[~? OH ~AL 1224-6718 3/Ib/i~ OH ~L BL (C) 6750-9700 ~/O/~g OH 2 ~AL BL813-6630 317,[~g CH s ~' OH OH ~757 OH T 8397 ~ SCHLUM DITE/BHC&DT/CNL OH Daily Well Op~/3/~; ~/2('/~ Are Dry Ditch Samples Reauired~go Was the well cored? yes~_ Analysis D ~ ' . no L MUD L MUD L PIL-SFL L RFT L SHDT DIP L TEMP R DIR SRVY R DST 1,2,3,5 R FORMATION TOPS Comments: 4/16/98 4/16/98 5/12/98 5/12/98 5/!2/98 12/10/98 3/10/00 5/12/98 5/12/98 5/12/98 4/16/98 7/29/98 12/10/98 12/10/98 5/12/98 3/13/00 5/12/98 5/12/98 5/12/98 4/16/98 7/29/98 5/12/98 And Received? ye~_ Sample Set # Tuesday, May 30, 2000 Page 1 of 1 KB Top Tyonek Top Three Mile Sand Base Three Mile Sand Top Chickaloon Top Mesozoic Coffee Creek Well Tops 62O' MSL 700' MD 4,780' MD 6,630' MD 6,935' MD NR ~~. ,,.1 ..'" AO~CC Individual Well Page: 1 Geological Materials Inventory Date: 11/25/98 / PERMIT DATA T DATA PLUS RUN RECVD D .................... -- L~9-9698 FINAL ~BL (C) 6750-9700 .J~59-9726 ~159-9700 ~1224-6718 ~HLUM DITE/BHC/LDT/CNL ~"BL 813-6630 -~BL 800-6686 ~fBL 800-6664 ~.-6680. 97-219 ~ 05/12/98 97-219 LDT/CN/GR 05/12/98 97-219 SHDT DIP FINAL 05/12/98 97-219 BHCS FINAL 05/12/98 97-219 PIL-SFL FINAL 05/12/98 97-219 DIPMETER FINAL 05/12/98 97-219 RFT FINAL 05/12/98 97-219 8397 1,2 05/12/98 97-219 TEMP FINAL 04/16/98 97-219 CET FINAL 04/16/98 97-219 CBL FINAL 04/16/98 97-219 DIR SRVY - 07/29/98 Are dry ditch samples required? ~ no And received? yes no Was the well cored? yes ~.~lysis & description received? __~asl no~, Are well tests required~Received? yes no Well is in compliance Initial cOMMENTS 7 Forcenergy Inc July 24, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Well Completion Report and Log (Form 10-407) Coffee Creek #1 Enclosed is Forcenergy's Well Completion Report and Log for the Coffee Creek #1 exploration well. Included are form 10-407, well completion schematic, daily report summary and final directional survey. The well had four unsuccessful drill stem tests performed and was plugged and abandoned as per AOGCC regulations. If there are any questions, please contact me at 258-8600. Drilling Manager Forcenergy Inc. HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 Miami, Florida 33129-2237 TELEPHONE 305/856-8500 FAX 305/856-4300 REGIONAL OFFICE 310 K Street Suite 700 Anchorage, Alaska 99501 TELEPHONE 907/258-8600 FAX 907/258-8601 STATE OF ALASKA ALASKA OIL GAS CONSERVATION C MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED: ABANDONED: X SERVICE: 2. Name of Operator Forcenergy Inc. 7. Permit Number 97-219 3. Address 310 K Street, Suite 700 8. APl Number Anchorage, Alaska 99501 50-283-20094 4. Location of well at surface 9. Unit or Lease Name 527' FWL, 710' FSL Sec 19 T14N il0W,SM ~ '~; ~"~'r'~ ~'~7~ ~";" i~ Coffee Creek At Total Depth~ -~- ~r -~-~,~:: ,:' i. -.. ~'~¢~!~i' 10. Well Number 5003' FWL, 871' FSL Sec 24 114N R1 l W, SM i .~ !'~ #1 i~ i 11. Field and Pool ~.-;--~: .............. --~ ~ Wildcat 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 620 KBI C-061466 12. Date Spudded2/13/98 13' Date T'D' Reached I 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' ir °ffsh°re I 16' N°' °f C°mpleti°ns4/25/98 6/26/98 n/a feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9,757' MD / 9,664' TVD Surface Yes: x No: n/a feet MD n/a 22. Type Electric or Other Logs Run 12 1/4" hole: Quad Combo, SHDT, RFT, Check Shot Velocity Survey 9 5/8" casing: CBL, CET, Temperature Log, Gyrodata Survey 8 1/2" hole: Quad Combo, SHDT, RFT, Check Shot Velocity Survey 23. CASING, LINER AND CEMENTING RECORD SE-I-I-lNG DEPTH MD CASING SIZE W'I-. PER FT. GRADE TOP Be'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 133~ K-55 SuM. 90' driven n/a None 13 3/8" 68# L-80 SuM. 1,219' 17 1/2" 1554 cuft None 9 5/8" 47# L-80 SuM. 6,715' 12 1/4" 450 cu ft None 7 5/8" 29.7# L-80 6,638' 7,288' 8 1/2" 174 cu ft None 24. PeMorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4,140 to 4,142' MD 6.5 BBL 15.8 ppg Type "G" 4,400' to 4,402' MD 10 BBL 15.8 ppg Type "G" 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) U L I Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD => Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE => 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None P, ECE[ Form 10-407 JUL 2 91998 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORM~,TION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF A'FrACHMENTS Well Schematic, Final Directional Survey, Daily Operations Summary 32. I hereby c._ertify that the foregoing is true and correct to the best of my knowledge Signed ~'~N'"~ ~ Title DdllingManager Date 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 space 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 productin 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. Form 10-407 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". RECEIVED jUL 29 1998 Alaska 0i! & (~s Cons. Commission Anchorage Halliburton Energy Services e~ORCENERGY FFEE CREEK #1 WELL TEST REPORT HALLIBURTON The Future Is Working Together. Forcenergy Inc Alaska Division MEMORANDUM TO: FROM: DATE: Gary Carlson & Paul VVhite Richard V. Nelson, Jr. April 15, 1998 SUBJECT: ' Coffee CreekTests Dan Seamount and I met and agreed on the exact perforation intervals for the five tests that we and Unocal have been discussing. I have not heard back from Dan today as to any changes that Joel might want to make but I wanted to get these to you for planning purposes. The table lists the individual intervals that make up each test, the net footage of perforations for each, the gross interval for each and the total footage of perforations for all five tests. Richard V. Nelson, Jr. C:\Wl N DOWS\TE M P\CCTestln.doc Page1 of 1 Date Modified: 4/14/98 Date Prepared: 4/14/98 kg Test #1 Test #2 Test #3 Test Test #5 Base 6983 6929 6912 6896 6885 6876 6852 5930 5835 5821 4325 4285 3184 2665 2631 2548 2508 Total Shot Footage Top 6945 6924 6909 6891 6883 6862 6835 59O6 5831 5815 43O2 4253 3132 2645 2621 2521 2484 Net Footage 38 5 3 5 2 14 17 84 24 4 6 34 23 32 55 52 2O 10 27 24 81 306 Gross Test Interval 148 115 72 52 181 C:\WlN DOWS\TE MP\CCTestl n.doc Page2 of 2 Date Modified: 4/14/98 Date Prepared: 4/14/98 kg HALLIBURTON Disclaimer These calculations are based on certain data, assumptions and applied mathematical methods. Inaccurate well data, changing well conditions, tolerance variations of mechanical components, mechanical malfunctions and other factors may affect these calculations. Halliburton Energy Services, Alaska makes no waranty, expressed or implied, as to the accuracy of the data, calculations or opinions expressed herein, or of the merchantability of fitness for a particular purpose. User agrees by its purpose thereof that the user will release, indemnify and costs related there to adsing out of or in conjunction with such use and incurred by user or third parties, whether due to negligence or otherwise. HALLIBURTON TABLE OF CONTENTS Forcenergy -- Coffee Creek #1 SECTION 1 ..................................................................... TEST SUMMARY SECTION 2 ..................................................................... DST #1 SEQUENCE OF OPERATIONS FLOW TEST RESULTS GAUGE DATA PLOTS SECTION 3 ..................................................................... DST #2 SEQUENCE OF OPERATIONS FLOW TEST RESULTS GAUGE DATA PLOTS SECTION 4 ..................................................................... DST ~ SEQUENCE OF OPERATIONS FLOW TEST RESULTS GAUGE DATA PLOTS CORRECTED DATA PLOTS SECTION 5 ..................................................................... DST #5 SEQUENCE OF OPERATIONS FLOW TEST RESULTS GAUGE DATA PLOTS CORRECTED DATA PLOTS SECTION 6 ..................................................................... MEMORY GAUGE DATA Surface Testing Well Summary Customer: Forcenergy Field: Beluga Lease: Coffee Creek Well #: 1 DST #: 1 On June 6, 1998 the first zone DST was initiated when the guns were fired. There was a 2600 psi nitrogen cushion on the zone when the guns fired. The well was opened on a 12/64" adjustable choke, and flowed for 3 hours and 48 minutes. This flown essentially bled off the nitrogen cushion and the well was shut in at the LPR-N. After a shut in period of 6 hours, the well was reopened for flow on a 20/64" adjustable choke. The tubing pressure at this time was less than 20 psi and bled off quickly. The well was shut in at the choke manifold after a 10 minute flow period and the test was terminated. There was no visible production of hydrocarbons at the surface. · , ?HALLIBURTON Surface Testing Well Summary Customer: Forcenergy Field: Beluga Lease: Coffee Creek Well #: 1 DST #: 2 On June 10, 1998 the second zone DST was started when the guns were fired. There was a 2000 psi nitrogen cushion on the zone when the guns fired. The well was opened for flow on a 12/64" choke. There were four choke changes during the initial 1 hour and 16 minute flow period. Fluid levels were shot after tis flow. After a downhole shut in period of one hour the well was opened for flow on 28/64" adjustable choke. The tubing pressure was 60 psi. After a 53 minute flow the LPR-N was closed and the test was terminated. There was no visible production of hydrocarbons at the surface. OHALLIBURTON Surface Testing Well Summary Customer: Forcenergy Field: Beluga Lease: Coffee Creek Well #: 1 DST #: 3 DST #3 had four components to the test. The first run of DST tools was run on June 16. This run was changed because of concern whether or not the zone that was squeezed off had good cement. A decision was made to change from the annular pressured LPR-N to the mechanically operated FuI-FIo Hydrospring as a downhole shut in tool. On June 17, the the bar was dropped to fire the guns. There was a 1650 psi nitrogen cushion on the well at this time. The well was opened on a 12/64" adjustable choke for a flow period of 1 hour and 37 minutes. After a shut in period o 1 hour and 27 minutes the well was reopened for flow. Tubing pressure at this time was less than 20 psi. This flow period lasted 17 minutes, and the decision was made to terminate the test. There was no trace of hydrocarbons at the surface during either flow period. When the tools were pulled from the well it was discovered that the hydrospring had not opened prior to dropping the bar because the bar was broken into two pieces and wedged above the tools. After pulling the complete tool string it was found that the guns had not fired. The hydrospring was changed out, the gauges were redressed and a new firing head was put on the guns and the tools were run again. On June 18, DST #3B started when the guns fired at 15:52. There was a 1650 psi nitrogen cushion on the well. The well was opened for flow on a 12/64" adjustable choke. After a flow period of 2 hours and 5 minutes the well was shut in at the choke manifold, the annulus had lost fluid. The annulus was filled but the water kept falling then rising. The hydrospring was closed and the annulus and tubing were monitored. After a shut in of 38 minutes, the hydrospring was opened and the well was opened for flow on a t6/64" adjustable choke. This flow period lasted 1 hour and 45 minutes and failed to yield any hydrocarbons at the surface. The test was then terminated. On June 19, the decision was made to retest the zone using the LPR-N above the zone that had been squeezed of. DST #3C started at 21:25 when the LPR-N was opened. There was a 1250 psi nitrogen cushion on the well at this time. The well was opened for flow on a 12/64" adjustable choke. After a 2 hour flow period the LPR-N was closed. This shut in period lasted 1 hour and 25 minutes before the test was terminated. There was no visible hydrocarbons at the surface during test 3C. HAL L i BN' Surface Testing Well Summary Customer: Forcenergy Field: Beluga Lease: Coffee Creek Well #: 1 DST #: 5 On June 22, 1998, the DST of the fifth zone of Coffee Creek #1 was initiated when the guns fired. There was a 950 psi nitrogen cushion on the well at this time. The well was opened for flow on a 12/64" adjustable choke. This flow period lasted 1 hour and 8 minutes. The well was then shut in at the LPR-N. The shut in lasted 30 minutes and the decision was made to cycle the Omni valve to the circulate position and reverse out. With the Omni in the circulate position nitrogen was used to displace the fluid from the tubing. When the tubing was displaced and the nitrogen bled off the well was reopened for flow on a 24/64" choke. There was no tubing pressure at surface when the well was opened for flow. After 2 hours the test was terminated. There was no visible hydrocarbons at the surface during the test. SEQUENCE'~' OPERATIONS '~ COMPANY: Forcenergy WELL: Coffee Creek #1 *"~'~' ........ ' '" ' LEASE: Coffee Creek HALLIBU RTOI FIELD: Beluga TICKET: 693294 I I DATE TIME STE CREW ON SITE OPERATIONS PERFORMED 19:50 Start pressuring, up line to 1000#, sta~ling at 500# and then 1000~ 20:00 'Pressure holding at 500#, take it up to 1000~ 20:15 Test good at 1000~, bleed of pressure 20:25 . Rig up air line at choke manifold to purple lines and vessels of testing fluid 20:30 Blow down flowline and bypass line to tank 20:40 Close off air, change valves so that we can blow down heater coils and separator 20:45 Start blowing down separator to tank 21:10 Unit is blown down 21:15 Bypass stack pack, arrange valves so that we are able to blow down gas scrubber "' 21:20 Start blowing down gas scrubber 21:30 Scrubber is blown down 21:35 . Arrange valves to do one pruge of the entire system 21:40 Pressure up system and flush with air 22:00 .... PressUre testing completed 22:15 Pressure up tubing with N2 for underbalance ' ' 22:30 Heater still will not light', decision made by Ray'Springer to go without it. . . .. ' Hook up chemical inj.ection pump, ' ' ' iHold Safety meeting prior to dropping bar 06~06~98 00:2'5 Tyburski-18 Drop bar to fire guns .. 00:.27. Jones, Morgan-16 Guns fired Hines, Zeddies-16 ' Test well as directed (see test results) i~ 01:~'2 ' Well shut in because ferrule blew off the psi sensing line for the BP controller ..... 01:15 Re-open well on 10164 ...... 01:35 Well shut in, lost rig .air supply, air compressor went down . . ' 021'10 . Well reopened on, 10164, when ri~l air is back online 04:12 Run rig wireline to ta~l fluid ... 08:00 ..... Tag fill at 3780' .. 49.8 bbls. fluid ............... ' '09:15 Open LPR-N --0 psi on tubing. '10':00 .... Test completed . 18:00 ' Harvey arrives to repair heater . 06~07~97 ' 06:00 Tyburski -18 ' ' Ni~lht crew still here, no helicopter until 10:30 ...... i ....... .'""i ..... ... Morgan~ Hines, ZeddieS-19 Harvey Completes repair on heater .. Do maintenance on equipment .... ..... Work on safety syste.m., Eri_c Jones 'to town ..... i-,age 4 SEQUENCET~ , OPERATIONS COMPANY: Forcenergy WELL: Coffee Creek #1 .... ':';"~' ' LEASE: Coffee Creek HALLIBURTON FIELD: Beluga TICKET: 693294 I I DA'T=E TIME STE CREW ON SITE OPERATIONS PERFORMED 51~'i98 11:30 Kris Zeddies Arrive Spernak Air ' ' 12:00 Meet with Company Representative 13:00 'Leave for location via track vehicle 19:15 Arrive location--Extremely muddy, Find ecluipment ,, 21:00 Shut down for day $128198 06:00 Kris Zeddies Started moving e¢luipment around to ~let at Halliburton equipment ' Moved ri~l e(luipment off cement pad Started buildin0, the berm , Rolled out herculite , ,Set separator and vertical scrubber Built more of the berm Moved part boxes and baskets into 'the berm Made inventory of the boxes and baskets 22:00 Shut down for the ni~lht 5129198 , 06:00 Kris Zeddies " Unloaded' fish totes and put tools into tool box Moved tanks to the berm Stood up 400 bbl. tanks . , .. One tank has drain fittin9 ripped Off, called office to report this' . Ran liquid discharge lines to tank manifold .... . . . Cleaned foam. insulation from around broken fitt!n9 s° that the tank can be repair'ed . . FiniShed the berm 21:00 ' Shut down for the night "' 5130198 ' 06:00 Kris Zeddies Hooked up tan'ks to tank inlet , ' ,, , Ran high gas out to scrubber pods , , Ran high gas line to vertical .... ' " Ran electrical cords alon~l berm, problem reaching ~lenerato,r .... ~ Put liquid level controllers on unit ,, Put sight glasses on the unit , ........ Cleaned up lab Inventory of parts in lab, .... ,, Fax n, eed list to Anchora~le, shut down for night , 5131/98 06:00 Kris, Zeddies Went over, , plan, with Ron,,,, SteVens,· , C°. Rep. , , ' ' ,, ........ Finished installing sight glasses on separator , SEQUENCE I,, OPERATIONS COMPANY: Forcenergy WELL: Coffee Creek #1 :' ...... LEASE: Coffee Creek HALLI BU RTOl'q FIELD: Beluga TICKET: 693294 i i i I I DATE TIME STE CREW ON SITE OPERATIONS PERFORMED i Some. parts arrived by helicopter, put them up in lab , Installed flan~le on PSV Started tyin~l in liquid out line from vertical to separator discharge line Checked liquid controller on vertical scrubber 'Unbolted the berm so that the lab could be moved out 17:30 . Moved from ri~ camp to main Veco camp at Beluga ..~ 06/01/98 06:00 Kris Zeddies Travel from Veco camp to Cleared trail through the woods to run hi~lh ~las flare line to 9ravel pit, south of location. Travel'ed back to Vec° camp . . 06/02/98 06:00 Kris Zeddies Travel frOm Yeco Camp to'ri9 ' ' Wait on loader use, check with electrician 'about hook ups .... ~ Moved berm wall back Moved Pipe rack and lab · Put to~ether more tubin~l for south flare line 16:00 ' Tyburski,Hines, Morgan, Crew travel t0...Spernak Air fo.r transport to Belu~la' ., 17100 Winslow, Jones Arrive veco camp ........... " ' =Get situated at ri9 camp, meet with Kris and 9o over procedures' to . .. , , ,, be used durin~l the ri9 up and flow. , ,,, 18:00 , Kris travels from ri~l to Veco camp ...... , ,, , 22:00 .. Shut down for ni~lht. . 06~03~98 04:30 :Hi'nes, M0r~lan, Jones Hold safety meetin~h travel t° location ...... ' Zeddies,Winslow+18 Look over location for ri~l-up needs ......... . Tybu ,rski+20 Start runnin~l flare line to the north s!de of location usin~l 2.875 tbs. , ........ Run flare line to the ~Iravel pit on the south side usin~l tb~l. ,, ......... Run' relief line towards the north side flare .... , , ' Add flan~les to ~las.. scrubber Make lists of needs 06~04~98 06:00 Tyburski-22 ' ' No'helicopter Until 12:30'because of the weather. ". ....... Winslow Set up highllow pressure sensors ........ 1.2:30 Morgan/Jones-16 .... Mark and Eric arrive on location ........... ' , Add flan~e to SSV ...... . .............. page SEQUENCEi OPERATIONS ' i COMPANY: Forcenergy WELL: Coffee Creek #1 :~":" ...... ' · Co.eeCree HALLIBURTON FIELD: Beluga TICKET: 693294 I I :DATE TIME STE CREW ON SITE OPERATIONS PERFORMED HineslZeddies-16 Bolt up liquid level controllers Fill heater bath with water Tie in a by-pass line from the inlet of the scrubber to the tank manifold Hook up air to test supply lines .. Hook up Barton meter Set up N2 Try to fire heater Crew chan~le out at 06:00 and 18:00 .... MorganlJones.-Days HineslZeddies--Nights .06..!.05/98 05:00 Tyburski-21 Still working on heater Jones, Morgan 16 Set up flowline , Hines, Zeddies-16 Run airline and safety system Hold Safety meetin~l, go over psi test procedures ...... 14:30 start Iow pressure test of equipment Leak at dicharge lin. e, nipple broken--break down and re-pipe. .".'".' 15i45 ' ' Finished low pressure test 16:00 , , Start pressure testin~l equipment according to $,TE procedures _ . .... Strart testin~l high pressure flowline to 5000#, sta~in~ it at 1000#, 2500# then 5000# _ Chicksan ~lives out at 2500#, change out with hard 90's after bleeding off line 16:30 Start sta~in~' pressUre.test a~l.ain. 16:40 Test to 5000#, hold 10 minutes ....... !6:50 " ~ ' , Bleed off pressure, open Valvin9 thru heater to separator and fill unit 17:00 , Leak at oil meter Y strainer, drain unit--no gasket, make up gasket from Spare material " , Shut down for crew change .. 17:45 . " Start fillin~ unit again 18:.15 . Unit filled with water, start pressure, test to 1000#, Staging at 500~ and 1000# _ Y strainer leaking again at 500# .. Bleed off pressure and and drain'unit and repair agian ..... Jared H011ey (Fluenta) arrives, at 18:00 18:50 New gasket. material in place, strart fillin~ .up unit again ' ' 19:10 Start testing unit again, Fluenta setting, up sand detection system ... ' ... ... 19:20 500# on unity ho.ldin.~l ,steady 19:30 ..... Bring pressure up to 1000# and hold for 10 minutes 19:40 ... Test of unit completed, bleed off pressure ... _ 19:45 ............. Bypass heater/separator, and prepare to test gas Out line from separator to scrubber . rage O COMPANY: Forcenergy HALLIBURTON ENERGY SERVICES H^LLI B U RTON FIELD: Beluga WELL TEST REPORT LEASE: Coffee Creek WELL#: DATE/TIME REMARKS WELLHEAD CONDITIONS TOTAL GAS TOTAL OIL TOTAL WATER WHP WriT CSG CHOKE GAS RATE GAS CUMM. COR. VOL OILRATE OIL CUMM. APl G.O.R. YIELD LIQ. INC. H20 RATE CUMM. mld/yr hr:mn (psla) (de;iF) (psia) (64ths) (mscfld) (mscf) (stb) (stb/d) (bbls) ((~60°) (scf/stb) (stblMMscf) (bbls) (bwld) (bbls) 05106/98 00:10 Pressure up Cs~l. to 2000# 2600 50 2000 12 05106198 00:10 Drop Bar to Fire ~luns 2600 50 1980 12 05106198 00:25 Guns Fired 2600 50 1930 12 05106198 00:27 Open well on 12164 2600 50 1930 t2 05106198 00:30 Safety system trips Sll at SSV 1450 50 1900 12 05/06/98 00:45 Open well 10164 1430 50 1850 10 05106198 01:10 Shut in well, leak in flare line 1345 50 1850 110 05106198 01:12 Open well on 10164 1340 50 1855 10 05106198 01:30 Well s/i, lost air supply from ri~l 1020 50 t850 12 05/06/98 01:35 980 50 1845 12 05106198 02:15 800 50 1830 12 05/06198 02:30 Open choke to 20~64 520 50 1950 16 05/06198 03:00 380 50 1850 20 -- 05106198 03:15 Bleed off cs9, close LPR-N 300 50 1850 20 05~06~98 03:55 Tubin~l and fiowline bled off 50 28 05~06~98 09:15 Open LPR-N 20 50 1500 28 05~06~98 09:25 Shut in at choke manifold 50 1500 28 05~06~98 09:30 Prepare to reverse out 50 28 Page 1 X ® ® Pr ssur /T mp ro r Test No: 1 zl_.O Gauge No: 10098 5.0 2.0 1.0 I I I I 0.0 History Well No: II 1 I I I I I I I I I I I 0~0 I I I Company: ~ FORCENEROY 200 ''1 I I I o HES z 100-~ o ~ o ,-w- o X 5.5 5.0 2..5 2.0 1.5 1.O 0.5 Pressure Vs Time o ~o o -o o -o -- -"0 -Z 0 0. _ _ o -- -- OZ. 0 0 0 o ~ o o o o o o o i X 0__ (D ..5.5 3.0 2.5 2.0 1.5 '1.0 0.5 Pressure VS Time o o o O~ 0 CD 0 0 0 0 0 ~z 6 6 6 6 6 6 O 6 6 o o o o o o o o ~ 0 3,6 3.0 2_,4 1.8 1.2 0.6 0o0 Pressure VS Time Pressure Vs Time X .5.5 5.0 2.5 2.0 1.5 1.0 0.5 ijllllllJllJlllJlJJllJlJlllJJlJJlll'lllllJ_ Z oo - " o o H~S o 0 0 0 0 0 0 © 4.0 5.0 2.0 1.0 0.0 Pressure~/Temperat ure Test No: 1 Gouge No~ 10220 History Well No: t I I I I t I , I I I I I O3O Compony: FORCENEROY 160 t20 8O -~ 4-0 I I I I I I I I o HES 0 Z 0 x ,5.5 ,5.0 2.5 2.0 1.5 1.0 0.5 Pressure Vs Time oz o k5 ~ o k5 i::::5 o o o o o 0 o o ~ o x 5.5 5.0 2.5 2.0 t.5 1.0 0.5 Pressure Vs Time o o o o o o o o HS~ o Pressure Vs Tirse X 5.6 5.0 2.4 1.8 1.2 0.6 0o0 IIl'llllllllll~l [ii ~11 [ i.[lit i it I[[[tl~lllil[[lll I Illllt I I i [ t I i [ I i ~ ] 1 i ] i i ~ I ~ J I I I I I I I I I I I ] I I I I I I I [ I I I I I oz o o [5 [5 o b b o 0 0 0 0 0 0 0 0 ~k~ 5.0 2.5 2~0 0~5 Pressure Vs Time 8 8 8 SEQUENCE OF OPERATIONS COMPANY: Forcenergy WELL: Coffee Creek #1 / ~r~"~' , LEASE: Coffee CreekHALLIBURTON FIELD: Beluga TICKET#: 693294 DATE TIME STE CREW ON SITE OPERATIONS PERFORMED 06108198 06:00 Tybumki, Winslow Do maintenance on equipment , Morgan, Hines, Zeddies Function test heater, chemical injection pump, safety system Build staim for the berm Hold safety meeting prior tO picking,uP guns Wait on BOP test , , , 06109198 06:00 Tyburski, Winslow Hold safety meeting, runn!ng in hole with tool string 12:00 Morgan, Hines, Zeddies Finish rigging up the upstream flowline, SSV, and safety system to the floor 15:00 Hold safety meeting, pressure teSt flowline to the front of the vessel Preheat the heater 16:00 " Pressure test N2 line to 3000~ ........ 16:t0 Test Good 16:12' " ~Start ,pun~'pin,g N2 CUshion.' ' ,, ' .... ..... 17:00 N2 pump down , 18:20 Husky 8 arrives with N2 tank, transfer fluid , 20:15 ', N2 pump back on line, finished with N2 transfer , 21:00 " Tybumki to Kenai for stitches ' , ...... ' '21:25 Hold safet7 meetin, 9,,N2 surface pressure at 2000# ~ 22:12 .... Pre~sure up, CSg~,to 1200#--Pressure leaking Off ................... .... 22:30 Start bleeding off N2 2,3,,;55 ...... ,,,," ,, N2,bled 0ff-- mub'in'{l",i'S',0# ,, , ', ,', ,, 06110198 00:30 Hines, Z'eddieS, Duniphin Start out of hole with tool String ..... .... 05:00 Tools out of hole, testing tools 09:40 ' 'start picking uptools '" ,, , ", .... 12;20 .... Helicopter arrive with Tyburski,, Morgan, Jones ........ 12:30 Run in hole with tool strin~l ....... ' 13:30 Hold safet7 meeting ........... ' ' 14:30 N2 pressure testing upstream flow line , ,, ,, 15:15 N2 starts putting on cushion Page 1 i SEQUENCE OF OPERATIONS COMPANY: Forcenergy WELL: Coffee Creek #1 ..... ..... LEASE: Coffee Creek HALLIBURTON FIELD: Beluga TICKET#: 693294 I I DATE TIME STE CREW ON SITE OPERATIONS PERFORMED 17:40 Hold safe~ meetin~l 18:33 Pressure up annulus to open LPR-N 18:38 Drop bar to fire ~uns 18:41 Guns fired 18:47 Open for flow On 12/.64. tubin~l pressUre 2080~ 19:12 Change choke to 14/64 19:40 Chan[le choke to 18164 .... 19:45 , Chan~le choke to 24164 19:53 Safe, valve loCked open ~ .. 19:55 Chan~le choke to 28/64 ............... ' 20:03 " Close LPR.N ......... 20:1'6 Shut in at manifold, take fluid level'shots 21:0~ " . ....O~en LPRN'with manifold shut in ... ' 2i:39 ;Open choke manifold on 28164 ,, ' 21:40 Shut in at choke to shoot fluid' level ' ' ............ ' 21:57 " Close LPR-N ' ' 22:0S ........ '.' Unseat packer to reveme Out and' come out Of the hole. · , , i i i i i i i i ii ii i i ii i ! i iii i i Page 2 O. COMPANY: Forcenergy HALLIBURTON ENERGY SERVICES H^LLI B U RTON FIELD: Beluga WELL TEST REPORT LEASE: Coffee Creek WELL#: ~ATE/TIME " REMARKS ' WELLHEAD CONDITIONS TOTAL GAS " TOTAL OIL ' TOTAL ~/ATER , , , WHp WHT CSG CHOKEiGAS RATE GAS CUMM! COR. VOL OILRATEIOILCUMM APl G.O.R. YIELD LIQ. INC.I H20 RATE CUMM. m!d/yr hr:mn (psia) (deg F)I (psla) (64ths) (mscfld) (mscf) (stb) (stbld) (bbls) (~60 °) (scffstb) istb/MMsct (bbls) (bwld) (bbls) 06110198 18:47 Open well on 12164 2080 57 1450 12 06110198 19:02 1640 56 1450 12 06110198 19:12 Change choke to 14164 1340 56 1375 14 1081.00 11.26 06110198 19:30 880 54 1325 14 935.28 21.00 0.6.110198 19:40 Change choke to 18164 700 54 1320 18 875.79 30.13 0.6_110198 19:45 Change choke to 24164 580 54 1310 18 790.35 38.36 06110198 19:55 , Change choke to 28164 340 54 1300 ,, 24 38.36 06110/98 20:03 Close LPR-N 340 54 1300. 28 38.36 .._ 06110198 20:15 Shut in at choke manifold 60 i, 54 [, , 06110198 21:04 Open LPR-N 60 54 . , 06110198 21:31 Open for flow on 28164 60 54 28 06/10198 21:40 Sll choke manifold 06110198 21:57 Close LPR-N ,. 0,61t0198 22:05 Unseat packer, Prepare to POOH . . . . . . I Page 1 Pressure/Temperature History Test No: 2 ~.0 Gauge No: 10220 Well No: 1 x qP I I t I I I I ] I I Company: Forcenergy 120 I I HES 40..~TM -0 -- - 0 .. -- -- -- -- -- -- 0 o .3.0 2.5 2.0 1.5 1.0 0.5 0o0 Pressure Vs Time ~~~~~~~~~j~~~~~~~~~~j~~~~~~~~~~j~~~~~~~~~~j~~~~~~~~~j~~~~~~~~~j~~~~~~~~~j~~~~~~~~~j~~~~~~~~~ O0 Co q.o Eo qo EO r.~ cO 0 Pressure Vs Time 2.4 2.0 X 0.4 0.0 / / / / / / / / 0o 0 0 0 0 0 0 0 O~ ~ ~ ~ 0 ~ ~ ~ 0 6z ~ © ~ 6 Q 6 Q' 0 o © 0 0 0 0 0 X i?..4 2.0 1.6 1.2 0.8 0-.4 0.0 0 0 0 0 0 0 0 0 Ht~ 0 6~C 60C Pressure Vs Time c_ Ca o on 0 (...n 0 0'~ 0 z 6 6 6 6 6 6 O 0 0 0 0 0 0 0 H~ 56E_ 52C _ _. 48C_ 44C_ -- -- 40C 0 0 ": SEQUENCE OFt ERATIONS ' , I COMPANY: Forcenergy WELL: Coffee Creek #1 LEASE: Coffee CreekHALLIBURTON FIELD: Beluga TICKET#: 693296 DATE TIME STE CREW ON SITE OPERATIONS PERFORMED 06/12198 Tyburski,Hines, Mor~lan, Jones Crew stand-by in Anchora~le , Zeddies, Winsiow 6113/98 Tyburski,Hines, Morcjan, Jones Crew stand-by in Anchora~le Zeddies, Winslow , 6114/98 15:30 Hines, Morgan, Jones, Zeddies .Arrive Spernak Air for transport to Belu~la Veco camp Winslow, Tybumki 'Travel to Beluga camp 16 Talked to Mike Murray, he said for the Crew to come to the ri9 in the mornin9 because they were still circulatin~l . . , 6/15/98 06:00 T.¥burski, Mor~lan, Jones, Travel to ri~l camp Winslow, Zeddies,Hines Ri~l still filterin~l brine .. 23:56 16 Start oUt of hole with bit and scraper 6/16198 01i45. .Tyburski -18, M0r~lan, Jones, Hold safety meetin~l ...... '.. , , Winslow, Zeddies,H!ne.s 02:10 16 Start pickin~l .UP ~luns 04:00 Start both ~tauges, 10220120225 and' 1.0102120113 ..... ' 04:30 Start pickin~l up tools ............. 10:00 Sch!umber~ler starts loP,lin9 .... " 'i3:40 Pick up surface tree .... . ~4:00 . Ri9 up surface iron .... 14:30 Ri~l down surface iron, pull out of hole , 19:30' ~ Gau~eS at surface, re-pro~lram . ' ........... 20:00 Chan~le out tools, take out LPR-N and add hydrosp, rin~l ' 22:40 " Run in h01e with new tool strin~l .......... 6i17198 '03:30 Tyburski. 19, Mor~lan, Jones," ~Correiation and sPace out dOne, .r!~l up surface head and iron ' 04:30 Zeddies,Hines, Duniphin ~Hold safety meeting ... 05:00 16 Pressure test surface iron to heater to ~000# , , , , 05:10 Pressure test lines to 3000# 05.:20 '" Test' ~ood, bleed off flowline ......... 06:00 Pressure test N2 line 07:30 " paul Winsiow' t~ Veco. camp then to Anchora~le " 08:30 Electrician rigging up Schlumberger back-up generator to give us Power . , .. ' .I SEQUENCE OF,i ERATIONS , .... COMPANY: Forcenergy WELL: Coffee Creek #1 "~'" ' ' ' LEASE: Coffee Creek HALLIBURTON FIELD: Beluga TICKET#: 693296 DATE TIME STE CREW ON SITE OPERATIONS PERFORMED i 09:30 Electrician .rigging up hot wire set-up from Epoch lab .... 10:55 Power on, warming up LEL sensors ._ 1t :00 Hol~l safety meeting 11:25 N2 cooling down 11:30 Start pumping N2 Cushion ..... 12:45 Cushion completed 13:10 Drop bar to fire guns 13:11 IndicatiOn of guns firing , , ...... 13:13 Open for flow on 12164 14:50 Shut in at hydrospring , . ... ' 16:17 ' Open hydr0spring ' 16:19 , Open for flow on 12164, tUbing pressure <20 psi , 16:36 Shut in at chok® manifold ..... 15:15 Rig down Surface iron, and pull Out of hole ' ... " 17:30 Shut down for crew change .... '18:20 Start running in, hole after crew change .. ... 20:30 Hydrospring at.surface, drop bar above tool .. 21:30 .. Pull tools and check guns .. "22:20 . Read gauges, pull vacuum on transducers and reprogram HMR'S 6118198 . 0i:10 'Tyburski - 21, Morgan, Jones~' . Start both gauges, 10220120225 and 10102/20113 . '... ... 01:15 Zeddies,Hines, Duniphin Checking guns . .. 02:35 16 BIT in tool string 02:50 ' ' Start picking up DST tools ~ 03:50 ~ Test hydrospring on rig.floor. 04:10 . Pick up hydrospring and bundle carrier 04:40 .... Run in h01e with tool stri'n~ ~ ' " 05:30 . . Shut down for crew change ' 06:30 Star[' running in hole after crew change 08:15 start correlation logging ' '~ ... 10:15 . End .correlation logging .. 10:30 .. Move pipe to get guns on depth . .. 11:30 Rig up surface head and iron , 12:35 Hold safety meeting for pressure test and N2 pumping 12;55 ' Start pressure testing flowline to 3000#, problem with rig pump . ' ':.'. ,, 13:2,5 ,, Start 3000~.t?st~o.n,floWlin® ..... Page' 2' ,' SEQUENCE OF~ 'ERATIONS COMPANY: Forcenergy WELL:TiCKET,:FiELD:LEASE: Coffee693296C°ffee Creek #1Beluga Creek B'U RTO N DATE TIME STE CREW ON SITE OPERATIONS PERFORMED 13:35 Test 9god 14:00 Start pumpin9 N2 cushion 14:30 Hold pre-flow safety meeting 15:23 N2 cushion completed 15:45 Bleed cushion down from 1780# to 1650# 15:51 Drop bar to fire guns 15:52 Guns fired 15:53 Open well for flow on 12/64 adiustable Choke, flow as directed 16:00 Drop 1.50" orifice plate .. 17;30 Bypass separator to tank 17:58 Shut in at choke manifold, annulus lost fluid , , 18:04 ,Fill annulus with fluid and monitor, fluid is risin9 and fallin9 18:07 Close hydrosprin~l, monitor annulus and tubin9 pressure 18:45 ,, Open for flow on 16164, flowline on bypass to the tank, open hydrosprin9 20:30 Rig down surface iron and choke manifold, prepare to pull out of hole 21:15 ~, 'Ri9 down surface tree ' ,, , 21:45 Pull out of hole with tool strin9 ,, 6119198' 01:1'5 Tyburski -21, Morgan, Jones -18,,, ToOls at surface .... 06:00 Zeddies,Hines, Duniphin Run bench test on gauges ' , 11:30 16 , Decision made to retest zone usin9 LPR-N wi Packer above squeeze perfs , 12:00 End bench test, found that 10102120113 did not collect data, sent to town ' , ............. Clean out 10220 crystal, cavity and pull vacuum., check transducer frequencies, ,', Reprogram gauges. 10220120225 and 10222120569 15:00 Run in hole with tools , , 17:20' ,, , Pick,,uP surface head ..... 17:54 , Set packer. 'Wait On crew change ,,, ,, 19:15 ,~, Fill flowline with water for pressure test , 19:20 Pressure test flowline to 1000# t9:30 ' Test lines to 3000# 19:40 Test 90,0d 19:50 ...... ,, Ri9 up N2 line' ,, ' ' 20:15 ,, Start pumping up N2 cushion , ,, , 2,0:40 ,,, Hold safety meeting , 21:00 ...... N2 cushion completed, !250# on tubin~ ~, , 2t:26 , Pressure up_casi_ng tO open LPR-N .... SEQUENCE OF;' 'ERATIONS COMPANY: Forcenergy WELL: Coffee Creek #1 ' .......... ' ' LEASE: Coffee Creek HALLIBURTON FIELD: Beluga TICKET#: 693296 I DATE TIME STE CREW ON SITE 'OPERATIONS PERFORMED i i 21:25 ' Open for flow on 12/84 , 21:32 Shut in at manifold, Bleed casing 21:42 Pressure up casin~l to open LPR-N 21:43 Open up for flow on 12/64 23:25 Bypass separator to tank 23:50 Bleed off casing to close LPR-N 6120198 01:15 Tybumki -20, Mor~lan, Jones -18, Make sure tubing is at 0 psi,,,ri~ down sur[ace iron ,,, 01:35 Zeddies,Hines, Duniphin Unseat packer 01:50 16 Start Out of hole with tools , , 05:00 Tools at surface 06:15 Break down to0is, read and se~ice gauges ,, Page 4 HALLIBURTON ENEROY SERVICES FIELD: Beluga SURFACE TESTINO REPORT LEASE: Coffee Creek WELL#: CO.REP.: Mike Murray DATE/TIME REMARKS WELLHEAD CONDITIONS TOTAL GAS ' TOTAL OIL .... ~OTAL WATE~ , WHP WriT} CSG 7.,HOKE GAS RATE GAS CU, MM COR. VOL OILRATEOILCUMM 'Apl G.O.R. H2S CO2 LIQ. INC. H2ORATE CUMM." ~ld/yr hr:mn (psiG) (deg F~ (psiG)(64ths) (mscfld) (mscf) (stb) (stbld) (bbls) (~60 °) (scflstb) (ppm)! (%) (bbls) (bwld) (bbls) 6118198 15:52 Open well on t2164 1650 68 12 6118198 16:00 Gas Gravity -..982 1160 68 12 874.34 9.11 6118198 16:15 1020 68 12 864.00 18.11 6118198 16:30 900 68 12 690.00 25,30 6118198 16:45 Gas 9ravity -..962 375 67 12 494.86 30.45 , 6118198 17:00 375 67 12 494.86 35.60 6118198 17:15 150 68 12 257.05 38.28 ,,.6118198 17:30' Bypass separtor to tank 75 68 12 38.28 , , 6119198 21:43! Openwellon 12164, startDST3C 1280 58 1500 12 38.28 6119198 22:00 Drop 1.50" plate 880 58 1475 12 688.00 45.45 6119198 22:15 620 58 1450 12 494.28 50.60 6119198 22:30! Ch__ange orifice plate to .750" 420 58___ 1450 1,2 406,07 54.83 6119198 22:451 320 58 t425 12 228.74 57.2t 6/19198 23:00 200 58 1425 12 145.38 58.72 6119198 23:15 120 58 1425 12 90.20 59.66 , , , Page 1 HALLIBURTON ENERGY SER¥1OE$ FIELD: E~lu§a $URFACE TE$TING REPORT LEASE: Ooffee Oreck WELL#: i CO.REP.: Mike Murray "DATE/TIME REMaRKs WELLHEAD CONI~ITiONS ' TOTAL GAS ' T0~AL OI1~ ' ' ' TOTAL WATE'R ........ WHP WriT CSG ;HOKEGAS RATEGAS CUMM COR. VOL OILRATEOIL CUMM APl G.O.R. H2S CO2 LIQ. INC. H20 RATE CUMM. mld/yr hr:mn (psiG) deg FI (psiG) (64ths) (mscfld) (mscf) (stb) (s~'bld)' (bbls) (~60 °) (scflstb) I(ppm) (%) (bbls) (bwld) (bbls) 6118198 15:52 Open well on 12164 1650 68 12 . $118198 16:00 Gas Gravity -. ,982 1160 68 12 874.34 9.11 · I 6118198 16:15 1020 68 12 864.00 18.11 ' I .... 6118198 16:30 900 68 12 690.00 25.30 ..... 6118198 16:45 Gas gravity-..962 . . 375 67 12 494.86 30.45 6118198 17:00 375 67 t2 494.86 35.60 ........ 6,/.18198. 17:15 .. 150 68 , . 12 257.05 38.28 6118198 17:30 Bypass separtor to tank 75 68 12 38.28 . . 6119198 21:43 Open well on 12164, start DST 3C. 1280 58 1500 12 .. 38...28 .... 6119198 22:00 . . D.rop 1..50" plate 880 58 1475 12 688.00 45.45 ........ 6119198 22:15 620 58 1450 12 494.28 50.60 ......... 6,/.19198 22:30 Chan~le orifice plate.to..750" 420 58 1450 12 406.07 54.83 _ 6119198 22:45 320 58 t425 t2 228.74 57.21 .................. 6119198 23:00 200 58 1425 12 145.38 58.72 ............. 6119198 23:15 120 58 1425 t2 90.20 59.66 ............... ..... ,,, Page 1 X 2.0 1.0 0.0 , Pr essur e,/T emper at ur e Test No: 3A Oauge No: 10102 I I I I 0 , i I History Well No: Company: I I I Forcenergy I 120 80 I I HES Z x 5.0 2.0 1.0 0.0 Pressure/Temperat ure Test No: Gauge No: ' I I 5A 10220 t I I I I t I I I LI History Well No: 1 Compony: I I I Forcenergy I _ HES 120 z X 2.,4 2.0 1.2 0.8 0.,4 ~r~$sur~ Ys Tirn~ Z Oo X 1.9 1.6 1.3 1.0 Pressure Vs Time X ] Pressure Vs Time 1.85 1.7C X 5.0 2.0 t.0 0.0 Pr essur e,/T emper at ur e Test No: 5C Gauge No: 10102 I I I I I History Well No: 1 I Company: I Forcenergy I _ _ _ -- -- _ _ - - - - . _ HES 120 8O Z X 2.2 1.g 1.6 1..5 Pressure Vs Time z 6 6 6 © © 6 6 ~5 o o o o o o o ~ X 2~4 2,1 t.8 1.5 Pressure Vs Time -- Q,,,I® Q,,,I C.,q (_~ O0 Oc Qo 0-) -~ 0 © 0 0 --o ~ ~ o ~ --~ C) O0 O~ .-~ I",0 CZ) © 0 m~ x Pressure?Temperature History Test No: 3C .3.0 Gauge No: 10015 t I 2.0 t.0 0.0 I I I I J . Well No: 1 I I I I I , I Company: Forcenergy 60 I I I I HES - 50 ~ Z -. _ -- -- - 40 - _30.., _ - _ --q - '13 - ID - _ .o. ~0 -0 © X 1.9 1.6 1.5 Pressure Vs Time Illlll'lllllllllllll IIIIIlllltll IIIIIIIIIIIIlllll'lll IIItllllllllllllllllllllllllllllllllll: -- 1.0 o o o o o o o ~ 0 X 2.2 1.9 1.6 1..5 Pressure Vs T'me (.,,< CO 0,~ O0 0 0 --' .w-', '--' .--w-'. f',,.). · 0 0 0 0 0 0 0 0 ~ -- _o -(3 0 _04 -- -"ID -- o -- ,. -- X o-- Pressure//Temperm(ure 5C 10102 I Test No: 2.0 Gauge No: I -- -- - 1o0_ 0.0 · o History Well No: 1 ' I i O~ ~oo Company: Forcenergy 120 I I I I HES _ 8O 'D Z 0 oo 0 1.6 Pressure Vs Time 0.7 -O7 0 © © © © © © © 1.9 1.0 Pressure Vs Time O.,I® Q,I Q,I 0,1 O0 0 0 .-~, ,-7', ~z ~ ~ ~ zoo ~ 6 ~S © © © © © © © SEQUENCE Of OPERATIONS I I COMPANY: Forcenergy ~k, WELL: Coffee Creek #1 ~ H LEASE: Coffee CreekALLIBURTON FIELD: Beluga TICKET#: 693299 I DATE TIME STE CREW ON SITE OPERATIONS PERFORMED 6121198' ' 07:00 Tybumki, Jones, Morgan Wait on cement and circulation jobs Zeddies, Hines 6122198 07:00 iTybumki, Mor~lan, Jones Hold pre-trip safety meetin~l 07:30 Hines, Zeddies Start pickin~l up ~luns 08:30 Pick up DST tools 09:10 Start HMR's, 10015120110 and 10102120225 09:30 Run in hole with tools , , 14:39 RUn .in hole with Io~!n.~ tools Move pipe to ~.et ~luns on depth .... 11i39 ' Set Packer 18:00 " Start ri99in9 up'surface iron 19:10 Fill flowline with water for pressure test ................. i9:32 Pressure test line to 1000# 19:35 Rais® test p, ressum to 3000# '" 19:40' , .... ' ' ' Leak at Lo-torsi,valve downstream of choke manifold 19:45 i Change out valve 20:10 ' Pressure up,tubin9 'tO 1000# .... 20i1'5 '" Raise pressure to 3000# ..... 20:25 Test. ~lood ..... 20:'35 Bleed down Pressure, flush lines to tankS'with air. function LPR-N" . ........ 21:00 . Hold safety meetin9 21:39 Bar away . . 2i:40' ' ' Guns fired , , , , ,, 2!;41 .... OPen for flow on 12164 . 20:49 Close LPR.N .... 20i50 shut in at'choke manifold ........ 23i'20 ' Pressure up 'casin~l t° start c¥clin9 Omni ..... . .. ' ..... 23:30 Reverse out , Page 1 SEQUENCE OF OPERATIONS COMPANY: Forcenergy WELL: Coffee Creek #1 FLiEEtSDE:: CB:luff;eaCreek ~[[~'JHALLI B U RTON TICKET#: 693299 DATE TIME STE CREW ON SITE OPERATIONS PERFORMED i 6/23198 00:10 Tyburski, Mor~lan, Jones Ri~l up surface iron to displace tubing volume with N2 00:30 Hines, Zeddies, Duniphin Cycle Omni to circulate position 00:35 Pressure test 'N2 line '00:55 Cycle Omni 01:17 Finish cycling Omni 01:27 . Start displacing fluid with N2 02:02 Stop pumpin~l N2 .... 02:04 Pressure up casin~, tubin~! 1320# 02:06 Bleed of casin~l to close LPR-N 02:07 Open for flow to bleed off N2. in tubinl], 12/64 .... 02':12 Choke to 24164 02:27 ' Pressure up caSin~l to move Omni tO well test position 02i'29 ..... Bleed casin~ ,, ,, ..... 02:47 Pressure up casin,~l tO open LPR-N , 02iS0 LPR'N open. 02:54 Choke to 24/64 03:00' Bleed off caSing ............ 03:12 ' Pressure u.p casin~l .. ... ..... 03i20 ' ' ' Bleed off casing 04;52 " .. PreSsure up ann.ulus to Open LPR-N' . ........ 05:20 :Bleed off cas!..n9 to close tools . . .. 05.:.30 .. Rig down surface Iron and prepare to pull out Of hole .. 11:30 Tools at surface "' 13:30 Get the word to r, ig down surface equipment .... ... ' .. "..' ...... 14:00 Rigging 'dOwn flowline, piped flare lines, safety system .................. . Pull .sightglasses; liqui,d level controllers.off of separator and scrubber ' ' 18:00 ...... Pull up tubing flare lines and break down, put tubin~l on pipe rack ..... '" " Bolt flanges to vertical scrUbber, pack up gauge support box, gauges and radios and Fluenta equipment to town. ,, , ,,, , , Page 2 i i SEQUENCE OF OPERATIONS COMPANY: Forcenergy WELL: Coffee Creek #1 LEASE: Coffee Creek HALLIBURTON FIELD: Beluga TICKET#: 693299 I DATE TIME STE CREW ON SITE OPERATIONS PERFORMED i i i i ii i i i i i i i 6124198 06:00 Tyburski,, Morgan, Jones Drain tank and heater bath, Roll up electrical, , cable, close up separator Hines, Zeddies, Duniphin Pack up do~l,house, ri~ down berm walls , 18:00 Travel to Veco camp , , ,, ,, ~ , , , , , , ,, , ,, ,, , ,, ,, , ,, ,, ,, ,,, ,,,,,, , ,, ,, , ,, , , , , , , , ,,,,,,,, , , , , , , , , , ,, , , ,,, ,,,, ,, ,, , , , , ,,,, ,, , , ,, , , ,,,, , ,, ,, ,, ,, , ,,, , , ,, ,,, , .... , , , ,,,, , , ,, , , , , , , ,, ,,,,, , ,, , ,, ,, , ,, ..... , , , , , ,, .... , , ,, , , , , , , , , , , , , , , ,,, , , , , , , ,, ,, ,, ,, ,, , , .............. , ..... , , , , , , , Page 3 HALLIBURTON ENERGY SERVlOE$ FIELD: I~luga SURFAOE TE$TING REPORT LEASE: Coffee Oreek WELL#: CO.REP.: Don Jones DATE/TIME REMARKS WELLHEAD CONDITIONS TOTAL GAS TOTAL OiL TOTAL WATER WHP WriT CSG CHOKE GAS RATE GAS CUMM. COR. VOL OILRATE OIL CUMM. APl G.O.R, H:zS CO=: LIQ. INC. H20 RATE CUMM. mldlyr hr:mn (psiG) (deg F) (psiG) (64ths) (mscfld) (mscf) (stb) (stbld) (bbls) (~60 °) (scf/stb) (ppm) (%) (bbls) (bwld) (bbls) 6122/98 21:42 Open well for flow on 12164 950 65 1550 12 6122198 21:45 Drop 1.50" orifice plate 820 65 1550 12 6122198 22:00 Change orifice plate to .750" 520 65 1550 12 425.00 8.85 6122198 22:15 280 64 1550 12 187.04 12.75 6122198 22:30 By-pass separator to tanks 100 64 1550 12 156,63 19,91 Page 1 X Pressure?Temperature History Test No: 4 3.0 Oauge No: 10102 ' Y I I' I I 2.0 1.0 0.0 Well No: I Company' Forcenergy 80 , I .. I HES -- -- -- (5 Z _40e ~ - (- 0 -~ 0 -- -- _ -0 -- z o .. -- 0 1.64 1.6( 1.5z t.4.z 1.4-( Pressure Vs Time ~~~~I~~~~~~~~I~~~~~~ o -o --0 Z -o X .m 2.4 1.8 1.2 O.g 0.6 Pressure' vS 'Time : ,. j i I j j i i j j i j i i j I I I I I I J I J I I J I I J J J I I I J I I J J I - 0 X 1.8C 1.7C 1.6( _ -- 1.5C ;._ -- -- -- -- 1.4( 1.5C -- -- -- t.2C OCZ o"} I'-o- O0 ~ 0 0 0 0 0 Pressure Vs Time _- -- jlJllJljjlllJtlflljlll'JlJlllllJlJlllllllll-- 0 0 0 ~ 0 i x 2.0 1.0 0.0 Pressure?Temperature History Test No: z~ Gauge No: 10015 I Well No: 1 Company: t '"' I I I I [ ' o o HES Forcenergy 50 I _ _ ... -40 3O 20 ® 10 Z 0 0 Z Pressure Vs Time X 1.2 t.16 t / / ~ T z 1.12 Or___ 4z~ OO ~ CZ)Z CD CZ) CZ) 0 0 0 X 2.1 0.8 0.6 Pressure Vs Time ~lllll~ll'll 0 0 0 CD 0 0 0 0 ~ 0 X Pressure Vs Time t.5C 1.4( ~1.2C 1.1C 1.0C 0.9( - / ~ / - / / 5z © © © © -0 -0 -- -- -- -0 .. -- -pO -- CD CD CD CD Pressure~Temperature HistOr~v : Test No; 4 2.0 Gauge No: 10102 Well No: 1 I I I ZO 0 L Company: Forcenergy 80 I I I I HES 40c~ o~ oo 0 1.06 1.0,1 0.9 0,9' 0.91 0,8! Pressure Vs Time 0.8 ----,Ix,) 0c- .~ ~ ~ ~ ~ ~ ~0 0 o o o o o o H 0 1.8 1.5 1.3 1.0 0.8 0.5 0.3 Pressure Vs Time o o o o o o o o H X Pressure Vs '1.2C 1.1C 1.OC 0.9( 0.8( 0.7( 0.6( ~5~_ .o.c OZ 0 I I I I I I I I I IJ[llllll JlJlJ]ll]lllllllllll cs © cs cs cs © cs H CBFFEE CREEK d: 1 PS<A 20~ C~lng 90' EZSV - 35O' 13 3/8' Casing 1;~tcj, TOC 2345' EZSV - 2454' ~OC 2631' DV CoLLar 2808' DST #5 Per?$ 2484' - E665' Inject;Ion Por~ 4009~ TOC 4082' EZSV - 4100' Squeeze Peres 4140' - 4142' 9ST #3 Peres 4253' - 4325' EZSV - 4415' Squeez~ Per-~'s 4400' - 440;=' TBC 5537' EZSV - 5785' DST #2 Peres 5815~ - 5930' TOL 6638' 9 5/8" C~$1ng 6715' TOC 6756' EZSV - 6800' ~OC 7133' DST #1 Peres 6835' - 6983' 7 5/8' Liner 7288' Cemen* Plug 7900' - 7325' TI) 9757' - 8 t/2' Hote RECEIVED JUL 2 9 1998 Alaska Oil & Ga,~ Cons. Cosmission Anc,horacle Forcener v Inc. Coffee Creek #1 Operations Summary February 3, 1998 Report #1 Rig up Sterling Alaska Drilling #1 on drillsite. Prep to drive 20" conductor. February 4, 1998 Report #2 Drive 20" conductor to refusal at 90' RKB. Continue rigging up. Test rig systems. February 5, 1998 Report #3 Continue rig-up operations. Install 20" bradenhead on conductor. February 6, 1998 Report #4 Nipple up diverter system. Continue rig-up operations. February 7, 1998 Continue rig-up operations. Report #5 February 8~ 1998 Report #6 Continue rig-up operations. Hook up diverter line, bifurcation valve and hydraulic controls. February 9, 1998 Report #7 Function test diverter system. Continue rig-up operations. February 10, 1998 Report #8 Diverter system test witnessed by Chuck Sheave. Test ok. Continue rig-up operations. February 11, 1998 Continue rig-up operations. Report #9 February 12~ 1998 Continue rig-up operations. Report #10 February 13, 1998 Continue rig-up operations. Report #11 February 14, 1998 Report #12 Test lines, pick up 17 '/2" BHA, Drill 17 ½" hole to 372'. February 15, 1998 Report #13 Drill 17 ½" hole to 522', survey, drill to 546', POOH, change BHA. February 16, 1998 Report #14 RIH, drill 17 ½" hole to 638', survey, Drill to 732' survey, drill to 830'. February 17~ 1998 Report #15 Short trip, drill 17 ½" hole to 1,010', survey, drill to 1,055'. February 18, 1998 Report #16 Drill 17 I/2" hole to 1,102', survey, drill to 1,196', survey, POOH or BHA change, RIH, Drill to 1,219'. February 19, 1998 Report #17 Circulate at 1,219', POOH, Rig up casing equipment, RIH with 13 3/8" casing to 1,219', pump cement, un- sting, circulate. Forcener v Inc. Coffee Creek #1 Operations Summary February 20, 1998 Report #18 POOH w/drill pipe, nipple down 20" diverter, cut 13 3/8" casing, weld on head, test to 1800 psi- good test, nipple up BOPE, work on rig systems. February 21, 1998 Report #19 Work on solids control equipment. February 22, 1998 Report #20 Work on solids control equipment. February 23, 1998 Report #21 Continue working on solids control equipment, test BOPs - witnessed by AOGCC. February 24, 1998 Report #22 Continue rigging up solids control equipment. February 25, 1998 Report #23 RIH to 1167', circulate, test casing to 1500 psi - good test, circulate and condition mud, drill cement to 1170'. February 26, 1998 Report #24 Drill 12 IA" hole to 1240', Perform Leak off Test to 16.4 ppg EMW. Drill to 1399', survey, drill to 1618', survey, drill to 1664'. February 27, 1998 Report #25 Drill 12 ¼" hole to 1836', circulate, survey, short trip to shoe, drill to 1962', gyro on Sperry Sun, drill to 2274'. February 28, 1998 Report #25 Drill 12 %" hole to 2359', circulate, survey, short trip to shoe, circulate, drill to 2700'. March 1, 1998 Report #26 Drill 12 ¼" hole to 2772', survey, POOH for bit, RIH with new BHA, drill to 3054'. March 2, 1998 Report #27 Drill 12 lA" hole to 3275', survey, drill to 3369', short trip, drill to 3590'. March 3, 1998 Report #28 Drill 12 ¼" hole to 3746', survey, drill to 4032', circulate, short trip. March 4, 1998 Report #29 RIH to 4032', drill 12 ¼" hole to 4252', survey, drill to 4432'. March 5, 1998 Report #30 Drill 12 IA" hole to 4489', short trip, drill to 4740', POOH for bit. March 6, 1998 Report #31 Continue to POOH for bit, test BOPs, change out BHA, RIH, drill 12 ¼" hole to 4938'. March 7, 1998 Report #32 Drill 12 ¼" hole to 5066', survey, drill to 5126', survey, drill to 5215'. March 8, 1998 Drill 12 ¼" hole to 5465'. Report #33 Forcener v Inc. Coffee Creek #1 Operations Summary March 9, 1998 Report #34 Drill 12 IA" hole to 5473', survey, POOH, Change out BHA, RIH, Drill to 5502', survey, drill to 5544'. March 10, 1998 Report #35 Drill to 5644', circulate, survey, drill 12 ¼" hole to 5771' March 11, 1998 Report #36 Drill 12 ¼" hole to 5807', short trip, drill to 6030'. March 12, 1998 Report #37 Drill 12 IA" hole to 6097', circulate, survey, POOH, change out BHA,. RIH to 5525', Ream to bottom. March 13, 1998 Report #38 Drill 12 ¼" hole to 6326', weekly BOP test waved by Chuck Sheave. March 14, 1998 Report #39 Short trip, drill 12 ¼" hole to 6500', Shakers malfunctioning, POOH. March 15, 1998 Report #40 Repair shakers, RIH, drill 12 ¼" hole to 6600', circulate, drill to 6690' March 16, 1998 Report #41 Drill 12 ¼" hole to 6720', circulate, short trip to shoe, POOH, lay down 12 ¼" tools, test BOP, Rig up wireline. March 17, 1998 Report #42 Wireline log with triple combo (sonic failed), log FMS, log with sonic, RIH with 12 ¼" cleanout assembly. March 18, 1998 Report #43 RIH with 12 ¼" cleanout assembly, circulate, POOH, wait on tools, RIH. March 19, 1998 Report #44 Continue to RIH, Circulate, POOH, Rig up for 9 5/8" casing, Run 9 5/8" 47# casing to 4000'. March 20, 1998 Report #45 Run 9 5/8" casing to 6715', test cement lines, pump 187 sx 12.5 ppg lead cement, pump 204 sx 15.6 ppg tail cement, displace, bump plug, open DV valve, pump 446 sx of 12.5 ppg cement, displace, bump plug, close DV valve, rig down. Pick up BOP stack, set 9 5/8" slips w/100K, remove cut off, dress stub, nipple up tubing spool, test to 3000 psi, Nipple up BOP. March 21, 1998 Report #46 Nipple up BOP, test to 5000 psi (AOGCC witness waived), pick up 8 ½" cleanout assembly, tag up at 2397', circulate above DV collar. March 22~ 1998 Report #47 Test casing to 2000 psi, drill out DV collar and re-test to 2000 psi, both good tests, drill cement to 6677', test casing to 2000 psi (good test), clean out to 6686', POOH, run Gyrodata directional survey, run CBL and CET logs on wireline. March 23, 1998 Report #48 Continue running CBL and CET logs on wireline, RIH with Vam packer, unable to set, POOH, dress packer, RIH, drop ball, test packer, open sleeve, inject Class II fluids. Forcenerev Inc. Coffee Creek #1 Operations Summary March 24~ 1998 Report #49 Continue injecting, close sleeve, test to 2700 psi, shear out ball, POOH, run tcmp log on wir¢lin¢, RIH with 8 ½" assembly, condition mud, clean out casing, drill 20' of new hole, test formation to 16 ppg EMW (no breakdown), drill 8 ½" hole to 6840'. March 25, 1998 Report #50 Drill 8 ½" hole to 6853', pull to shoe, drill to 7060', short trip to shoe, drill to 7148' March 26, 1998 Report #51 Drill 8 ½" hole to 7227', survey, trip for BHA, drill to 7270'. March 27~ 1998 Report #52 Drill 8 ½" hole to 7321', survey, drill to 7623'. March 28, 1998 Report #53 Circulate, short trip, drill 8 ½" hole to 7788', circulate, survey, trip for new bit, test BOP, RIH, drill to 7795'. March 29, 1998 Report #54 Drill 8 ½" hole to 8265', circulate, survey, drill to 8280' March 30, 1998 Report #55 Drill 8 ½" hole to 8473', circulate, short trip to shoe (some flow and gas), circulate and weight up to 9.5 ppg, monitor well - no flow, POOH. March 31, 1998 Report #56 Trip for bit and BHA, RIH, drill 8 ½" hole to 8705'. April 1, 1998 Report #57 Drill 8 ½" hole to 8788', circulate, survey, drill to 8835', trip for bit and BHA, ream to bottom. April 2, 1998 Report #58 Drill 8 ½" hole to 9117'. April 3, 1998 Report #59 Drill 8 ½" hole to 9293', circulate, survey, drill to 9306', circulate, POOH, change BHA, RIH. April 4, 1998 Report #60 Continue to RIH, drill 8 ½" hole to 9436', short trip to shoe, drill to 9506'. April 5, 1998 Drill 8 ½" hole to 9758'. Report #61 April 6~ 1998 Report #62 Circulate, survey, POOH, laydown BHA, Test BOP, rig up wireline, Log triple combo with wireline. April 7, 1998 Report #63 Wireline log with dipmeter (no go), log with RFT (no go), log with VSP. April 8~ 1998 Report #64 Continue running VSP logs, rig down wireline, lay down BHA, RIH to 9748', circulate, POOH, RIH open ended w/mule shoe to 8400', circulate bottoms up. Forcenerev Inc. Coffee Creek #1 Operations Summary April 9, 1998 Report #65 Spot hi-vis pill, POOH to 7900', circulate, Rig up cement lines, pump 59 bbl of 15.8 ppg cement, POOH 8 stds, reverse out cement, POOH, RIH with cleanout assembly, tag cement at 7312', circulate bottoms up, drill cement to 7325', circulate. April 10, 1998 Report #66 POOH, sling casing to location with helicopter, rig up casing equipment, wait on daylight for helicopter operations. April 11, 1998 Report #67 Work on rig, wait on weather to continue helicopter operations. April 12, 1998 Report #68 Sling load remainder 7 5/8" liner, Rig up casing equipment, run 7 5/8" liner to 7288', circulate. April 13, 1998 Report #69 Pump 156 sx of cement, displace, bump plug, set hanger, set packer, reverse out contaminated cement, POOH, test BOPs, RIH with mill and scrapers, clean out cement to 7200', circulate, POOH. April 14, 1998 Report #70 Test BOPs - good test, test casing to 2000 psi, RIH with injection packer, inject Class II fluid, close sleeve and test to 2000 psi, release packer and pump out ball, POOH. April 15, 1998 Report #71 Continue to POOH, clean pits, work on rig. April 16, 1998 Report #72 Continue to clean pits, RIH with injection packer. April 17, 1998 Report #73 Inject excess Class II fluids, close port, test to 1000 psi, shear out ball, POOH, wait on water hauling to build brine system. April 18, 1998 Report #74 Suspend rig operations ~n order to repair road, secure well, crews sent home. April 19, 1998 Shut down for road repmr. Report #75 April 20, 1998 Shut down for road repair. Report #76 April 21, 1998 Shut down for road repmr. Report #77 April 22, 1998 Shut down for road repmr. Report #78 April 23, 1998 Shut down for road repmr. Report #79 April 24, 1998 Shut down for road repmr. Report #80 Forcenergy Inc. Coffee Creek #1 Operations Summary April 25, 1998 Report #81 Shut down for road repmr. April 26, 1998 Shut down for road repmr. Report #82 April 27, 1998 Shut down for road repmr. Report #83 April 28, 1998 Shut down for road repmr. Report #84 April 29, 1998 Shut down for road repmr. Report #85 April 30, 1998 Shut down for road repmr. Report #86 May 1, 1998 Shut down for road repmr. Report #87 May 2, 1998 Shut down for road repmr. Report #88 May 3, 1998 Shut down for road repmr. Report #89 May 4, 1998 Shut down for road repmr. Report #90 May 5, 1998 Shut down for road repmr. Report #91 May 6, 1998 Shut down for road repmr. Report #92 May 7, 1998 Shut down for road repmr. Report #93 May 8, 1998 Shut down for road repmr. Report #94 May 9, 1998 Shut down for road repmr. Report #95 May 10, 1998 Shut down for road repmr. Report #96 May 11, 1998 Shut down for road repmr. Report #97 May 12, 1998 Shut down for road repair. Report #98 Forcener v Inc. Coffee Creek #1 Operations Summary ..May 13, 1998 Shut down for road repair. Report #99 May 14, 1998 Shut down for road repair. Report #100 May 15, 1998 Shut down for road repmr. Report #101 May 16, 1998 Shut down for road repair. Report #102 May 17, 1998 Shut down for road repair. Report #103 May 18, 1998 Shut down for road repair. Report #104 May 19, 1998 Shut down for road repmr. Report #105 May 20, 1998 Shut down for road repair. Report #106 May 21, 1998 Shut down for road repmr. Report #107 May 22, 1998 Shut down for road repair. Report #108 May 23, 1998 Shut down for road repmr. Report #109 May 24, 1998 Shut down for road repair. Report #110 May 25, 1998 Shut down for road repmr. Report #111 May 26, 1998 Shut down for road repair. Report #112 May 27, 1998 Shut down for road repair. Report #113 May 28, 1998 Shut down for road repair. Report #114 May 29, 1998 Shut down for road repair. Report #115 May 30, 1998 Shut down for road repair. Report #116 Forcenergy Inc. Coffee Creek #1 Operations Summary May 31, 1998 Shut down for road repair. Report #117 June 1, 1998 Shut down for road repair. Report #118 June 2, 1998 Report #119 Prep rig for start-up, start up power, Test BOPs - witness waived by AOGCC, RIH with mule shoe on 4 ½" DP. June 3, 1998 Report #120 Mix brine on surface, displace mud with 9.3 ppg brine, POOH, RIH with injection packer, start injecting drilling mud from displacement. June 4, 1998 Report #121 Inject used drilling mud, clean pits, POOH with injection packer, laydown tools, RIH with mule shoe, rig up surface lines to filter brine. June 5, 1998 Report #122 Reverse circulate and filter brine, POOH with mule shoe, rig up test equipment, tools. June 6, 1998 Report #123 RIH with DST #1, correlate with wireline, make up test tree, set packer, rig up test lines and test to 5000 psi, pre-charge drill string with nitrogen, make repairs on test equipment, drop firing bar, flow well through choke down to 300 psi, shut in well. June 7, 1998 Report #124 Continue well shut-in for pressure build-up, open LPRN tester valve - 0 psi on drill string, pump 95 bbl of brine down drill pipe - drill pipe on vacuum, reverse out, recovered 45 bbl of contaminated brine, monitor well, shear IPO valve, rig down test tree and manifold, POOH with DST #1, laydown tools and guns, pick up 7 5/8" retainer and RIH to 6800', set retainer at 6800', un-sting from retainer, filter brine while circulating. June 8, 1998 Report #125 Continue circulating and filtering brine at 6800', stab into retainer, inject Class II fluids on rig, rig up cementing lines, test lines, pump 15.5 bbl of 15.8 ppg cement, displace with brine, un-sting to spot 2 bbl on top of retainer, POOH 2 stands, pump drill pipe wiper plug, hold 500 psi on well with annular preventer due to retainer leakage, release pressure on well, POOH to 5000', circulate and filter brine in hole. June 9, 1998 Report #126 Reverse circulate and .filter at 5000', RIH to 6050', circulate and tilter brine, adjust brine weight to 9.3 ppg, POOH, Test BOPs - witnessed by AOGCC, pick up DST #2. June 10, 1998 Report #127 RIH with DST #2, correlate on Wireline, rig-up test tree and lines, set packer at 5743',, test surface lines to 3000 psi, Pre-load string with nitrogen to 2000 psi, open LPRN, clear communication with the annulus, rig down test tree and manifold, POOH to Balance Isolation Tool. June 11, 1998 Report #128 Change out LPRN, Drain valve, Jars, and RTTS bypass valve, RIH with DST #2, rig up test tree and lines, test lines to 3000 psi, pre-charge nitrogen to 2000 psi, open LPRN, drop firing bar, guns fired, open choke, bleed down to 0 psi on tubing, close LPRN for 30 minutes, open LPRN, 0 psi on tubing, open bypass, unseat packer, monitor well, POOH, laydown DST tools, top shot at 5815', bottom at 5930'. Forcener v Inc. Coffee Creek #1 Operations Summary June 12, 1998 Report #129 Pick up 9 5/8" retainer, RIH, set retainer at 5785', test annulus, unable to inject into perforations, spot 248' of cement above retainer, POOH to 5100', reverse out 1.5 drill pipe volumes, pump drill pipe wiper plug, POOH, RIH with injection packer, tie into injection port at 4009' inject 477 bbl of Class II fluids, POOH with injection packer. June 13, 1998 Report #130 Continue to POOH with injection packer, RIH with 9 5/8" retainer, set retainer at 4415',, circulate brine to 9.3 ppg constant, POOH with setting tool, test casing to 2000 psi, perforate squeeze perfs on wireline at 4140' to 4142' and 4400' to 4402' with 4 spf., RIH with 9 5/8" retainer and set at 4180', rig up to perform squeeze, unable to circulate through perfs, pump 47 bbl of 15.8 ppg cement between retainers, un-sting and squeeze 19 bbls of 15.8 ppg cement above the top retainer, drop drill pipe wiper plug, hold 600 psi squeeze on cement for 1 hour. Estimated top of cement at 4078'. June 14, 1998 Report #131 Wait on cement with 600 psi for 2 more hours, bleed off pressure, monitor well - stable, POOH, laydown stinger and plug catcher, RIH with cleanout assembly, tag cement at 3960', drill cement to 4110'. June 15~ 1998 Report #132 Continue drilling cement to 4360', circulate, POOH, pick up casing scraper and junk basket, circulate hole clean, filter brine, clean cement cuttings from pits. June 16, 1998 Report #133 Continue cleaning pits, build brine volume, filter brine, reverse circulate clean 9.3 ppg brine, POOH, Pick up DST #3, RIH. June 17, 1998 Report #134 Continue RIH with DST #3, correlate with wireline, make up test tree, set packer, unseat packer, POOH with DST #3, change BHA, move packer below squeeze perfs, change from LPRN to Hydrospring tester valve, RIH with DST #3, correlate with wireline, set packer at 4195', make up test tree and manifold, test to 3000 psi. June 18~ 1998 Report #135 Pre-charge tubing with nitrogen, drop f'n-ing bar, bleed pressure down to 0 psi, POOH, firing bar had struck the Hydrospring tester valve, Change out tools, RIH with new DST #3. June 19~ 1998 Report #136 RIH with DST #3, correlate with wireline, make up test tree, open hydrospring valve, set packer at 4202', test surface lines to 3000 psi, pre-charge nitrogen to 1650 psi, dropped firing bar, bleed off pressure to 0 psi, annulus took 32 bbl in last 30 minutes of test,, release packer and allow gas to migrate to surface, POOH, laydown test tools, BOP test - witness waived by AOGCC. June 20~ 1998 Report #137 Continue testing BOP, make up DST #3 re-mn, RIH, set packer at 4125', test lines to 3000 psi, pre-charge nitrogen to 1250 psi, activate LPRN tool, bled pressure to 0 psi on string, shut in well for 90 minutes, open test string, 0 psi, unseat packer, POOH. June 21~ 1998 Report #138 Laydown DST #3, transfer fluid, RIH with 9 5/8" retainer, rig up mud lines and cement lines, continue transferring fluid. Forcener v Inc. Coffee Creek #1 Operations Summary June 22, 1998 Report #139 Continue transferring fluid, set retainer at 4100', test lines to 3500 psi, Inject Class II fluids in test perfs, pump 25.7 bbls of 15.8 ppg cement, un-sting from retainer, spot 1 bbl of cement, POOH 3 stds, reverse circulate 2 drill pipe volumes, drop drill pipe wiper plug, circulate, filter and weight up brine to 9.2 ppg, POOH, laydown running tool. June 23, 1998 Report #140 Pick up DST #5, RIH, correlate with wireline, make up test tree and surface lines, set packer at 2402', test surface lines to 3000 psi, pre-charge nitrogen to 950 psi, open choke, bleed pressure to 0 psi, shut in well, displace string with nitrogen, allow well to flow, little gas, shut in well, allow build up, unseat packer, allow gas to migrate, prep to POOH. June 24, 1998 Report #141 Monitor well for gas, POOH with DST # 5, laydown assembly, RIH with drill string to be laid down, laydown drill pipe and drill collars. June 25, 1998 Report #142 Laydown drill pipe, drill collars and jars, RIH with 9 5/8" retainer to 2454', displace brine with fresh water, set retainer at 2454', test cement lines to 3500 psi, inject 355 bbl of remaining Class II fluids, pump 26.4 bbl of cement, un-sting from retainer, lay last 8 bbl of cement on retainer, POOH 3 stands, drop drill pipe wiper plug, displace to bottom, POOH, laying down drill pipe and collars. Start loading out equipment for rig down operations. June 26, 1998 Report #143 Laydown drill pipe, RIH and set retainer at 150', laydown drill collars and drill pipe, nipple down BOP, cut off casing 3' below ground level, tag retainer at 150' with drill pipe, pump 12.3 bbl of 15.8 ppg cement, fill 9 5/8" x 13 3/8" annulus, POOH, top off pipe with cement (AOGCC witnessed). Weld plate over casing and attach a dry hole marker, release rig, commence rig down and demobilization. Coffee Creek #1 Single Shot Data 8 ~" Hole Depth - MD Inclination Azimuth 7245 ft 11 o 255 o 7742 ft 12 ½ o 245 o 8220 ft 12 ½ o 240 o 8720 ft 10 ½o 2620 9220 ft 6 ½ o 272 o 9722 ft 2 o 264 o A Gyroda t a D i r e c t iona i Survey for FORCE ENERGY INC. COFFEE CREEK, WELL NO. 1 MAT SU BOROUGH, ALASKA Job Number: A0398GMS446 Run Date: 21-Mar-98 23:45:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 61.200000 deg. N Sub-sea Correction from Vertical Reference: 620 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal 'Coordinates Calculated% from Local Horizontal Reference ORIGINAL A Gyroda t a Di re c t iona i Survey FORCE ENERGY INC. COFFEE CREEK, WELL NO. 1 MAT SU BOROUGH, ALASKA Job Number: A0398GMS446 MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700.0 1800.0 1900.0 2000.0 2100.0 2200.0 2300.0 2400.0 0.00 0.00 0.0 .23 268.48 100.0 .10 315.10 200.0 .55 348.47 300.0 1.03 345.24 400.0 1.34 337.56 500.0 1.41 329.10 599.9 1.20 323.15 699.9 .90 324.99 799.9 .99 321.55 899.9 1.35 320.74 999.9 1.00 315.61 1099.8 1.03 312.26 1199.8 1.13 314.77 1299.8 1.32 322.46 1399.8 1.57 325.15 1499.8 1.77 328.51 1599.7 1.89 331.67 1699.7 2.09 330.68 1799.6 2.56 332.08 1899.5 2.84 333.42 1999.4 2.96 332.45 2099.3 3.08 331..79 2199.1 3.25 331.92 2299.0 3.49 331.15 2398.8 DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 0.0 0.00 0.0 0.0 -.0 .23 .2 268.5 .1 .18 .5 276.4 .6 .47 .9 312.9 1.9 .48 2.1 333.6 3.9 6.0 7.9 9.4 10.7 12 13 15 16 17 20 22 25 28 31 .3 .8 .0 .3 .9 .0 .4 .2 .2 .8 .0 .5 .1 .0 .2 36 40 45 50 55 .35 4.2 337.2 .22 6.6 335.7 .25 8.8 333.3 .30 10.6 331.7 .11 12.3 330.6 .35 14.3 329.2 .36 16.3 327.9 .07 18.0 326.5 .11 19.9 325.3 .25 22.0 324.7 .27 24.5 324.6 .22 27.4 324.9 .15 30.6 325.4 .20 34.0 326.0 .48 38.1 326.6 .28 42.8 327.3 .13 47.8 327.9 .13 53.1 328.3 .17 58.6 328.6 .24 64.4 328.9 Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E .01 S .20 W .05 N .47 W .59 N .63 W 1.92 N .96 W 3.87 N 1.63 W 6.00 N 2.71 W 7.89 N 3.97 W 9.37 N 5.04 W 10.69 N 6.03 W 12.28 N 7.31 W 13.81 N 8.66 W 15.03 N 9.93 W 16.33 N 11.30 W 17.94 N 12.70 W 19.97 N 14.18 W 22.42 N 15.77 W 25.19 N 17.36 W 28.23 N 19.04 W 31.79 N 20.98 W 35.97 N '23.13 W. 40.48 N 25.43 W 45.13 N 27.90 W 50.00 N 30.50 W 55.17 N 33.30 W A Gyroda t a D i re c t i onal Survey FORCE ENERGY INC. COFFEE CREEK, WELL NO. MAT SU BOROUGH, ALASKA Job Number: A0398GMS446 MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet 2500.0 2600.0 2700.0 2800.0 2900.0 3000.0 3100.0 3200.0 3300.0 3400.0 3500.0 3600.0 3700.0 3800.0 3900.0 4000.0 4100.0 4200.0 4300.0 4400.0 4500.0 4600.0 4700.0 4800.0 4900.0 3.66 330.55 2498.6 3.80 326.79 2598.4 3.70 328.49 2698.2 3.91 328.32 2798.0 3.98 329.98 2897.7 4.06 328.64 2997.5 4.17 327.71 3097.2 3.88 324.50 3197.0 3.76 320.22 3296.8 3.53 320.26 3396.6 3.27 313.85 3496.4 2.93 312.79 3596.2 3.27 310.96 3696.1 3.68 309.39 3795.9 3.83 309.39 3895.7 3.87 311.30 3995.5 4.13 309.16 4095.2 4.32 309.02 4194.9 4.41 309.70 4294.7 4.40 307.66 4394.4 '4.46 307.39 4494.1 4.58 303.71 4593.8' 4.73 300.62 4693.4 4.66 298.94 4793.1 4.70 297.57 4892.8 60.6 66.2 71.7 77.3 83.2 89 95 101 106 111 115 119 123 126 131 135 139 144 149 154 158 163 167 171 175 .3 .4 .2 .5 .4 .7 .4 .0 .9 .1 .4 .9 .6 .4 .2 .9 .5 .8 .9 .7 DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 18 70.7 329.1 28 77.2 329.0 15 83.7 328.9 22 90.3 328.9 14 97.2 328.9 12 104.2 328.9 13 111.4 328.9 36 118,4 328.7 31 125.0 328.4 23 131.3 328.0 46 137.2 327.5 34 142.4 327.0 35 147.6 326.4 42 153.5 325.8 15 159.8 325.1 13 166.3 324.5 30 173.0 324.0 19 180.2 323.4 10 187.6 322.8 16 195.0 322.3 06 202.5 321.7 31 210.1 321.1 29 217.7 320.4 15 225.4 319.7 12 233.0 318.9 HORIZONTAL COORDINATES feet 60.61 N 36.34 W 66.17 N 39.73 W 71.69 N 43.23 W 77.34 N 46.70 W 83.25 N 50.23 W 89.27 N 53.81 W 95.37 N 57.59 W 101.20 N 61.50 W 106.47 N 65.56 W 111.36 N 69.63 W 115.70 N 73.65 W 119.42 N 77.59 W 123.03 N 81.62 W 126.94 N 86.26 W 131.09 N 91.32 W 135.44 N 96.44 W 139.94 N 101.76 W 144.59 N 107.49 W 149.42 N 113.37 W 154.21 N 119.36 W 158.92 N 1~5.49 W 163.49 N 131.89 W 167.81 N 138.76 W 171.87 N 145.86 W 175.73 N 153.05 W Page A Gyroda t a D i r e c t i ona 1' Survey FORCE ENERGY INC. COFFEE CREEK, WELL NO. 1 MAT SU BOROUGH, ALASKA Job Number: A0398GMS446 MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 5000.0 4.71 296.90 4992.4 5100.0 5.05 293.87 5092.1 5200.0 5.32 291.58 5191.6 5300.0 5.70 289.41 5291.2 5400.0 5.75 288.07 5390.7 179.5 .05 24017 318.2 183.1 .43 248.5 317.5 186.6 .34 256.8 316.6 190.0 .43 265.4 315.7 193.2 .14 274.4 314.8 179.49 N 183.13 N 186.61 N 189.97 N 193.17 N 160.35 W 168.03 W 176.37 W 185.37 W 194.82 W 5500.0 6.07 287.07 5490.2 5600.0 6.26 286.96 5589.6 5700.0 6.45 288.25 5689.0 5800.0 6.39 288.04 5788.3 5900.0 6.52 286.00 5887.7 196.3 .34 283.6 313.8 199.4 .18 293.2 312.9 202.8 .24 303.2 312.0 206.3 .06 313.5 311.1 209.5 .26 323.8 310.3 196.28 N 199.42 N 202.77 N 206.26 N 209.~55 N 204.64 W 214.91 W 225.46 W 236.09 W 246.84 W 6000.0 6.47 290.50 5987.1 6100.0 6.62 290.56 6086.4 6200.0 6.75 291.41 6185.7 6300.0 6.83 292.11 6285.0 6400.0 7.05 291.33 6384.3 213.1 .51 334.3 309.6 217.1 .15 345.1 309.0 221.3 .17 356.2 308.4 225.6 .11 367.5 307.9 230.1 .24 379.1 307.4 213.08 N 217.08 N 221.25 N 225.64 N 230.11 N 257.58 W 268.25 W 279.12 W 290.10 W 301.33 W 6500.0 7.48 291.38 6483.5 6600.0 8.02 291.41 6582~6 6680.0 8.44 291.08 6661.8 234.7 .43 391.3 306.9 239.6 .54 404.3 306.3 243.8 .52 415.4 305.9 234.71 N 239.63 N 243.78 N 313.11 W 3'25.67 W 336.34 W Final Station Closure: Distance: 415.39 ft Az: 305.94 deg. Page Forcenergy Itic 310 K Street, Suite 700 Anchorage, Alaska 99501 Phone: (907) 258-8600 Fax: (907) 258-8601 DATA TRANSMITTAL Date: June 30,1998 To" Howard Okland Alaska Oil & Gas Conservation Commission From: Barbara Kruk Forcenergy Inc. 3001 Porcupine Drive 310 K Street, Suite 700 Anchorage, AK 99501 Anchorage, AK 99501 Phone:(907)279-1433 x235 FAX: (907) 276 - 7542 Phone: (907) 258 - 8600 FAX: (907) 258 - 8601 TRANSMITTAL DESCRIPTION 1 - report - Borehole Seismic Report - Coffee Creek #1 - April 1998 Report from Schlumberger Velocity Survey Report Report include~-nclosures O Please sign below to acknowledge receipt. Received By: IReturned to Forcenergy Accepted By: Date: IDate cc#1 AOGCC.xIs Date Modified:6/30/98 Date Prepared: 2/19/98 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David jo~~ Chairmarf--~ DATE: June 24, 1998 THRU: Blair Wondzeil, ~ P. I. Supervisor FROM: Larry Wade, ~I~ SUBJECT: Petroleum Inspector FILE NO: .DOC P&A Forcenergy Coffee Creek #1 PTD 97-219 June 24,1998: I flew to Beluga and caught the chopper for Coffee Creek #1 at 0545. They were having trouble with the pumps. Finally got the drill pipe laid down and ran in to 150' and set an EZ drill. Nippled down the BOPs and slipped the drilling line. Cut the casing and conductor off at 3 feet below ground level. Ran back into the hole and laid in cement till we got returns at surface. POOH and laid in another bbi to compensate for drill pipe displacement. Welded on cap and dry hole marker. SUMMARY: Witnessed P&A of Forcenergy Coffee Creek #1. Attachments: cc; NON-CONFIDENTIAL STATE OF ALASKA ALASKA 0I£ AND GAS CONSERVATION COMMISSION Plug And Abandonment Report Operator: Forcener~l¥ Operator Rep.: Mike Murray Lease No.: Well No.: Total Depth: Date: 6/24/98 Well Name: Coffee Creek #1 PTD No.: 97-219 Sec. T-R Sec 19 T 14N R 10W Meridian: Seward Elevation: Mud Wt.: ppg. Ii CASING DATA: Drive Pipe: Conductor: Intermediate: 9 5/8" O.D." Set @: O.D." Set @: O.D." Set @: f. With f. Surface: f. Prodctn: 7" Penetration O.D." Set @: O.D." Set @: PLUGGING DATA: 1. Open Hole Plugs: 6800',5185,4415, 153' 7101 ft. 2. Open Hole Isolation Plugs: 3. Perforation Plugs: 4. Annulus Plugs: 5. Casing Stub Plugs: 6. Surface Plug: Casing Removal: REMARKS: 0-153' " Casing Cut @ Feet " Casing Cut @ Feet " Casing Cut @ Feet " Casing Cut @ Feet Distribution: orig - Well File c - Operator c - DNR/DOG c - Database c- Rpt File c - Inspector Inspector (s): Lawrence M.Wade FI--O00 (Rev. 3/93) d99gf~e.xls 06/24/98 ~YED 13:21 FAX 907 258 8601 FORCENERGY ALASKA Forcen Inc 97- 2t? June 24, 1998 Alaska Oil and Gas Conservation Commission Mr. Blair Wondzell 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Plug and Abandon Coffee Creek #1 Dear Mr. Wondzell This letter is to follow up our conversation on June 23r~ regarding P&A of our coffee Creek #1 well. We are planning to plug and abandon as per our discussion, as follows. All perforations below 4100' have been previously abandoned. Cement has been placed below and above a retainer at that depth. Clean out depth is 4082'. The perforations to be abandoned are from 2484'-2665'. We are setting a cement retainer at 2454' and squeezing 80 sx of cement below retainer and spotting 40 sx above retainer. We will then set a retainer at 150' and spot cement to the surface. We will co-ordinate transportation to have an AOGCC representative on location to witness any part of this procedure. I will submit a formal report on the P&A with-in the required time. Blair if you have comments please call me at 258-8600. ~ any questions or hank you very much, ~ 1'4,2_= Drilling Manager HEADQUARTERS REGIONAL OFFICE Forcenergy Center TELEPHONE TELEPHONE 2730 SW 3rd Avenue 305/856-8500 310 K Street 907/258-8600 Suite 800 FAX Suite 700 FAX Miami, Florida 33129-2237 305/856-4300 Anchorage, Alaska 99501 907/258-8601 06/24/98 ]~ED 13:21 FAX 907 258 8601 FORCENERGY ALASKA tt~]001 Forcenergy Inc 310 K Street, Suite 700 Anchorage, Alaska 99501 (907) 2!58-8600 258-8601' FAX FAX TRANSMITTAL SHEET DATE: FAX: FROM: Z7 L Phone: CONFIDENTIALITY NOTE: The Information in this facsimile transmittal ia legally privileged and confidential information Intended only for the use of the indlvldual or entity named above. If the reader of this message is not the intended recipient. you ere hereby notified that any dislemlnaflon, distr~utlen or copy of the transmittaJ is strictly prohibited. If you receive this transmittal in error, please immediately notify us by telephone, and tatum the original transmfttal to ua at the above address via the United States Postal Service. Thank you. FAXALA.DOC ?JI 1/97 MESSAGE' ]998 MEMORANDUM State of Alaska TO: .... Alaska Oil and Gas Conservation Commission David John~ DATE: June 8, 1998 Chairman THRU' Blair Wondzeli, ~ FILE NO: P. I. Supervisor am9kfhfe, doc FROM' Chuck Scheve, 4. ~ SUBJECT: Petroleum Inspector BOPE Test SAD! Rig #1 Coffee Creek #1 PTD 97-219 Monday June 8~ 1998; i traveled to the Forcenergy Coffee Creek #1 Well and witnessed the weekly BOPE test on Sterling Alaska Drilling's Rig 1. As the attached AOGCC BOPE Test Report shows there was 1 failure. The kill line HCR valve failed to pressure test. Two manual valves were in place and tested good so immediate repairs were not required. The Rig in general appeared to be in good condition. The location is very crowded and extremely soft and muddy but all things considered well organized. Summary; I witnessed the weekly BOPE test on the Sterling Alaska Drilling Rig 1 drilling the Forcenergy Coffee Creek #1 well. SADI #1, 618198, TEST TIME 4 HOURS, 1 FAILURE Attachment: am9kfhfe.xls , .,X Unclassified Confidential (Unclassified if doc. removed ) STATE OF ALASKA ..... OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: DATE: SADI Rig No. 1 PTD # 97-219 Rig Ph.# Force ne r~ly Rep.: ,. Mike Murray Coffee Creek #1 Rig Rep.: Mike Leslie Set @ Location: Sec. 19 T. Weekly X Other f 4N R. lOW Meridian Seward MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes Test Pressure P/I= FLOOR SAFETY VALVES: Quan. Upper Kelly / IBOP , ~ Lower Kelly / IBOP Bali Type '! Inside BOP Well Sign OK Drl. Rig OK Hazard Sec. Yes BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves f HCR Valves 2 Kill Line Valves Check Valve Test Press. P/F 250/2500 1 25O/5, O00 I 250/5,000 250/5,000 250/5,000 2 250/5,000 F/P CHOKE MANIFOLD: No. Valves 10 No. Flanges 20 ,, Manual Chokes Hydraulic Chokes 1 Test Pressure 250/5,000 250/5,000 Functioned Functioned P/F P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 19 sec. Trip Tank OK OK System Pressure Attained 2 minutes 35 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: OK Remote: OK Flow Indicator OK OK Nitgn. Bti's: 4~2300 Meth Gas Detector OK 'oK' P~g. H2S Gas Detector OK OK 3000 ! ,, 165ot NUmber of Failures: 1 ,Test Time: 4~0 Hours. Number of vanes tested 13 Repair or Replacement of Failed Equipment will be made within ~'ays. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No, 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. i. Supervisor at 279-1433 III I I I I II I I I I I REMARKS: I~'11 line HCR failed to pressure test. Two manual valves were in place and tested. Repairs will be made to HCR when t~me permits. Distribution: odg-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector FI-021L (Rev.12/94) 'S~ATE WITNESS REQUIRED~ YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: v~r(messed By: am9kfhfe Chuck Scheve THU 09:38 FAX 907 258 8601 FORCENERGY ALASKA ~_j. ool 06/04/98 -. Forcenergy ino ~ 310 K Streot, Suite 700' Anchorage, Alaska; 995..0'I (907) 258-8600 258-8601: FAX FAX TRANSMITTAL.SHEET' PAGES TO FOLLOW, TO: , Phone: ,2,, 7,~'- / ~'~-3 I CONFIDENTIALITY NOTE: The Information In this faeslnuqe transmittal is lagallt~ prlvile~led and_confidential [nformation ~ for the use of the Indlvldual or entity named above. If the reader of this message Is not the Intended reclplent, you are hereby noafled that any d~saernlnatton, distribution or copy of the transmittal la strictly prohibited. If you receive tl~s transmittal In ewer, please imme~ately notify us by telephone, and return the original transmittal to us at the above address via the United States Postal 8ere{ce, Thank you. ,_ FA.XA/..A,~ ~'11/97 MESSAGE: · 1998 AlalkaOil&GasCons. P~ 06/04/98 THU 09:38 FAX 907 258 8601 FORCENERGY ALASKA ~002 Force ergy Inc June 4,1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Attn: Mr. Blair Wondzell Re: Coffee Creek #1 Mr. Wondzell We would like to notify you at this time of our commencement of the Coffee Creek #1 DST program. We will be performing five separate Drill Stem Tests, starting from the lowermost zone and working up. Each zone will be properly abandoned upon completion of the individual DSTs, unless it looks like a potential production zone. The intervals being tested are on a separate sheet attached to this letter. As seen by the attached well schematic, there is no cement at the depths of tests #3 and ~4. We will be performing circulation squeezes pdor to testing these two intervals. If there are any questions, please contact me at 907-258-8600. Rob Stinson Drilling Engineer Forcenergy Inc. JUN 0 1998 \~FGEANCI-I~SYSV~CCT~RSTINSON~-.offee Ck #1\Wondzell Test. doc Date Modified: 6/4/98 Date Prepared; 6/4t98 HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 Miami, Florida 33129-2237 TELEPHONE 305/856-8500 FAX 305/856-4300 REGIONAL OFFICE 310 K Street Sufl:e 700 Anchorage, Alaska 99501 TELEPHONE 907/258-8600 FAX 907/258-8601 06/04/98 THU 09:38 FAX 907 258 8601 FORCENERGY ALASKA ~003 Test #1 Test #2 Coffee Creek #1-Perf Intervals for Testing Net Base Top Footage 6983 6945 38 6929 6924 5 6912 69O9'3 6896 6891 5 6885 6883 2 6876 6862 14 6852 6835 17 84 Gross Test interval ... 148 5930 5906 24 5835 5831 4 5821 5815 6 34 115 Test #3 4325 ' 4302 23. 4285 4253 32 55 72 Test Test #5 3184 3132 52 2665 2645 2O 2631 262t 10 2548 2521 27 25O8 2484 24 81 Total Shot Footage 3O6 52 181 06/04/98 THU 09:38 FAX 907 258 8601 FORCENERGY ALASKA ~004 Coffee Creek #1 20" 133#, L-80 13 3/8" 68#, L-80 BTC 90' TOC 1160' 1219' · DV Collar 2812' Ported Collar 4013' TOC 5260' 9 5/8" 47#, L-80 BTC 6720' 7-5/8" 29.04#,. L-80 FL4S 7200' 1998 Almka Oil & GasCees. C~ ,. 06/04/98 THU 09:53 FAX 907 258 8601 FORCENERGY ALASKA Forcenergy Ino 310 K Street, Suite 700 · Anchorage, Alaska= 99!501 (9d7) 258-8600 268-8601: FAX FAX TRANSMITTAL.SHEET' DATE.: 6~'/7"-,,~. PAGES TO FOLLOW ,/O TO: ,1 i i , ill il , i FAX: I CONFIDENTIALITY NOTE: The lafmmatlon In this facsimile transmittal is legally mivileaed and e.onfidenfi, af in.form'.p, tion. j _Intended a[n.l¥ for the use of the Individual or entity named above. If the ~eader ef rids me~ge Is not the Intended recipient, you are hereby notified that any dissemination, d~stdbufion or cap¥ af the trensmlttM la ~trietly prohibited. If you receive this transmittal In error. I~ea~e im~ed~ate{y notify us by telephone, and return the original traf~al to us at the above address via the United States Postal Service. Thank you. .. F AX.A/_A.IZ~ 2/I MESSAGE' .,~,'~,-e ]998 Ala~a 0il & ~sCon$. Comml~ 06/04/98 THU 09:53 FAX 907 258 8601 FORCENERGY ALASKA ~002 COFFEE CREEK #1 Testing Procedure t998 05/13/98 R~v (3) 06/04/98 THU 09:53 FAX 907 258 8601 FORCENERGY ALASKA ~003 Test Objective: Determine producibility of potential hydrocarbon bearing zones. Dctennine initial reservoir pressure, permeability, skin factor and investigate areal extent of reservoir within the allotted flow time. Collect surface gas samples for compositional analysis. Equipment Discussion Surface Test Equipment: The equipment intended for flow testing the wells includes a 1 OK surface test tree, 5K surface safety valve, data header, choke manifold, combination heater/separator unit, vertical gas scrubber, two 400 BbI upright tanks and two gas stacks. An eleetroniC sand detector will be used immediately upstream of the choke manifold to monitor any sand production. The safety system with include hi/low pressure shutdowns on the heater, separator and vertical separator, hi.romp shutdown on the heater, hi/low level shutdowns on the separator and vertical separator in addition to manual emergency shut down panels on the fig floor, at the heater/separator, taz~k farm and at the location of the diverter valves on the gas line, LEL detectors will be positioned at the base of both gas stacks, the heater/separator unit, the tank farm, the. rig and at other locations specified by the SECORP. Drill Stem Test Tools: The DST string is intended to simplify the test process. A 9 5/8" RTTS II will be used as a test packer. Above the packer will be a safety joint, jars, bundle carrier with two electronic memory recorders programmed to collect data during the testing sequence, a LPR-N tester valve and internal pump out (IPO) sub for a reversing valve. The LPR-N operates by applying pressure to the annulus and is normally closed. Applying approximately 1500 psi to the annulus opens the tool - bleeding the annulus to 0 psi closes the tool. Applying internal pressure to the drill string opens the IPO sub. Normally the tool is set to open at 2000 psi which should be sufficient for this test. Perforating Guns: 4 5/8" 12 spfTCP guns are recommended in order to reduce the drawdown across the sandfaee and reduce the possibility of flowing sand into the wellbore. The guns will use a mechanical firing head and be fired with a drop bar. By abandoning the lower zone with a EZSV bridge plug set 10 feet below the zone being tested, correlation logging of the guns can be avoided. The guns can be placed on depth by tagging the bridge plug and picking up the required distance. 05/13/98 2 Rev (3) 06/04/98 THU 09:54 FAX 907 258 8601 FORCENERGY ALASKA ~004 . o 4, . Clean pits, disposing of any solids from drilling in a cement slurry, in the same manner that cuttings were handled while drilling the well. Prepare approximately 800 bbl of fresh water for displacement. Run in hole with a easing'scrapper. Displace mud in hole with water. Mix NaCI into water to a brine weight'of 9.4 ppg. 6. Pull out of hole. 8~ Run in hole with Tam injection tool. Open port collar and inject any remaining mud left over from the changeover to brine. 9. Close port collar and test to 3,000 psi. POOH with injection tool. 10. RIH open ended to TD. Circulate and filter brine. 11. Rig-up Halliburton, Dowell and Seeorp testing equipment. 12. Perform DST Test #1 as per the attached procedure. 13. 14. 15. 16. 17. 18. 1998 If well Test #1 looks promising, set a Halliburton EZSV retaifier 30' above the top perforated interval, unlatch from the retainer and displace enough cement to come back up 80 ft above the retainer. If well Test #1 does not look good, abandon the lower section per AOGCC requirements. Set a retainer at 6,800 feet and pump enough volume of cement to squeeze to 100' below lowermost perforations. Perform DST Test #2 as .per attached procedure. If well Test #2 looks promising, set a Halliburton EZSV retainer 30' above the top perforated interval, unlatch from the retainer and displace enough cement to come back up 80 ft above the retainer. If well Test #2 does not look good, abandon the perforations per AOGCC requirements. Set a retainer at 5,785 feet and pump enough volume of cement to squeeze down to 100' below the lowermost perforations. Set retainer at 4,415 feet. O 05/13/98 3 Rev (3) 06/04/98 THU 09:54 FAX 907 258 8601 FORCENERGY ALASKA ~005 19. Perforate from 4,400 feet to 4,402.feet and from 4,140 feet to 4,142 feet with 4" - 4 spf guns on wireline. Use a lubricator during this operation. 20. Run in hole with retainer 21. · Set retainer at 4,180 feet. 22. Establish circulation through perforations. 23. Pump 36 bbls of squeeze cement. 24. Unlatch from retainer 25. Pick up 20 feet. 26. Pump 5 bbls of cement. Pump down drill pipe wiper dart. 27. Perform a hesitation squeeze to lock-up. 28. Pull out of hole. 29. 'Run in hole with cleanout assembly and cleanout tO 4,380 feet. 30. Filter brine to clean up cement contamination. 31. Run CBL and CET logs, unless good circulation was established through the perforations before cement was pumped. 32. Perform DST Test #3 as per attached procedure. Note: set test packer above the top squeeze perf. 33. If well Test #3 looks promising,, set a Halliburton EZSV retainer 30' above the top perforated interval, unlatch from the retainer and displace enough cement to come back up 80 ft above the retainer. 34. If well Test #3 does not look good, abandon the perforations per AOGCC requirements. Set a retainer at 4,223 feet and pump enough volume of cement to squeeze down to 100' below the lowermost perforations. 35. Set retainer at 3,215 feet. 36. Perforate from 3,200 feet to 3,202 feet and from 2,960 feet to 2,962 feet with 4" - 4 spf guns on wireline. Use a lubricator during this operation. 37. Run in hole with retainer O 05/13/98 4 Rev (3) 06/04/98 THU 09:54 FAX 907 258 8601 FORCENERGY ALASKA ~006 38. Set retainer at 3,000 feet. 39. Establish circulation through perforations. 40. Pump 33 bbls of squeeze cement. 41. Unlatch from retainer 42. Pick up 20 feet. 43. Pump 5 bbls of cement. Pump down drill pipe wiper dart. 44. Perform a hesitation squeeze to "lock-up" 45. Pull out of hole. 46. Run in hole with cleanout assembly and clean out to 3,180 feet. 47. Filter brine to remove cement contamination. 48. Run CBL and CET logs, unless good circulation was established through the -perforations before cement Was pumped. 49. Perform DST Test fi4 as per attached procedure. Note: set test packer above the top squeeze perf. 50. If well Test #4 looks promising,, set a Halliburton EZSV retainer 30' above the top perforated interval, unlatch from the retainer and displace enough cement to come back up 80 ft above the retainer. 51. If well Test fi4 does not look good, abandon the perforations per AOGCC requirements. Set a retainer at 3,102 feet and pump enough volume of cement to squeeze down to 100' below the lowermost perforations. 52. Perform DST Test # 5 as per attached procedure. 53. Run completion or abandon well as per Forcenergy's drilling department's 'instructions. JUN 0 4 t998 ~ Oil & Gas Cons. Com,,ni~i~ O 05/13/98 5 Rev (3) 06/04/98 THU 09:55 FAX 907 258 8601 FORCENERGY ALASKA ® Drill Stem Test Procedure (DST//1 Only) . o MU Perforating and Drill Stem Testing tool string as follows (refer to attached diagram). · Perforating guns to perforated the following interval (bottom to top): 6983 - 6945 6929 - 6924 6912 - 6909 6896 - 6891 6885 - 6883 6876 - 6862 6852 - 6835 · Model IID Mechanical Firing Head · 2 7/8" x 4' Heavy Wall tubing sub with 1.56" No Go · 30' - 2 7/8" Tubing · · 2 7/8" BIT · 30' - 2 7/8" Tubing · 7 5/8" Champ HI Packer · VR Safety Joint · Big John Jars · One stand 4 ~/4" drill collars · Bundle Carrier w/two Halliburton Memory Recorders · Drain Valve · LPR-N Tester Valve · 3 7/8" CAS pin x 3 1/2" IF box crossover · IPO Reversing Valve · 3 1/2" IF pin x 4 ¼" FH box crossover · 4 ½" Drill Pipe to surface · 4 ¼" FH pin x 4 ½" IF box crossover · Surface Test Tree · 4 W' IF pin x 4 lA" FH crossover ', 15' 4 lA' FH pup joint · TIW Valve RIH with 4 V2" DP to measured depth of top shot. Assembly below LPR-N tester valve will fill with completion fluid through BIT while GIH. Drill string above tester valve will be run dry. RU wireline and run GR/CC1 to correlate guns on depth. 05/13/98 6 Rev (3) 06/04/98 THU 09:55 FAX 907 258 8601 FORCENERGY ALASKA ~008 , . o , . 10. 11. 12, 13. 14. 15. 16. 17. 05/13/98 POOH and rig down wireline. Space out using pup joints to place top shot at a depth of 6,835 feet and have top of drill pipe as close to the floor as possible. Set packer with ¼ mm to the right (at the packer) and slack off25,000#. .RU test tree (with bar drop lubricator) and MU lines to test tree and kill pump. Close lower valve on test tree. Open swab valve. Ensure TIW valve is closed. Pressure test surface equipment as follows. (Note: Pressure testing of equipment downstream of choke manifold and all test equipment can be done prior to this point to save time.) · Pressure test tree, surface lines to choke manifold and choke manifold to 5000 psi. · Pressure test flow lines and heater to the front of the separator to 2500 psi. · Pressure test separator and liquid lines downstream of separator to tanks to 500 psi. · Pressure test gas line to stack to 50 psi (can be done with air) Blow all lines to tanks With rig air. Open lower master valve. Close swab valve. Load drop bar in lubricator on top of swab valve. Ensure TIW valve is closed. RU and pressure drill string above tester valve with N2 to X, XXX psi to establish desired underbalance. Close lower master valve on tree. RD N2. Hold safety meeting to discuss test procedures, contingency procedures and personnel responsibilities. Shut down all sources of ignition not needed for testing. Close choke manifold valves. Open lower master valve. Open wing valve to equalize lines to choke manifold. Check wellhead pressure to ensure desired pressure. Pressure annulus to +/- 2000 psi to open LPR-N tester valve. Ensure positive indication of tester valve opening by monitoring tubing pressure or using shot · detection device. Drop bar to fire guns by opening swab valve. Guns will fire in 1 to 2 minutes. After guns have fired open choke manifold to flow on the adjustable choke. Maintain pressure at 100 to 200 psi below initial wellhead pressure by opening choke as N2 bleeds off. A higher drawdown to formation increases the possibility of flowing sand into the weUbore. JUN 0 4 1998 Rev (3) 06/04/98 THU 09:55 FAX 907 258 8601 FORCENERGY ALASKA ~009 18. Flow well for 30 minutes. Bleed annulus pressure to 0 psi to close LPR-N tester valve. Leave well shut in for 60 minutes. 19. Reopen well to flow by pressuring annulus to 1500 psi. Flow well at stabilized rate for 6 hours. Do not exceed a total produced gas rate of XX MMSCF. 20. Bleed annulus pressure to 0 psi to close LPR-N tester valve. Leave well shut in for 12 hours. 21. Optional Flow Period. Reopen well to flow by pressuring annulus to 1500 psi. Stabilize flow at same rate as extended flow period. Perform step rate test as follows: Flow well for 30 minutes. Reduce flowing pressure 25% by decreasing choke setting. Flow well for 30 minutes. Reduce flowing pressure by 25% by decreasing choke setting. · Flow well for 30 minutes. Reduce flowing pressure by 25% by decreasing choke setting. · Flow well for 30 minutes, 22., If desired, open well to flow maximum rate allowable per sand production and produced gas volumes. 23. 24. Bleed annulus to 0 psi to shut well in at LPR-N tester valve. Bleed off pressure in drill string through test equipment. Load drill string with XX Bbls NaC1 brine. Pressure drill string to 2000 psi to open IPO valve. Note: This is a one-time tool - once it is open it cannot be re-closed. 25, Reverse out two robing volumes to kill well, 26. Unseat packer. Check to ensure well is dead. 27. POOH, Laydown tools and cheek guns for all shots fired. 05/13/98 rD 8 Rev (3) 06/04/98 THU 09:56 FAX 907 258 8601 FORCENERGY ALASKA ~010 Coffee Creek #1 Welltest #1, Rev. I Test Goals: Determine deliverability, reservoir pressure, kit, and skin factor. Distinguish between tufoulent and mechanical skin Zone of interest: 6835' -6983' Reservoir Pressure: 3230 psig Calculated WHSIP: 2570 psig Perforations: 6983'-6945', 6929'-6924', 6912'-6909', 6896'-6891', 6885'-6883', 6876'-6862', 6852'-6835'; 12 SPF; 84' net/148' gross. UlUasoni¢ sand detector ia surface piping. 4.5" aria pipe test string. Continuous reconling of wellhead pressures and tempomtures, and of gas and liquid rates. Fluid level monitoring equipment. . , 10. 11. 12. 13. 14. Run nitrogen Perfonite tubing convoyed, undgrbalanced, with downhole tool op~x, and surface shut itl Monitor fluid level and pressures. Gradually open ~rface to maimain desired dmwdown. Flow well for 30 minutes. Shut well in at with downhole tool. Allow initial BHSIP to sMbilize for I hour. Gradually open well to flow, gradually inca~asing flow to maximum rate of 10 MMCFPD or 20% drawdown or onset of sand production. Stack gas to atmosphere. Contimmusly monitor sand productiou. If flow rotes are limited, such th~_ steady flow rates cannot be expected at lower drawdowns, this initial drawdown may be increased gradually, to 30°A If sand production occurs, back off flow rate unill sand production ceases. Once rate has stabilized, flow well at stabilized rate for 6 hours. Collect gas romp. le near end of flow period for gravity measuremmt and chemical analysis, Shut well in using bottom hole shut off for pressure buildup equal to 1.5 times total flow period above (i.e. Steps 4 flu~ugh 7). Open bottom hole shut off to begin step rate tests. Flow period #1: Flow at initial rote used above. Flow at stabili2ed rate for 3 hours, For each flow period plot log Q vt, lo§(WHSI~-WHFP~). Two to three ~v¢ flow p~ods are required. Three or more data points should plot in a stmi~ line - if not, it is an indication that fluid levels in wellbore are changing. Testing is invalid as long as fluid levels are changing. Slope of straight line should be between 0.5 (fully turbulent flow) and 1.0 (full laminar flow). If not possible to prevent liquid loading or unloading of wellbore, Isochronal testi'ng will be require& Flow period #2: Decrease drawdown by 5°Aage-po~ or ¼ of total drawdown and allow well to flow for 3 hours. Plot log Q vs. log(WHSl~-~). Flow period #3: Decrease drawdown by 5%age-points or % of tolai drawdown and allow well to flow for 3 hours. Plot log Q vs. log (WHSI~-WHFP:). Flow period g4: De~rease drawdown by 5%age-points or % of total drawdown and allow well to flow for 3 hours. Plot log Q vs. Iog(WI-ISI~-WHFPI). NOTE: Measure GLRs during flow period~ If GLRs change, additional flow laxiods are required such that two or three flow periods with stabilized GLRs are obtained for analysis. 15. 16. 17. 18. Verify that plot of backpressure test d~a provides valid estimate of deliverability and bac&pressm, e exponent and coefficient. Detemfine whether additional flow periods are required. Collect gas sample near end of last flow period for gravity measurement and chemical analysis. With bottom-hole shut-off tool, shut-in well for 24 hour presmn~ buildup. Retrieve BlIP gauge. END Reservoir/Evaluation Engineer/// 0 KWC~J:\Coffo~ C~k\CC# 1 WelltesOtl FinslAoc ' O~OID8 Forcenergy inc Alaska Division May 12, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska, 99501 Dear Sir or Madam: Enclosed, find the following final logs for the Forcenergy Coffee Creek #1 Well Item LIS Format of final merged logs SHDT MSD & Hand Picked Dips BHC Sonic/Gamma Ray 1 Dipmeter/Gamma Ray (Run 1) 1 Phasor Induction-SFL/GR 1 Repeat Formation Tester 1 Lithodensity/Comp Neutron/GR 1 Mud Log Blueline Reproducible Tape 1 Plot Sincerely, Richard V. Nelson, Jr. Petroleum Geologist ~ /, I it Received C:\WlN DOWS~Personal~OGCCLogTransmittalCC.doc Date: Date Modified: 5/12/98 Date Prepared: 5/12/98 ITl Forcenergy Inc Alaska Division May 12, 1998 Mr. Robert P. Crandall Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska, 99501 Dear Sir: Forcenergy completed ddlling operations at our Coffee Creek #1 well after ddlling to 9,757 feet, logging and plugging back to 7,325 feet and setting a 7 5/8" liner to 7,288 feet. After setting the liner, we suspended dg operations because of the deteriorating condition of our access road. We have identified five general zones to test when we have the necessary equipment and supplies at the dg location. A bdef summary of those zones and the general hydrocarbon potential of the well is enclosed. Analysis of mud logs and openhole logs reveal no evidence of liquid hydrocarbons in this well. Forcenergy will be requesting from ADEC a reduction of the Oil Spill Plan Response Planning Standard to zero, based on the results of ddlling and well log data, both of which indicate no evidence of liquid hydrocarbons in the well. We are requesting your concurrence with this conclusion. The purpose of this request is to facilitate testing of the well and to eliminate a requirement that we have demonstrated to be unnecessary. I have delivered the State's set of well logs so that you will have them available. Thanks for your time. Sincerely, Richard V Nelson, Jr. Petroleum Geologist C:\W1N DOWS\TEMP~RoadTest2.doc Date Modified: 5/12/98 Date Prepared: 5/12/98 kg 06/04/98 TItU 09:38 FAX 907 258 8601 FORCENERGY ALASKA OO3 Test #1 Test #2 Coffee Creek #1 ,Perf Intervals for Testing Net Base Top Footage 6983 6945 38 6929 6924 5 6912 6909 3 6896 6891 5 6885 6883 2 6876 6862 14 6852 6835 17 84 GROSS Test interval 148 5930 5906 24 5835 5831 4 5821 5815 6 34 11'5 Test #3 4325 ' 4302 23, 4285 4253 32 55 72 Test ~4 3184 3t32 52 52 Test #5 2665 2631 2548 2508 2645 2O. 2621 10 2521 27 2484 24 81 181 Total Shot Footage 306 06/04/98 THU 09:38 FAX 907 258 8601 { FORCENERGY ALASKA 004 Coffee Creek #1 20" 133#, L-SO 13 3/8" 68#, L-80 BTC TOC I160' 1219' DV Collar 2812' Ported Collar 4013' TOC 5260' 9 5/8" 47#, L-80 BTC 6720' 7-5/8" 29.04#,. L-80 FL4S 7200' 1998 Alaska0il&Gas(2m, ~ ,, O Hydrocarbon Potential Of Coffee Creek #1 The general zones of interest on electric logs for this well are: 2,448'-2,665'; 3,132'-3,184'; 4,253'-4,325'; 5,815'-5,930'; 6,835'-6,983' Formation wise, the top of the Tyonek is at about 700' and the Tyonek unconformably overlies probable Wishbone or Chickaloon (older Tertiary) rocks at about 7,000'. Preliminary age dating would place the Tyonek from 6,000' to 7,000' to be roughly equivalent to the Tyonek just above the top of the Granite Point oil pay at Granite Point. The well probably bottomed in the older Tertiary sands and conglomerates. Mud Log Examination Mudlogging was done from surface casing to TD by Epoch Well Logging, Inc. Samples were collected in 30-foot intervals and ali samples were examined on site. No oil shows were reported at any depth in the well. The first traces of C2 were noted just above 3,500' and the first C3 was logged at 4,700'. Nothing heavier than C3 was observed anywhere in the well. Below 7,000' the gas levels dropped of appreciably, except for one incidence of wiper gas that probably came from a coal at 7,800'. The mudlog would strongly suggest that no significant liquid hydrocarbons were encountered in the Coffee Creek #1 Well. Electric Logs In the interval 2,484-2,665, the sands appear relatively lithic and have a reaction almost like that in the Beluga River gas sands. There is minor cross over on the Density-Neutron curves through the zones showing resistivity and relatively Iow water saturations but considerable separation between the curves in the higher water saturation zones. The zone from 3,132-3,184 similarly shows cross-over to very little separation between density and neutron curves where resistivity in the sand is greater than ten ohms but considerable separation in the Iow resistivity sands. The interval from 4,253-4,325 has very similar density-neutron separation, porosities and resistivities to the Upper Tyonek gas zones below 5,400' in the Lewis River lA well. From 5,815 to 5,930, is a zone of contrasting high and Iow resistivities that appear to be gas on salt water. In the higher resistivity zone the density and neutron curves again almost overlie one another but in the Iow resistivity zones they show considerable separation. The Final interval from 6,835 to 6,983 shows thin zones of cross-over between the density and neutron curves and good resistivities in thin sands. The lack of visible hydrocarbon shows, the lack of heavy gasses on the chromatography log and the general response of the logs all suggest that if this well flows hydrocarbons at all, they will only be gas. Preliminary age dating by Dick Curry in Dallas, Texas (Formerly ARCO) suggests that the bottom of the zones of interest in this well are probably just above the top of the oil in the Granite Point Field and just above the first oil shows seen at Ivan River. Forcenergy Inc Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Blair Wondzell Re: Coffee Creek #1 - Well Operations Shutdown Mr. Wondzell This is an Application for Sundry Approvals (form 10-403) for the temporary shutdown of well operations on Forcenergy's Coffee Creek #1 well. This is follow-up to your verbal approval on April 17, 1998. The road which was constructed to the ddllsite was intended for winter travel. It has deteriorated to the point of being impassible. We decided that the best course of action was to temporarily shut down well operations and allow the road crews to propedy repair the road. As soon as this is complete, the testing program on Coffee Creek #1 will begin. The well is currently secure, with a liner cemented in place, mud in the hole and the blind rams closed. We expect to be crewing up on or around May 1, 1998 to test the well. If there are any questions, please contact me at 907-258-8600. Drilling Manager Forcenergy Inc. Date Modified: 4/21/98 Date Prepared: 4/21/98 pc HEA~~~utd°wn-d°c Forcenergy Center 2730 SW 3rd Avenue Suite 800 Miami, Florida 33129-2237 TELEPHONE 305/856-8500 FAX 305/856-4300 REGIONAL OFFICE 310 K Street Suite 700 Anchorage, Alaska 99501 TELEPHONE 907/258-8600 FAX 907/258-8601 STATE OF ALASKA ALASKA Oii:: AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation Shutdown: X Re-enter suspended well: · Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved prOgram: Pull tubing: Variance: Perforatei Other: 2. I~ar~e of Operator 5. Type of well: 6. Datum elevation (DF or KB) Forcenergy Inc. Development: 620' KB feet 3. Address Exploratory: X 7. Unit or Property name ,,, 310 K Street, Suite 700 Stratigraphic: Coffee Creek Anchorage, Alaska 99501 Service: 4. LoCation of well at surface ' 8. Well number 527' FWL 710' FSL Sec 19 T14N R10W #1 At top of productive interval 9. Permit number 527' FWL 710' FSL Sec 19 T14N R10W 97-219 , At effective depth 10. APl number 527' FWL 710' FSL Sec 19 T14N R10W 50- 283-20094 At total depth 11. Field/Pool 527' FWL 710' FSL Sec 19 T14N R10W Wildcat 12. Present well condition summary Total depth: measured 7,200 feet Plugs (measured) true vertical 7,200 feet ~PR 211998 Effective depth: measured feet Junk (measured) i1~~ & ~lSC~l~i~., true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 90' 20" N/A 90' 90' Surface 1,219' 13 3/8" To Surface 1,219' 1,219' Intermediate 6,720' 9 5/8" To 5,260' 6,720' 6,720' Production Liner 560' 7 5/8" To 6,640' 7,200' 7,200' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: , 14. Estimated date for commencing operation 15. Status of well classification as: May 1, 1998 16. If proposal well verbally approved: ~o Oil: Gas: Suspended: X Blair Wondzell April~, 1998 Name ~,~prover Date approved Service: 17. I here~ ceJ~ythat the foregoing is tru' and correct to the best of my kno~iedge. Signed: \ ~ Paul White Title: Drilling Manager Date: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approva~,,~.~..~ Plug integrity BOP Test ~ Location clearance .... Mechanical Integrity Test Subsequent form required 10- ~,~"t' ur~ginal Signed 8y David W. Johnston ,,Z//L.~) Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE VELOCITY SURVEY FOR COFFEE CREEK #1 conducted for Forcenergy Inc April 1998 Forcenergy Coffee Creek #1 Run 1 ~pril 7, 1998 WELL SEISMIC REPORT Company: Forcenergy, Inc. Well: Coffee Creek #1 Field: Wildcat Region: Kenai Run: One APl number: 50-283-20094-00 Well Loc.: 527' FWL & 710' FSL State: Alaska Acquired: April 7, 1998 Permanent Datum/Seismic Reference- Mean Sea Level (MSL) Elevation of Permanent Datum: 0.0 Ft. Elevation of Ground Level: 620.0 Ft. Elevation of Kelly Bushing: 641.0 Ft. Driller's Depth: 9757.0 Ft. Logs Measured From: KB Bottom Logged InLy.: 9757.0 Ft. Survey Starteck. Apr. 7, 1998 Logging Unit: 310 Recorded by:. R. Walsh Log Analyst: Sines Drilling MeasuredFrom: Top Logged Interval'. Survey Completed:. Location: Witnessed by: Processing Job Number: KB 1147.0 Ft. Apr. 7, 1998 Wildcat R. Nelson 98188 Source Description: Source Locations: Sonic Log: Directional Data: Shaped dynamite charges Muliple locations around Well Bore Not used Client supplied Processed at Schlumberger- GeoQuest Alaska Interpretation Center 500 W. International Airport Rd. Anchorage, Alaska 99516 (907)563-1592 Forcenergy Run 1 Coffee Creek #1 . ,pril 7, 1998 CONTENTS - 1. - ACQUISITION INFORMATION 1 2. - SEISMIC REPORT Describes source and Geophone locations, applies geometrical corrections and computes Average and Interval Velocities for the selected levels. 3. -PLOTS Plots of the check shots, and Time/Depth Curve 4.- VELOCITY REPORT Computes Average Velocity, RMS Velocity and interval Velocity from pseudo Sonic Log versus Two Way Travel Time. 5. - DEPTH REPORT Lists Two Way Travel Time From the pseudo Sonic Log versus Two Way Travel Time. 6. - TIME REPORT Lists Depth from the pseudo Sonic Log versus Two Way Travel Time. 7. - FIELD REPORTS 8.- POUCHES Contain plots of the time /depth curve All interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations, and we shall not, except in the case of gross or willful negligence on our part, be liable or responsible for any loss, costs, damages or expenses incurred or sustained by anyone resulting from any interpretations made by any of our officers, agents or employees. These interpretations are also subject to our general terms and conditions as set out in our current price schedule. Have a nice day! Forcenergy Run 1 Coffee Creek #1 ~ril 7, 1998 Processing Notes Schlumberger acquired a check shot survey for Forcenergy on April 7, 1998 on their Coffee Creek #1 well. The data were acquired using the Schlumberger SAT 3 component tool to record the downhole signal. The source signature was generated discharging shaped dynamite charges in shot holes around the well bore. Overall quality of the data was good. The check shots times were corrected for source and geophone offset and depths were corrected to true vertical depth. A Velocity Quick Look was computed and included in this report. Ramona Sines GeoQuest Anchorage, Alaska ANALYST: R. SINES 3-MAY-98 16:04:20 PROGR3%M: GSHOT 007.E09 * SCHLUMBERGER * . * VELOCITY SURVEY SUMMARY COMPANY : FORCENERGY WELL : COFFEE CREEK FIELD : WILDCAT COUNTY : KENAI STATE : ALASKA REFERENCE: 98188 ****************************** SURFACE GEOMETRY TABLE ******************************* ******************************************************************************************* ******************************************************************************************* ELEVATION OF KELLY BUSHING (KB) ABOVE MEAN SEA LEVEL ELEVATION OF SEISMIC REFERENCE DATUM (SRD) ABOVE MSL ELEVATION OF GROUND LEVEL ABOVE SRD VELOCITY OF MEDIUM FROM SOURCE TO SURFACE SENSOR VELOCITY OF MEDIUM FROM SOURCE TO SRD 641.40 FT 0.00 FT 620.00 FT 8000.00 FT/SEC 8000.00 FT/SEC ****************************** SOURCE POSITION TABLE ******************************** so~cm ELEWTION I SOURCE SIST~CE ABOVE S~ I FROM ~ELL~EXO 530.0 FT I 463.0 FT I SOURCE AZIMUTH FROM NORTH 351.0 DEG DEPTH RANGE FROM TO 99999.0 0.0 FT ****************************** SURFACE SENSOR TABLE ********************************* SURFACE SENSOR ELEVATION ABOVE SRD 530.0 FT SURFACE SENSOR DISTANCE FROM WELLHEAD 463.0 FT SURFACE SENSOR AZIMUTH FROM NORTFI 351.0 DEG DEPTH RANGE FROM TO 99999.0 0.0 FT ****************************** SOURCE ELEVATION TABLE ******************************* ******************************************************************************************* ******************************************************************************************* TI~ CROX SURCACE I TI~m CROM I I SENSOR TO SOURCE I SOURCE TO SRD I I o.oo ms I -~s.m5 mS I I *************************** DEVIATED WELL RECEIVER GEOMETRY TABLE ****************************** LEVEL NO 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 MEASURED DEPTH FROM KB 1044.7 FT 1239.9 FT 1350.0 FT 1549.8 FT 1800.0 FT 2049.9 FT 2299.9 FT 2549.9 FT 2789.9 FT 3350.1 FT 3600.0 FT 4000.1 FT 4400.2 FT 4800.1 FT 5288.2 FT 5600.0 FT 6000.1 FT 6400 1 FT 6800 1 FT 7200 0 FT 7600 0 FT 8000 1 FT 8400 0 FT 8750 0 FT 9000 0 FT 9100 0 FT 9500 0 FT 9752 4 FT VERTICAL DEPTH FROM KB 1044.4 FT 1239.5 FT 1349.4 FT 1548.9 FT 1798.8 FT 2048.3 FT 2298.0 FT 2547.4 FT 2786.9 FT 3345.6 FT 3595.0 FT 3994.2 FT 4393.4 FT 4792 1 FT 5278 2 FT 5588 4 FT 5985 9 FT 6382 7 FT 6778 6 FT 7172 7 FT 7564 7 FT 7955 7 FT 8346 8 FT 8690 0 FT 8937 2 FT 9036 1 FT 9433.9 FT 9685.6 FT VERTICAL DEPTH FROM SRD 403.0 FT 598.1 FT 708.0 FT 907.5 FT 1157.4 FT 1406.9 FT 1656.6 FT 1906.0 FT 2145.5 FT 2704.2 FT 2953.6 FT 3352.8 FT 3752.0 FT 4150.7 FT 4636.8 FT 4947.0 FT 5344 5 FT 5741 3 FT 6137 2 FT 6531 3 FT 6923 3 FT 7314 3 FT 7705 4 FT 8048 6 FT 8295 8 FT 8394 7 FT 8792.5 FT 9044.2 FT EAST WEST COORDINATES -10 9 FT -14 3 FT -17 1 FT -22 1 FT -28 4 FT -34 7 FT -41.0 FT -48.4 FT -55.8 FT -73.5 FT -80.0 FT -89.2 FT -98.5 FT -108.7 FT -120.1 FT -125.9 FT -137.4 FT -174.3 FT -223.5 FT -288.5 FT -367.8 FT -452.2 FT -535.0 FT -602.6 FT -639.4 FT -654.1 FT -692.4 FT -709.9 FT NORTH SOUTH COORDINATES -5.8 FT 0.6 FT 5.8 FT 15.3 FT 27.1 FT 38.9 FT 50.8 FT 64.7 FT 78.9 FT 115.5 FT 131.1 FT 155.2 FT 180.8 FT 209.4 FT 251.9 FT 283.3 FT 325.9 FT 357.9 FT 383.7 FT 400.8 FT 405.3 FT 400.8 FT 391.3 FT 382.3 FT 379.7 FT 378.7 FT 377.6 FT 377.6 FT GEOPHONE OFFSET 12.3 FT 14.4 FT 18.1 FT 26 9 FT 39 3 FT 52 2 FT 65 2 FT 80 8 FT 96 6 FT 136.9 FT 153.6 FT 179.0 FT 205.9 FT 235.9 FT 279.1 FT 310.0 FT 353.7 FT 398.1 FT 444.0 FT 493.8 FT 547.3 FT 604.2 FT 662.9 FT 713.7 FT 743.6 FT 755.8 FT 788.7 FT 804.1 FT GEOPHONE AZIMUTH -117.9 DEG -87.5 DEG -71.2 DEG -55.4 DEG -46.4 DEG -41.7 DEG -38 9 DEG -36 8 DEG -35 3 DEG -32 5 DEG -31 4 DEG -29 9 DEG -28 6 DEG -27 4 DEG -25 5 DEG -24 0 DEG -22.9 DEG -26.0 DEG -30.2 DEG -35.7 DEG -42.2 DEG -48.4 DEG -53.8 DEG -57.6 DEG -59.3 DEG -59.9 DEG -61.4 DEG -62.0 DEG COMPANY : FORCENERGY WELL : COFFEE CREEK LEVEL NO 10 11 15 17 18 19 20 21 22 23 MEASURED DEPTH FROM KB FT 1044.7 1239.9 1350.0 1549.8 1800.0 2049.9 2299.9 2549.9 2789.9 3350.1 3600.0 4000.1 4400.2 4800.1 5288.2 5600.0 6000.1 6400.1 6800.1 7200.0 7600.0 8000.1 8400.0 VERTICAL DEPTH FROM SRD FT 403.0 598.1 708.0 907.5 1157.4 1406.9 1656.6 1906.0 2145.5 2704.2 2953.6 3352.8 3752.0 4150.7 4636.8 4947.0 5344.5 5741.3 6137.2 6531.3 6923.3 7314.3 7705.4 MEASURED TIME FROM SURFACE SENSOR TO GEO mS 143.0 160.0 177.9 201.4 227.1 252.7 281.4 311.6 337.6 404. o 434.5 474.4 516.3 556.2 605.6 636.1 680.0 712.0 756.0 786.3 817.0 851.0 874.0 VERTICAL TIME FROM SOURCE TO GEOPHONE mS 127.9 148.1 167.0 192.4 220.0 247.0 276.6 307.6 334.3 401.8 432.6 473.0 515.2 555.4 605.1 635.8 679.8 711.8 755.8 785.9 816.3 850.0 872.6 VERTICAL TIME FROM SRD/GEO. mS 61.6 81.9 100.7 126.2 153.7 180.7 210.4 241.4 268.0 335.5 366.4 406.7 449.0 489.1 538.8 569.5 613.5 645.6 689.5 719.7 750.1 783.7 806.3 AVERAGE VELOCITY SRD/GEO. FT/S 6S41 7303 7028 7194 7528 7786 7874 7897 8005 8060 8062 8244 8357 8485 8605 8687 8711 8893 8901 9076 9230 9333 9556 DELTA DEPTH FT 195.0 109.9 199.5 249.8 249 5 249 6 249 5 239 5 558 7 249 3 399 3 399 2 398 7 486 1 310 1 397 6 396 7 395 9 394 2 391 9 391 0 391 1 DELTA TIME 20.3 18 9 25 4 27 6 27 0 29 7 31 0 26 6 67 5 30 8 40 4 42 3 40 2 49 7 30 6 44 0 32 0 43 9 30 1 30 4 33 6 22 6 INTERVAL VELOCITY FT/S 9622 5833 7851 9054 9253 8413 8052 8985 8278 8084 9893 9447 9922 9782 10118 9028 12387 9009 13075 12879 11623 17294 343.2 18.7 18385 COMP~RX~Y : FORCENERGY WELL : COFFEE CREEK LEVEL NO 24 25 26 27 28 MEASURED DEPTH FROM KB FT 8750.0 9000.0 9100.0 9500.0 9752.4 VERTICAL DEPTH FROM SRD FT 8048.6 8295.8 8394.7 8792.5 9044.2 MEASURED TIME FROM SURFACE SENSOR TO GEO mS 893.0 917.0 925.0 944.2 965.1 VERTICAL TIME FROM SOURCE TO GEOPHONE mS 891.3 915.1 923.0 942.1 962.9 VERTICAL TIME FROM SRD/GEO. 825.0 848.8 856.8 875.8 896.7 AVERAGE VELOCITY SRD/GEO. FT/S 9756 9773 9798 10039 10086 DELTA DEPTH FT 247.2 98.9 397.8 251.7 DELTA TIME 23.8 7.9 19.1 20.9 INTERVAL VELOCITY FT/S 10381 12474 20852 12073 kNALYST: R. SINES 6-MAY-98 12:27:13 PROGP, A24: GTRFRM 001.E14 * SCHLUMBERGER . ******************** TIME REPORT COMPANY : FORCENERGY, INC. WELL : COFFEE CREEK #1 FIELD : WILDCAT COUNTY : KENAI STATE : ALASKA REFERENCE: 98188 LOGGED : 7-APR-98 COMPANY : FORCENERGY, INC. WELL : COFFEE CREEK #1 PAGE 1 LONG DEFINITIONS GLOBAL STPTIM - SAMPLING OF TIME REPORT SAMPLED NDPT NDPT NDPT NAM Time Report Depth NAM Time Report Depth NAM Time Report Depth (GLOBAL PAR3kMETERS) STEP OF TIME LIST (WST) STPTIM ( VALUE ) : 10.0000 MS COMPANY : FORCENERGY, INC. WELL : COFFEE CREEK #1 PAGE 2 TWO WAY DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH SONIC /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT TIME + 0 * + 1 * + 2 * + 3 * + 4 * + 5 * + 6 * + 7 * + 8 * + 9 * FROM SRD SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 MS FT FT FT FT FT FT FT FT FT FT 0 0 10.00 35.0 38.5 42.0 45 5 49.0 52 20.00 70.0 73.5 77.0 80 5 84.0 87 30.00 105.0 108.5 112.0 115 5 119.0 122 40.00 140.0 143.5 147.0 150 5 154.0 157 50.00 175.0 178.5 182.0 185 5 189.0 192 60.00 210.0 213.5 217.0 220.5 224.0 227 70.00 245.0 248.5 252.0 255.5 259.0 262 80.00 280.0 283.5 287.0 290.5 294.0 297.5 301 0 304 90.00 315.0 318.5 322.0 325.5 329.0 332.5 336 0 339 5 343 0 346 100.00 350.0 353.5 357.0 360.5 364.0 367.5 371.0 374 5 378 0 381 110.00 385.0 388.5 392.0 395.5 399.0 402.5 407.6 412 4 417 3 422 120.00 426.9 431.7 436.5 441.3 446.1 450.9 455.7 460 6 465 4 470 130.00 475.0 479.8 484.6 489.4 494.2 499.0 503.9 508 7 513 5 518 140.00 523.1 527.9 532.7 537,5 542.3 547.2 552.0 556.8 561 6 566 150.00 571.2 576.0 580.8 585.6 590.5 595.3 599.3 602.2 605 1 608 160.00 611.0 613.9 616.8 619,7 622.6 625.5 628.5 631.4 634 3 637 170.00 640.1 643.0 646.0 648,9 651.8 654.7 657.6 660.5 663.5 666 180.00 669.3 672.2 675.1 678.0 681.0 683.9 686.8 689.7 692.6 695 190.00 698.5 701.4 704.3 707.2 710.9 714.8 718.7 722.6 726.6 730. 200.00 734.4 738.3 742.3 746,2 750.1 754.0 758.0 761.9 765.8 769 210.00 773.7 777.6 781.5 785.4 789.4 793.3 797.2 801.1 805.1 809. 220.00 812.9 816.8 820 8 824.7 828.6 832.6 836.5 840.4 844.3 848. 230.00 852.2 856.1 860 240 00 891.4 895.4 899 250 00 934 2 938.8 943 260 00 979 5 984 0 988 6 993 1 997 270 00 1024 8 1029 3 1033 8 1038 4 1042 280 00 1070 1 1074 6 1079 1 1083 6 1088 290 00 1115 3 1119 9 1124 4 1128 9 1133 300 00 1160 7 1165 3 1169 9 1174 6 1179 310 00 1206 9 1211 6 1216 2 1220 8 1225 4 1230 320 00 1253 2 1257 8 1262.5 1267 1 1271.7 1276 330 00 1299 5 1304 1 1308.7 1313 4 1318.0 1322 340.00 1345 7 1350 4 1355.0 1359 6 1364.2 1368 9 1373 5 1378 350.00 1392 0 1396 6 1401.3 1405 9 1410.2 1414 4 1418 6 1422 360.00 1435 4 1439 6 1443.8 1448 0 1452.3 1456 5 1460 7 1464 370.00 1477.5 1481 7 1485.9 1490 1 1494.3 1498 5 1502 7 1506 380.00 1519.6 1523 8 1528.0 1532 2 1536.4 1540 6 1544 8 1549 390.00 1561.6 1565.8 1570.0 1574.2 1578.5 1582.7 1586 400.00 1603.7 1607.9 1612.1 1616.3 1620.5 1624.7 1628 1 1637 3 1641 410.00 1645.8 1650.0 1654.2 1658.3 1662.3 1666.4 1670 4 1678 4 1682 420.00 1686.5 1690.5 1694.5 1698.6 1702.6 1706.6 1710 7 1718 7 1722 430.00 1726.7 1730.8 1734.8 1738.8 1742.8 1746.9 1750 9 1759 0 1763 440.00 1767.0 1771.0 1775.1 1779.1 1783.1 1787.1 1791.2 1795 2 1799 2 1803 450.00 1807.3 1811.3 1815.3 1819.3 1823.4 1827.4 1831.4 1835.5 1839 5 1843 460.00 1847.5 1851.6 1855.6 1859.6 1863.6 1867.7 1871.7 1875.7 1879 7 1883 470.00 1887.8 1891.8 1895.8 1899.9 1903.9 1908.1 1912.6 1917.1 1921.6 1926 480.00 1930.6 1935.1 1939.6 1944.1 1948.6 1953.1 1957.6 1962.0 1966.5 1971 490.00 1975.5 1980.0 1984.5 1989.0 1993.5 1998.0 2002.5 2007.0 2011.5 2016 3.5 7.0 10 5 14.0 17 5 21.0 24.5 28.0 31.5 5 56 0 59.5 63.0 66.5 5 91 0 94.5 98.0 101.5 5 126 0 129.5 133.0 136.5 5 161 0 164.5 168.0 171.5 5 196 0 199.5 203.0 206.5 5 231 0 234.5 238.0 241.5 5 266 0 269 5 273.0 276.5 5 308 0 311 5 5 5 1 2 3 4 0 2 4 5 5 7 0 3 0 864.0 867.9 871.8 875.7 879.7 883.6 887.5 3 903 2 907.1 911.6 916.1 920.7 925.2 929.7 3 947 8 952 4 956.9 961.4 965.9 970.5 975.0 6 1002.2 1006.7 1011.2 1015.7 1020.3 9 1047.4 1052.0 1056.5 1061.0 1065.5 2 1092.7 1097.2 1101.8 1106.3 1110.8 4 1138.0 1142.5 1147.0 1151.6 1156.1 2 1183 8 1188.4 1193.1 1197.7 1202.3 1 1234.7 1239.3 1244.0 1248.6 3 1281.0 1285.6 1290.2 1294.8 6 1327 2 1331 9 1336.5 1341.1 1 1382.8 1387.4 8 1427.0 1431.2 9 1469.1 1473.3 9 1511.1 1515.4 0 1553.2 1557.4 9 1591 1 1595 3 1599 5 9 1633 6 4 1674 5 6 1714 7 9 1754 0 2 5 8 1 0 0 500.00 2020.5 2024.9 2029.4 2033.9 2038.4 2042.9 2047.4 2051.9 2056.4 2060.9 510.00 2065.4 2069.9 2074.4 2078.9 2083.3 2087.8 2092.3 2096.8 2101.3 2105.8 520.00 2110.3 2114.8 2119.3 2123.8 2128.3 2132.8 2137.3 2141.8 2146.2 2150.3 530.00 2154.5 2158.6 2162.7 2166.9 2171.0 2175.2 2179.3 2183.4 2187.6 2191.7 540.00 2195.9 2200.0 2204.1 2208.3 2212.4 2216.5 2220.7 2224.8 2229.0 2233.1 550.00 2237.2 2241.4 2245.5 2249.7 2253.8 2257.9 2262.1 2266.2 2270.4 2274.5 COMPA/~Y : FORCENERGY, INC. WELL : COFFEE CREEK #1 PAGE 3 TWO WAY DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH SONIC /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT TIME + 0 * + 1 * + 2 * + 3 * + 4 * + 5 * + 6 * + 7 * + 8 * + 9 * FROM SRD SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 MS FT FT FT FT FT FT FT FT FT FT 560 00 2278.6 2282 8 2286 9 2291.0 2295.2 2299.3 2303.5 2307.6 2311.7 2315.9 570 580 590 600 610 620 630 00 2320.0 2324 00 2361.4 2365 00 2402.8 2406 00 2444.2 2448 00 2485.6 2489 00 2527.0 2531 00 2568.3 2572 2 2328 5 2369 9 2411 3 2452 7 2493 1 2535 5 2576 640.00 2609.7 2613.9 2618 650.00 2651.1 2655.3 2659 660.00 2692.5 2696.7 2700.8 2704 670.00 2733.2 2737.2 2741.3 2745 680.00 2773.6 2777.7 2781.7 2785.7 2789 690.00 2814.0 2818.1 2822.1 2826.2 2830 700.00 2854.5 2858.5 2862.5 2866.6 2870 710.00 2894.9 2898.9 2903.0 2907.0 2911 720.00 2935.3 2939.3 2943.4 2947.4 2951 730.00 2980.7 2985.6 2990.6 2995.5 3000 740.00 3030.1 3035.1 3040.0 3045.0 3049 3 2332.4 2336.6 2340.7 2344.9 2349.0 2353.1 2357.3 7 2373.8 2378.0 2382.1 2386.2 2390.4 2394.5 2398.7 1 2415 2 2419.3 2423.5 2427.6 2431.8 2435.9 2440.0 5 2456 6 2460.7 2464.9 2469.0 2473.2 2477.3 2481.4 8 2498 0 2502.1 2506.3 2510.4 2514.5 2518.7 2522.8 2 2539 4 2543.5 2547.7 2551.8 2555.9 2560.1 2564.2 6 2580 8 2584.9 2589.0 2593.2 2597.3 2601.5 2605.6 0 2622 2 2626.3 2630.4 2634.6 2638.7 2642.8 2647.0 4 2663 5 2667.7 2671.8 2676.0 2680.1 2684.2 2688.4 9 2709.0 2713.0 2717.0 2721.1 2725.1 2729.2 3 2749 4 2753 4 2757 5 2761.5 2765.5 2769.6 9 2801.9 2806.0 2810.0 3 2842 3 2846.4 2850.4 8 2793 2 2834 6 2874 0 2915 5 2955 5 3005 9 3054 8 2797 3 2838 7 2878 1 2919 9 2960 4 3010 9 3059 7 2882 1 2923 9 2965 4 3015 8 3064 750.00 3079.6 3084.6 3089.5 3094.4 3099 4 3104 3 3109 3 3114 2 3119 760.00 3129.1 3134.0 3139.0 3143.9 3148.9 3153.8 3158.7 3163 7 3168 770.00 3178.5 3183.5 3188.4 3193.4 3198.3 3203.3 3208.2 3213 2 3218 780.00 3228.0 3232.9 3237.9 3242.8 3247.8 3252.7 3257.7 3262.6 3267 790.00 3277 5 3282.4 3287.4 3292.3 3297.2 3302.2 3307.1 3312.1 3317 6 3272 0 3322 9 3331.9 3336.8 3341.8 3346.7 3351.7 3356.4 3361.2 3365.9 3370 3 3380.1 3384.8 3389.5 3394.2 3398.9 3403.7 3408.4 3413.1 3417 6 3427.3 3432.0 3436.7 3441.5 3446.2 3450.9 3455.6 3460.4 3465 8 3474 5 3479.2 3484.0 3488.7 3493.4 3498.1 3502.9 3507.6 3512 0 3521 8 3526.5 3531.2 3535.9 3540.7 3545.4 3550.1 3554.8 3559 800.00 3326 810.00 3375 820.00 3422 830 00 3469 840 00 3517 8 2886.8 2890.8 2 2927.2 2931.3 8 2970.8 2975.7 3 3020 2 3025.2 8 3069 7 3074.7 2 3124.1 6 3173.6 1 3223 1 5 0 6 8 t 3 5 850 860 870 880 890 900 910 920 930 940 950 00 3564 3 3569 00 3611 5 3616 00 3658 7 3663 5 3668 00 3706 0 3710 7 3715 00 3753 3 3758 2 3763 00 3802.9 3807 00 3852.5 3857 00 3902.1 3907 00 3951.7 3956 00 4001.3 4006 00 4050.9 4055.9 4060 0 3573.7 3578.4 3583.2 3587.9 3592.6 3597.3 3602.1 3606.8 2 3621 0 3625.7 3630.4 3635.1 3639.8 3644.6 3649.3 3654.0 2 3672.9 3677.6 3682.4 3687.1 3691.8 3696.5 3701.3 4 3720.1 3724.9 3729.6 3734.3 3739.0 3743.8 3748.5 2 3768 2 3773.1 3778.1 3783.0 3788.0 3793.0 3797.9 8 3812 8 3817 8 3822.7 3827.7 3832.6 3837.6 3842.6 3847.5 5 3862 4 3867 4 3872.3 3877.3 3882.3 3887.2 3892.2 3897.1 1 3912 0 3917 0 3921.9 3926.9 3931.9 3936.8 3941.8 3946.8 7 3961 6 3966 6 3971.6 3976.5 3981.5 3986.4 3991.4 3996.4 3 4011 2 4016 2 4021.2 4026.1 4031.1 4036.1 4041.0 4046.0 9 4065 8 4070.8 4075.7 4080.7 4085 7 4090.6 4095.6 960.00 4100.5 4105.5 4110.5 4115 970.00 4150.2 4155.1 4160.0 4164 980.00 4199.1 4204.0 4208.9 4213 990.00 4248.0 4252.9 4257.8 4262 7 4267 1000.00 4296.9 4301.8 4306.7 4311.6 4316 1010.00 4345.8 4350.7 4355.6 4360.5 4365 1020.00 4394.7 4399.6 4404.5 4409.4 4414 1030.00 4443.6 4448.5 4453.4 4458.3 4463 1040.00 4492.5 4497.4 4502.3 4507.2 4512 1050.00 4541.5 4546.3 4551.2 4556.1 4561 1060.00 4590.4 4595.3 4600.1 4605.0 4609 4 4120.4 4125 4 4130.3 4135 6 4179.5 4184 5 4228.4 4233 4 4277.3 4282 4 4326 2 4331 3 4375 2 4380 2 4424 1 4429 1 4473 0 4477 9 4526 8 4575 7 4624 3 4140.2 4145.2 4 4189.3 4194.2 3 4238.2 4243.1 2 4287.1 4292.0 1 4336.0 4340.9 0 4384.9 4389.8 0 4433 9 4438.7 9 4482 8 4487.7 8 4531 7 4536.6 7 4580 6 4585.5 6 4629 5 4634.4 8 4684.9 4 4735.5 8 4169.7 4174 8 4218 6 4223 6 4272 5 4321 4 4370 3 4419 2 4468 1 4517 0 4565 9 4614 0 4521 9 4570 8 4619 1070.00 4639.4 4644.4 4649.5 4654.5 4659.6 4664.7 4669.7 4674.8 4679 1080.00 4690.0 4695.0 4700.1 4705.1 4710.2 4715.2 4720.3 4725.4 4730 1090.00 4740.5 4745.6 4750.7 4755.7 4760.8 4765.8 4770.9 4776.0 4781.0 4786.1 1100.00 4791.1 4796.2 4801.3 4806.3 4811.4 4816.4 4821.5 4826.5 4831.6 4836.7 1110.00 4841.7 4846.8 4851.8 4856.9 4862.0 4867.0 4872.1 4877.1 4882.2 4887.3 COMPi~N-Y : FORCENERGY, INC. WELL : COFFEE CREEK #1 PAGE 4 TWO WAY DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH SONIC /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT TIME + 0 * + 1 * + 2 * + 3 * + 4 * + 5 * + 6 * + 7 * + 8 * + 9 * FROM SRD SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 MS FT FT FT FT FT FT FT FT FT FT 1120 00 4892 3 4897.4 4902 4 4907.5 4912.6 4917 6 4922.7 4927.7 4932.8 4937.8 1130 00 4942 1140 00 4988 1150 00 5033 1160 00 5078 1170 00 5123 1180 00 5169 1190.00 5214 9 4947.9 4952 4 4956.9 4961 4 4965 5 4993.0 4997 5 5002.0 5006 5 5011 6 5038.1 5042 6 5047.2 5051 7 5056 8 5083.3 5087 8 5092.3 5096 8 5101 9 5128.4 5132 9 5137.4 5141 9 5146 0 5173.5 5178 1 5182.6 5187 1 5191 2 5218.7 5223.2 5227.7 5232.2 5236 1200.00 5259.3 5263.8 5268.3 5272.8 5277.4 5281 9 5286 4 5290 1210.00 5304.4 5309.0 5313.5 5318.0 5322.5 5327 0 5331 5 5336 1220.00 5351.5 5357.7 5363.9 5370.0 5376.2 5382 4 5388 6 5394 1230.00 5413.4 5419.6 5425.8 5432.0 5438.2 5444.4 5450 6 5456 1240.00 5475.3 5481.5 5487.7 5493.9 5500.1 5506.3 5512 5 5518 1250.00 5537.3 5543.5 5549.7 5555.8 5562.0 5568.2 5574.4 5580 1260.00 5599.2 5605.4 5611.6 5617.8 5624.0 5630.2 5636.4 5642 9 4970.4 4974.9 4979.5 4984.0 1 5015.6 5020.1 5024.6 5029.1 2 5060.7 5065.2 5069.7 5074.2 3 5105.8 5110.4 5114.9 5119.4 5 5151 0 5155.5 5160.0 5164.5 6 5196 1 5200.6 5205.1 5209.7 7 5241 3 5245 8 5250.3 5254.8 9 5295.4 5299.9 0 5340.6 5345.3 8 5401.0 5407.2 8 5462.9 5469 1 7 5524.9 5531 1 6 5586.8 5593 0 6 5648.8 5654 9 1270.00 5661.1 5667.3 5673.5 5679.7 5685.9 5692.1 5698.3 5704.5 5710.7 5716 9 1280.00 5723.1 5729.3 5735.5 5741.5 5746.1 5750.6 5755.1 5759.6 5764.1 5768 6 1290.00 5773.1 5777.6 5782.1 5786.6 5791.1 5795.6 5800.1 5804.6 5809.1 5813.6 1300.00 5818.1 5822.6 5827.1 5831.6 5836.1 5840.7 5845.2 5849.7 5854.2 5858.7 1310.00 5863.2 5867.7 5872.2 5876.7 5881.2 5885.7 5890.2 5894.7 5899.2 5903.7 1320.00 5908.2 5912.7 5917.2 5921.7 5926.2 5930.7 5935.2 5939.8 5944.3 5948.8 1330.00 5953 3 5957 8 5962.3 5966 8 5971.3 5975.8 5980.3 5984.8 5989.3 5993.8 1340.00 5998 1350.00 6043 1360.00 6088 1370 00 6133 1380 00 6197 1390 1400 1410 1420 1430 1440 1450 1460 1470 00 6262 00 6327 00 6393 00 6458 00 6524 00 6588 00 6652 3 6002 4 6047 4 6092 4 6138 1 6203 5 6269 9 6334 3 6399 6 6465 0 6530 5 6595.0 6601 9 6659.3 6665 00 6717.3 6723.7 6730 00 6781.7 6788.1 6794 8 6007.3 6011 9 6052.4 6056 9 6097.4 6101 3 6144 8 6151 7 6210 2 6216 1 6275 6 6282 4 6341 0 6347 8 6406 3 6412 9 6419 2 6471 7 6478.2 6484 5 6537 0 6543.4 6549 4 6607.8 6614 8 6672.2 6678 7 6685 2 6736.6 6743.1 6749 6 6801.0 6807.5 6813 8 6016.3 6020.8 6025.3 6029.8 6034.3 6038.9 9 6061.4 6065.9 6070.4 6074.9 6079.4 6083.9 9 6106.4 6110.9 6115.4 6119.9 6124.4 6128.9 4 6157.9 6164.5 6171.0 6177.5 6184.1 6190.6 8 6223 3 6229.8 6236.4 6242.9 6249.4 6256.0 1 6288 7 6295 2 6301.7 6308.3 6314.8 6321.4 5 6354 0 6360 6 6367.1 6373.7 6380.2 6386.7 4 6425 9 6432.5 6439.0 6445.6 6452.1 8 6491 3 6497.9 6504.4 6510.9 6517.5 9 6556 3 6562.8 6569.2 6575.6 6582.1 3 6620 7 6627 2 6633 6 6640.0 6646.5 1 6691 5 6698 0 6704.4 6710.9 4 6768 8 6775.3 5 6755 9 6820 3 6884 8 6946 9 6762 3 6826 7 6891 6 6952 8 6833 2 6897 4 6958 1480.00 6846.1 6852.5 6859.0 6865.4 6871.9 6878 1490.00 6910.5 6916.9 6923.4 6929.2 6935.0 6940 1500.00 6969.9 6975.7 6981.5 6987.3 6993.1 6998.9 7004 7 7010 5 7016 3 7022 1510.00 7028.0 7033.8 7039.6 7045.4 7051.2 7057.0 7062 8 7068 6 7074 5 7080 1520.00 7086.1 7091.9 7097.7 7103.5 7109.3 7115.1 7121.0 7126 8 7132 6 7138 1530.00 7144.2 7150.0 7155.8 7161.6 7167.4 7173.3 7179.1 7184 9 7190 7 7196 1540.00 7202.3 7208.1 7213.9 7219.7 7225.6 7231.4 7237.2 7243.0 7248.8 7254 1550.00 7260.4 7266.2 7272.0 7277.9 7283.7 7289.5 7295.3 7301.1 7306.9 7312 2 6839.7 6 6904 1 2 6964 0 2 3 4 5 6 7 1560.00 7320.6 7329.3 7337.9 7346.5 7355.2 7363.8 7372.5 7381.1 7389.8 7398.4 1570.00 7407.1 7415.7 7424.4 7433.0 7441.7 7450.3 7459.0 7467.6 7476.2 7484.9 1580.00 7493.5 7502.2 7510.8 7519.5 7528.1 7536.8 7545.4 7554.1 7562.7 7571.4 1590.00 7580.0 7588.7 7597.3 7606.0 7614.6 7623.2 7631.9 7640.5 7649.2 7657.8 1600.00 7666.5 7675.1 7683.8 7692.4 7701.1 7710.0 7719.2 7728.4 7737.6 7746.8 1610.00 7756.0 7765.1 7774.3 7783.5 7792.7 7801.9 7811.1 7820.3 7829.5 7838.7 1620.00 7847.9 7857.1 7866.3 7875 5 7884.6 7893.8 7903.0 7912.2 7921.4 7930.6 1630.00 7939.8 7949.0 7958.2 7967 4 7976.6 7985.8 7995.0 8004.1 8013.3 8022.5 1640.00 8031.7 8040.9 8049.4 8054 6 8059.8 8065.0 8070.2 8075.4 8080.6 8085.8 1650.00 8091.0 8096.2 8101.4 8106 5 8111.7 8116.9 8122.1 8127.3 8132.5 8137.7 1660.00 8142.9 8148.1 8153.3 8158 5 8163.6 8168.8 8174.0 8179.2 8184.4 8189.6 1670.00 8194.8 8200.0 8205.2 8210 4 8215.5 8220.7 8225.9 8231.1 8236.3 8241.5 COMPANY : FORCENERGY, INC. WELL : COFFEE CREEK #1 PAGE 5 TWO WAY DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH DEPTH SONIC /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT TIME + 0 * + 1 * + 2 * + 3 * + 4 * + 5 * + 6 * + 7 * + 8 * + 9 * FROM SRD SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 MS FT FT FT FT FT FT FT FT FT FT 1680.00 8246 7 8251.9 8257.1 8262 3 8267.5 8272.6 8277.8 8283.0 8288.2 8293.4 1690.00 8299 2 8305.4 8311.6 8317 1700.00 8361 5 8367.8 8374.0 8380 1710.00 8443 5 8453.9 8464.4 8474 1720.00 8547 8 8558.2 8568.6 8579 1730.00 8652 0 8662.5 8672.9 8683 1740.00 8756 3 8766.7 8777.1 8787 1750.00 8831.9 8837.9 8844.0 8850 1760.00 8892.3 8898.3 8904.3 8910 1770.00 8952.6 8958.7 8964.7 8970 9 8324.1 8330 3 8336.6 8342.8 8349.1 8355.3 2 8386 5 8392 8 8485 1 8589 3 8693 6 8795 0 8856 4 8916 7 8976 2 8495 5 8599 7 8704 7 8801 1 8862 4 8922 8 8982 7 8401.8 8412.2 8422.7 8433.1 6 8506.1 8516.5 8526.9 8537.4 9 8610 3 8620 8 8631.2 8641.6 2 8714 6 8725 0 8735.4 8745.9 7 8807 8 8813 8 8819.8 8825.9 1 8868 1 8874 2 8880.2 8886.2 5 8928 5 8934 5 8940.6 8946.6 8 8988 9 8994 9 9000.9 9007.0 1780.00 9013.0 9019.0 9025.1 9031.1 9037.1 9043.2 ANALYST: R. SINES 6-MAY-98 12:27:21 PROGRAM: GTRFRM 001.E14 * SCHLUMBERGER * DEPTH REPORT COMPANY : FORCENERGY, INC. WELL : COFFEE CREEK #1 FIELD : WILDCAT COUNTY : KENAI STATE : ALASKA REFERENCE: 98188 LOGGED : 7-APR-98 COMPANY : FORCENERGY, INC. WELL : COFFEE CREEK #1 PAGE LONG DEFINITIONS GLOBAL STPDPT - SAMPLING OF DEPTH REPORT SAMPLED NTIM NTIM NTIM NTIM NTIM NAM Depth Report Time NAM Depth Report Time NAM Depth Report Time NAM Depth Report Time NAM Depth Report Time (GLOBAL PARAMETERS) STEP OF DEPTH LIST (WST) STPDPT (VALUE) : 100.000 FT COMPANY : FORCENERGY, INC. WELL : COFFEE CREEK #1 PAGE 2 VERTICAL TWO WAY TWO WAY TWO WAY TWO WAY DEPTH TIME AT TIME AT TIME AT TIME AT FROM + 0 * + 1 SRD SMPL/10 SMPL/10 SMPL/10 SMPL/10 FT MS MS MS MS 0 100.0 200 0 300 0 400 0 500 0 600 0 700 0 800 0 900 0 1000 0 1100 0 1200 0 1300 0 1400 0 1500.0 1600.0 1700.0 1800.0 1900.0 2000.0 2100.0 2200.0 2300.0 2400.0 2500.0 2600.0 2700.0 2800.0 2900.0 3000.0 3100.0 3200.0 3300.0 3400.0 3500.0 3600.0 3700.0 3800.0 3900.0 4000.0 4100.0 4200.0 4300 0 4400 0 4500 0 4600 0 4700 0 4800 0 4900 0 5000 0 5100 0 5200 0 5300 0 5400 0 5500.0 0 28.57 57 14 85 71 114 29 135 20 156 24 190 53 216 71 242 18 264 52 286 61 308.50 330.11 351.73 375.35 399.12 423.36 448.19 473.03 495.45 517.71 541.00 565.16 589.32 613.49 637.65 661.81 686.53 711.27 733.91 754.12 774.34 794.56 815.22 836.39 857 56 878 74 899 42 919 58 939 73 959 89 980 19 1000 63 1021 08 1041 52 1061 97 1081 99 1101 75 1121 52 1142 55 1164 71 1186 86 1209 02 1227.84 1243.98 2 86 31 43 6O 00 88 57 116 49 137 28 159 67 193 78 219 26 244 64 266 73 288.82 310.66 332.28 353.96 377.73 401.50 425.84 450.68 475.41 497.67 519.93 543.42 567.58 591.74 615.90 640.06 664.26 689.00 713.74 735.93 756.15 776.36 796.58 817.34 838.51 859 68 880 85 901 43 921 59 941 75 961 90 982 23 1002 68 1023 12 1043 57 1064 01 1083 96 1103 73 1123.50 1144.77 1166.92 1189.08 1211.23 1229.45 1245.60 5.71 34.29 62.86 91.43 118 57 139 36 163 10 196 33 221 80 246 85 268 94 291 03 312 82 334 44 356 33 380 10 403 88 428 32 453.16 477.64 499.90 522.16 545.83 570.00 594.16 618.32 642.48 666.73 691.47 716.22 737.95 758.17 778.38 798.60 819.46 840.63 861.80 882.97 903.45 923.61 943.76 963.92 984 28 1004 72 1025 17 1045 61 1066 06 1085 94 1105 71 1125 47 1146 98 1169 14 1191.29 1213.45 1231.07 1247.21 8.57 37.14 65.71 94.29 120.65 141.43 166.53 198 88 224 35 249 06 271 15 293 24 314 98 336 60 358 71 382 48 406 25 430 81 455 65 479 87 50213 52438 54825 572.41 596.57 620.73 644.90 669.21 693.95 718.69 739.97 760.19 780.40 800.62 821.57 842.75 863.92 885.O9 905.47 925.62 945.78 965.94 986.32 1006.77 1027.21 1047.66 1068 10 1087 92 1107 68 1127 45 1149 20 1171 35 1193 51 1215 66 1232 68 124883 TWO WAY TWO WAY TWO WAY TIME AT TIME AT TIME AT +4* +5* +6* SMPL/10 SMPL/10 SMPL/10 MS MS MS 11.43 40.00 68.57 97.14 122.73 143.51 169.96 201.42 226.90 251.27 273.36 295.45 317.15 338 76 361 09 384 86 408 63 433 29 458 13 482 09 504 35 526 61 550 67 574.83 598.99 623.15 647.31 671.68 696.42 721.16 741.99 762.21 782.43 802.64 823.69 844.86 866.03 887.20 907.48 927.64 947.80 967.95 988.37 1008.81 1029.26 1049.70 1070.13 1089.89 1109.66 1129.43 1151.41 1173.57 1195.72 1217.88 1234.30 1250.44 14.29 42.86 71.43 100.00 124.81 145.59 173.39 203.97 229.44 253.48 275.57 297 66 319 31 340 92 363 46 387 24 411 01 435 78 460 61 484 32 506 58 528 92 553 08 577 24 601 41 625 57 649.73 674.16 698.90 723.64 744.01 764.23 784.45 804.67 825.81 846.98 868.15 889.32 909.50 929.65 949.81 969.97 990.41 1010.86 1031.30 1051.75 1072.10 1091.87 1111.64 1131 47 1153 63 1175 78 1197 94 1219 76 1235 91 1252 06 17.14 45.71 74.29 102.86 126.88 147.67 176.81 206.52 231.99 255.69 277.78 299.85 321.47 343.08 365.84 389.61 413.42 438.26 463.10 486 54 508 80 531 34 555 50 579 66 603 82 627 98 652 14 676 63 701.37 725.82 746.04 766.25 786.47 806.76 827.93 849.10 870.27 891.36 911.51 931.67 951.83 972.01 992.46 1012.90 1033.35 1053.79 1074.08 1093.85 1113.61 1133.69 1155.84 1178.00 1200.15 1221.38 1237.52 1253.67 TWO WAY TIME AT + 7 * SMPL/10 20.00 48.57 77.14 105.71 128.96 149.75 180.24 209.07 234.54 257.90 279.99 302.02 323.63 345.24 368.22 391.99 415.91 440.74 465.58 488.77 511.03 533.75 557 91 582 08 606 24 630 40 654 56 679 10 703 84 727 84 748 06 768.27 788.49 808.87 830.04 851.21 872.38 893.37 913.53 933.69 953.84 974.05 994.50 1014.95 1035.39 1055.84 1076.06 1095.82 1115.59 1135.91 1158.06 1180.21 1202.37 1222.99 1239.14 1255.28 TWO WAY TIME AT + 8 * SMPL/10 MS 22.86 51.43 80.00 108.57 131.04 151.83 183.67 211.61 237.09 260.11 282.20 304.18 325.79 347.41 370.60 394.37 418.39 443.23 468 07 491 00 513 25 536 17 560 33 584 49 608 65 632 82 656 98 681 58 706 32 729 86 750 08 770.30 790.51 810.99 832.16 853.33 874.50 895.39 915.54 935.70 955.86 976.10 996.54 1016.99 1037.44 1057.88 1078.03 1097.80 1117.57 1138.12 1160.28 1182.43 1204.58 1224.61 1240.75 1256.90 TWO WAY TIME AT + 9 * SMPL/10 25.71 54.29 82.86 111.43 133.12 153.91 187.10 214.16 239.63 262.32 284.40 306.34 327.95 349.57 372.97 396.75 420.87 445.71 470.55 493.22 515.48 538.59 562.75 586 91 611 07 635 23 659 39 684 05 708 79 731 88 752 10 772 32 792 54 813 11 834.28 855.45 876.62 897.40 917.56 937.72 957.87 978.14 998.59 1019.03 1039.48 1059.93 1080.01 1099.78 1119.54 1140.34 1162.49 1184.65 1206.80 1226.22 1242.37 1258.51 COMPANY : FORCENERGY, INC. WELL : COFFEE CREEK #1 PAGE 3 VERTICAL TWO WAY TWO WAY TWO WAY TWO WAY TWO WAY TWO WAY TWO WAY TWO WAY TWO WAY TWO WAY DEPTH TIME AT TIME AT TIME AT TIME AT TIME AT TIME AT TIME AT TIME AT TIME AT TIME AT FROM + 0 * + 1 * + 2 * + 3 * + 4 * + 5 * + 6 * + 7 * + 8 * + 9 * SRD SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 FT MS MS MS MS MS MS MS MS MS MS 5600.0 1260.13 1261.74 1263.36 1264.97 1266.59 1268.20 1269.82 1271.43 1273.05 1274.66 5700.0 1276.27 1277.89 1279.50 1281.12 1282.73 1284.88 1287.10 1289.32 1291.54 1293.76 5800.0 1295.98 1298.20 1300.42 1302.64 1304.86 1307.08 1309 30 1311.52 1313.74 1315.96 5900.0 1318.18 1320.40 1322.62 1324.84 1327 06 1329.28 1331 6000.0 1340.38 1342.60 1344.82 1347.04 1349 26 1351 48 1353 6100.0 1362.58 1364.79 1367.01 1369.23 1371 26 1372 79 1374 6200.0 1380.44 1381.97 1383.50 1385.03 1386 56 1388 09 1389 6300.0 1395.73 1397.26 1398.79 1400.32 1401 85 1403 38 1404 6400.0 1411.03 1412.56 1414.09 1415.62 1417 15 1418 68 1420 6500.0 1426.33 1427.86 1429.39 1430.92 1432.47 1434 02 1435 6600.0 1441.78 1443.34 1444.89 1446.44 1448.00 1449 55 1451 6700.0 1457.31 1458.87 1460.42 1461.97 1463.52 1465 08 1466.63 1468.18 1469.74 1471.29 6800.0 1472.84 1474.39 1475.95 1477.50 1479.05 1480.61 1482.16 1483.71 1485.26 1486.82 6900.0 1488.37 1489.92 1491.48 1493.14 1494.86 1496.58 1498.30 1500.02 1501.75 1503 47 50 1333.72 1335.94 1338.16 70 1355.92 1358.14 1360.36 32 1375.85 1377.38 1378.91 62 1391.14 1392.67 1394.20 91 1406.44 1407.97 1409.50 21 1421.74 1423.27 1424.80 57 1437.13 1438.68 1440.23 10 1452.65 1454.21 1455.76 7100 7200 7300 7400 7500 7600 7700 7800 01614 79 1615 7900 01625 67 1626 8000.0 1636 55 1637 8100.0 1651 74 1653 8200.0 1671 00 1672 8300.0 1690 13 1691 0 1522.40 1524.12 1525.84 1527.56 1529.28 1531.00 1532.72 1534.44 1536.16 1537 0 1539.60 1541.32 1543.04 1544.77 1546.49 1548.21 1549.93 1551.65 1553.37 1555 0 1556.81 1558.53 1559.93 1561.09 1562.24 1563.40 1564.56 1565.71 1566.87 1568 0 1569.18 1570.34 1571.49 1572.65 1573.81 1574.96 1576.12 1577.28 1578.43 1579 0 1580.75 1581 90 1583.06 1584.22 1585.37 1586.53 1587.69 1588.84 1590.00 1591 0 1592.31 1593 0 1603 88 1605 67 88 09 O3 59 16 47 1594 621595 78 1596.94 1598.09 1599.25 1600.41 1601.56 1602.72 00 1606 88 1616 76 1627 64 1638 67 1655 93 1674 74 1693 8400.0 1705.83 1706.78 1707 74 1708 701709.66 1710 8500.0 1715.42 1716.38 1717 34 1718 29 1719.25 1720 8600.0 1725.01 1725.97 1726.93 1727.89 1728.85 1729 8700.0 1734.60 1735.56 1736.52 1737.48 1738.44 1739 8800.0 1744.71 1746.37 1748.03 1749.68 1751.34 1753 8900.0 1761.28 1762.94 1764.59 1766.25 1767.91 1769 9000.0 1777.85 1779.50 1781.16 1782.82 1784.47 80 1730 40 1740 00 1754 56 1771 09 1607 97 1618 85 1628 72 1639 59 1657 86 1676 34 1694 18 1608.26 1609.35 1610.44 1611.53 1612.62 1613.70 06 1619.14 1620.23 1621.32 1622.41 1623.49 1624.58 93 1630.02 1631.11 1632.20 1633.29 1634.37 1635.46 81 1640.90 1642.11 1644.03 1645.96 1647.89 1649.81 52 1659.45 1661.37 1663.30 1665.23 1667.15 1669.08 78 1678.71 1680.64 1682.56 1684.49 1686.42 1688.34 94 1696.55 1698 15 1699 75 1701.36 1702.96 1704.56 62 1711 58 1712.54 1713.50 1714.46 21 1721 17 1722.13 1723.09 1724.05 76 1731.72 1732.68 1733.64 36 1741.31 1742.27 1743.23 65 1756.31 1757.97 1759.62 22 1772.88 1774.53 1776.19 7000 0 1505.19 1506.91 1508.63 1510.35 1512.07 1513.79 1515.51 1517.23 1518.95 1520 Shot Hole Locations from Northern Geophysical NAD-271 ALAJSKA STATE PLANE ZONE 4 / US SURVEY FEET AZIMUTH & E AZIMUTH IS OLDNAME NE NW SW AVG WELL ,ISTANCE FROM WELL TO POINT ;~ELATIVE TO GRID, DISTANCE IN US SURVEY' FEET NEWNAME FAST NORTH AZIMUTH N 298446.72 2664110,28 352.8544 S 298437.23 2663903.26 346.8622 E 298527,31 2664023.55 1.7260 W 298343.80 2664093,81 341.8509 AVG 298438.77 2664032.73 350.6870 WELL 298513.80 2663575.20 0.0000 DIST 539.27 336.88 448.55 545.76 463.64 0.00 Well Deviation Survey from the client 2 3 4 5 $ 10 11 12 13 14 17 19 20 21 3,3 26 DEPTH 629 722 613 1000 1094 1192 15/8 1798 233O 2735 3704 4213 4740 506§ '~7.27 .' ~ 7742 8220 9722 DEG ;~EE 1 t4 1 f, 1 21 21 3 3 1~ 3 4 5 11 12. 10. 6. 2 '~ FORCENER(IY INC. COFFEE CREEK IN CORRE~I~ I$ 22,3 E,~ST DIR. 332 $;~ERR¥ GYRO 355 SPERRY 291 GYRO DATA Z77.3 2~7.3 262.3 272.3 264 3 TV~ 719~ 7242 76g7 8164 8655 9152 7 66544 ANALYST: 1-MAY-98 16:45:49 * SCHLUMBERGER * . * ******************** TRUE VERTICAL DEPTH REFERENCE: FS2A. PAGE 1 BOTTOM HOLE LOCATION DATA: (GLOBAL PA~RAMETERS ) BH COURSE LENGTH BHCL BOTTOM HOLE AZIMUTH BHAZI BH MEASURED DEPTH BH/V~D BH TRUE VERTICAL DEPTH BHTVD BH DISTANCE NORTH BHDN BH DISTANCE SOUTH B~DS BH DISTANCE EAST BHDE BH DISTANCE WEST BHDW TVD ALGORITHM TVDALG ( VALUE ) : 834.935 FT : 265.000 DEG : 10800.0 FT : 10732.6 FT : 374.395 FT · -374.395 FT : -746.287 FT : 746.287 FT : EXACT RADIUS OF CURVATURE METHOD. PAGE 2 * DEPTH * DEVIATION * AZIMUTH * TRUE * + NORTH * + EAST * COURSE * * * * VERTICAL * - SOUTH * - WEST * LENGTH * * * * DEPT~ * DRIFT * DRIFT * * FT * DEG * DEG * FT * FT * FT * FT . . . . . . . * 0 * 0 * 200.0 * 0 * 0 * 0 * 0 * 100.0 * .4 * 200.0 * 100.0 * -1.2 * -.5 * 1.3 * 200.0 * .8 * 200.0 * 200.0 * -2.4 * -,9 * 2.6 * 300.0 * 1.2 * 200.0 * 300.0 * -3.7 * -1.4 * 3.9 * 400.0 * 1.6 * 200.0 * 399.9 * -4.9 * -1.8 * 5.2 * 500.0 * 2.0 * 200.0 * 499.9 * -6,1 * -2.3 * 6.5 * 600.0 * 1.6 * 200.0 * 599.9 * -8.9 * -3.3 * 9.5 * 700.0 * 1.5 * 238.6 * 699.8 * -10.2 * -4.7 * 11.2 * 800.0 * 1.5 * 292.9 * 799.8 * -10.7 * -6,3 * 12,5 * 900,0 * 1.7 * 314.0 * 899.8 * -8.9 * -8.3 * 12,2 * 1000.0 * 2.0 * 330.0 * 999.7 * -6.8 * -10.3 * 12.3 * 1100.0 * 1.1 * 330.1 * 1099.7 * -4.5 * -11.6 * 12.4 * 1200.0 * 3.0 * 332.0 * 1199.6 * -1.3 * -13.3 * 13.4 * 1300.0 * 3.0 * 332.0 * 1299.5 * 3.5 * -15.9 * 16.2 * 1400.0 * 3.0 * 332.0 * 1399.3 * 8.2 * -18.4 * 20.1 * 1500.0 * 3.0 * 332.0 * 1499.2 * 12.9 * -20,9 * 24.6 * 1600.0 * 3.1 * 332.0 * 1599.1 * 17.7 * -23,4 * 29.3 * 1700.0 * 3.1 * 332.0 * 1698.9 * 22.4 * -25.9 * 34.2 * 1800.0 * 3.1 * 332.0 * 1798.8 * 27.1 * -28,4 * 39.3 * 1900.0 * 3.1 * 332.0 * 1898.6 * 31.8 * -30.9 * 44.4 * 2000.0 * 3.1 * 332.0 * 1998.5 * 36.6 * -33.5 * 49.6 * 2100.0 * 3.1 * 332.0 * 2098.3 * 41,3 * -36.0 * 54.8 * 2200.0 * 3,1 * 332.0 * 2198.2 * 46.0 * -38.5 * 60.0 * 2300.0 * 3.1 * 332.0 * 2298.1 * 50.8 * -41.0 * 65.2 * 2400.0 * 3.3 * 332.0 * 2397.9 * 56.2 * -43.9 * 71.3 * 2500.0 * 3.6 * 332.0 * 2497.7 * 61.9 * -46.9 * 77.6 * 2600.0 * 3.9 * 332,0 * 2597.4 * 67.5 * -49~9 * 84.0 * 2700.0 * 4.2 * 332.0 * 2697.2 * 73.2 * -52,9 * 90.4 * 2800.0 * 4.3 * 332.4 * 2797.0 * 79.5 * -56,2 * 97.4 * 2900.0 * 4.3 * 333.0 * 2896.7 * 86.2 * -59.5 * 104.7 * 3000.0 * 4 3 * 333.6 * 2996.4 * 92.8 * -62,8 * 112.0 * 3100.0 * 4 3 * 334.2 * 3096.2 * 99.4 * -66,1 * 119.4 * 3200.0 * 4 3 * 334.8 * 3195.9 * 106.1 * -69.4 * 126.7 * 3300.0 * 4 1 * 335.7 * 3295.6 * 112,4 * -72.2 * 133.6 * 3400~0 * 4 0 * 336.8 * 3395.4 * 118.6 * -74.8 * 140.3 * 3500.0 * 3 8 * 337.8 * 3495.2 * 124.9 * -77.4 * 146.9 * 3600.0 * 3.7 * 338.9 * 3595.0 * 131.1 * -80.0 * 153.6 * 3700.0 * 3.5 * 340.0 * 3694,7 * 137.3 * -82.7 * 160.3 * 3800.0 * 3.5 * 340.0 * 3794.5 * 143.3 * -84.8 * 166.5 * 3900.0 * 3,6 * 340.0 * 3894.3 * 149.2 * -87.0 * 172.7 * 4000.0 * 3.6 * 340.0 * 3994.1 * 155.2 * -89.2 * 178.9 * 4100.0 * 3.7 * 340.0 * 4093.9 * 161.1 * -91.3 * 185.2 * 4200.0 * 3.7 * 340.0 * 4193.7 * 167.0 * -93.5 * 191.4 * * 4300.0 * 3.9 * 340.0 * 4293.5 * 173.9 * -96.0 * 198.6 * * 4400.0 * 4.1 * 340.0 * 4393.2 * 180.8 * -98.5 * 205.9 * ************************************************************************** PAGE 3 * 4500.0 * * 4600.0 * * 4700.0 * * 4800.0 * * 4900.0 * * 5000.0 * * 5100.0 * * 5200.0 * * 5300.0 * * 5400.0 * * 5500.0 * * 5600.0 * * 5700.0 * * 5800.0 * * 5900.0 * * 6000.0 * * 6100.0 * * 6200 0 * * 6300 0 * * 6400 0 * * 6500 0 * * 6600 0 * * 6700 0 * * 6800.0 * * 6900.0 * * 7000.0 * * 7100.0 * * 7200.0 * * 7300.0 * * 7400.0 * * 7500.0 * * 7600.0 * * 7700.0 * * 7800.0 * * 7900.0 * * 8000.0 * * 8100.0 * * 8200.0 * * 8300 0 * * 8400 0 * * 8500 0 * * 8600 0 * * 8700 0 * * 8800 0 * * 8900 0 * * DEPTH * DEVIATION * AZIMUTH * TRUE * + NORTH * + EAST * COURSE * * * * * VERTICAL * - SOUTH * - WEST * LENGTH * * * * * DEPTH * DRIFT * DRIFT * * * FT * DEG * DEG * FT * FT * FT * FT * . . . . . . 4 3 * 340 0 * 4492 9 * 187.8 * -101.0 * 213.2 * 5 * 340 0 * 4592 7 * 340 0 * 4692 8 * 340 9 * 4792 9 * 342 3 * 4891 9 * 343 8 * 4991 0 * 345.2 * 5090 4 * 346.4 * 5190 6 * 194.8 * -103.6 * 220.6 * 3 * 201.7 * -106.1 * 227.9 * 0 * 209.4 * -108.7 * 235.9 * 7 * 217.5 * -111.2 * 244.2 * 3 * 225.6 * -113.7 * 252.6 * 9 * 233.9 * -116 2 * 261.2 * 4 * 243.5 * -118 3 * 270.7 * 5.7 * 347.6 * 5290.0 * 253.0 * -120 4 * 280 2 * 6.0 * 348.9 * 5389.5 * 262.6 * -122 4 * 289 7 * 6.3 * 350.1 * 5489.0 * 272.3 * -124 5 * 299 4 * 6.3 * 351.7 * 5588.4 * 283.3 * -125 9 * 310 0 * 6.4 * 353.3 * 5687.7 * 294.3 * -127.3 * 320 6 * 6.5 * 354.9 * 5787.1 * 305.3 * -128.8 * 331 3 * 6.7 * 343.6 * 5886.5 * 315.6 * -133.0 * 342.5 * 6.8 * 331.6 * 5985.8 * 325.9 * -137.4 * 353.7 * 7.0 * 319.9 * 6085.2 * 336.1 * -142.0 * 364.9 * 7.2 * 314.9 * 6184.3 * 343.4 * -152.8 * 375.8 * 7.5 * 310.0 * 6283.4 * 350.6 * -163.5 * 386.9 * 7.7 * 305.1 * 6382.6 * 357.9 * -174.3 * 398.1 * 8.0 * 300 2 * 6481 7 * 365.2 * -185.0 * 409.4 * 8 2 * 295 8 5 * 290 9 0 * 288 9 4 * 286 9 9 * 284 10 4 * 282 3 * 6580 8 * 6679 7 * 6778 7 * 6877 6 * 6975 6 * 7074 8 * 372.5 * -195.8 * 420.8 * 9 * 379.4 * -207.2 * 432.3 * 5 * 383.7 * -223.5 * 444.0 * 0 * 388.0 * -239.7 * 456.1 * 6 * 392.3 * -256.0 * 468.4 * 2 * 396.6 * -272.2 * 481.0 * 10.9 * 280.6 * 7172.7 * 400.8 * -288.5 * 493 8 * 11.1 * 276.5 * 7270.9 * 403.5 * -307.0 * 507 0 * 11.4 * 274.3 * 7368.8 * 404.1 * -327.2 * 520 0 * 11.7 * 272.2 * 7466.8 * 404.7 * -347.5 * 533 4 * 12.0 * 270.0 * 7564.7 * 405.3 * -367.8 * 547 3 * 12.4 * 267.9 * 7662.6 * 405.9 * -388.1 * 561 6 * 12.5 * 266.4 * 7760.3 * 404.9 * -409.1 * 575.6 * 12.5 * 265.3 * 7858.0 * 402.9 * -430.6 * 589.7 * 12.5 * 264.3 * 7955.6 * 400.8 * -452.1 * 604.2 * 12.5 * 263.3 * 8053.2 * 398.7 * -473.7 * 619.1 * 12.5 * 262.2 * 8150.9 * 396.7 * -495.2 * 634.5 * 12.2 * 262.0 * 8248.8 * 394.1 * -515.3 * 648.7 * 11.8 * 262.1 * 8346.8 * 391.3 * -535.0 * 662.9 * 11.4 * 262.2 * 8444.7 * 388.6 * -554.8 * 677.3 * 11.0 * 262.2 * 8542.7 * 385.9 * -574.5 * 692.1 * 10.6 * 262.3 * 8640.7 * 383.1 * -594.3 * 707.1 * 9.9 * 263.9 * 8739.4 * 381.8 * -610.0 * 719.6 * 9.1 * 265.8 * 8838.3 * 380.8 * -624.7 * 731.6 * · ****************** ** ***************************************************** PAGE 4 * DEPTH * DEVIATION * AZIMUTH * TRUE * + NORTH * + EAST * COURSE * . * * * VERTICAL * - SOUTH * - WEST * LENGTH * * * * * DEPTH * DRIFT * DRIFT * * * FT * DEG * DEG * FT * FT * FT * FT * . . . . . . . . * 9000.0 * 8.3 * 267.7 * 8937.2 * 379.7 * -639.4 * 743.6 * * 9100.0 * 7.5 * 269.7 * 9036.1 * 378.7 * -654.1 * 755.8 * * 9200.0 * 6.7 * 271.6 * 9135.0 * 377.7 * -668.8 * 768.0 * * 9300.0 * 5.8 * 270.9 * 9234.5 * 377.5 * -677.6 * 775.7 * * 9400.0 * 4.9 * 269.4 * 9334.2 * 377.6 * -685.0 * 782.2 * * 9500.0 * 4.0 * 268.0 * 9433.9 * 377.6 * -692.4 * 788.7 * * 9600.0 * 3.1 * 266.5 * 9533.6 * 377.6 * -699.8 * 795.2 * * 9700.0 * 2.2 * 265.1 * 9633.3 * 377.7 * -707.2 * 801.7 * * 9800.0 * 2.0 * 265.0 * 9733.2 * 377.4 * -711.5 * 805.5 * * 9900.0 * 2.0 * 265.0 * 9833.1 * 377.1 * -715.0 * 808.4 * * 10000.0 * 2.0 * 265.0 * 9933.1 * 376.8 * -718.5 * 811.3 * * 10100.0 * 2.0 * 265.0 * 10033 0 * 376.5 * -722.0 * 814.3 * * 10200.0 * 2.0 * 265.0 * 10133 0 * 376.2 * -725.4 * 817.2 * * 10300.0 * 2.0 * 265.0 * 10232 9 * 375.9 * -728.9 * 820.1 * * 10400.0 * 2.0 * 265.0 * 10332 8 * 375.6 * -732.4 * 823.1 * * 10500.0 * 2.0 * 265.0 * 10432 8 * 375.3 * -735.9 * 826.0 * * 10600.0 * 2.0 * 265.0 * 10532 7 * 375.0 * -739.3 * 829.0 * * 10700.0 * 2.0 * 265.0 * 10632.6 * 374.7 * -742.8 * 832.0 * * 10800.0 * 2.0 * 265.0 * 10732.6 * 374.4 * -746.3 * 834.9 * Force , ergy Inc March 31, 1998 Alaska Oil and Gas Conservation Commission Mr. Bob Crandall 3001 Porcupine Drive Anchorage, Alaska 99501 Re-' Annular Injection Summary Coffee Creek #1 Dear Mr. Crandall: This letter is in reference to the annular injection on the Coffee Creek #1 well. The purpose of this report is to document and summarize the annular injection project. The 9 5/8" casing was run with a ported sub at 4,013'. This sub was positioned above the first stage cement and below the cement set with the DV stage collar. Due to poor mud properties, we injected most of our mud volume at that point and made new volume to drill out in 8 1/2" hole. Upon completion of our injection, we ran a temperature log to determine which zones had taken fluid. The following synopsis discusses these issues. If there are any questions, please contact me at 258-8600. Paul White Drilling Manager Forcenergy Inc. Attachments' Injection report CBL/VDL & CET logs Temperature logs Well schematic HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 TELEPHONE 305/856-8500 FAX REGIONAL OFFICE 310 K Street Suite 700 TELEPHONE 907/258-8600 FAX 9 5/8" Casing Job The 9 5/8" casing was run to a depth of 6,720' on March 19, 1998. 9 5/8" 47//L-80, BTC. The configuration of the string is as follows: DV Stage Collar 2,812' VAM Ported Collar 4,013' Landing Collar 6,638 Float Collar 6,718' Float Shoe 6,720' This casing was 9 5/8" Cement Job The 9 5/8" cement job was performed on March 20, 1998 by BJ Services. No significant problems were encountered during this process. The first stage went as follows: 1) Pump 50 bbls of water pre-flush 2) Pump 187 sacks of lead "G" 12.5 ppg cement 3) Pump 204 sacks of tail "G" 15.6 ppg cement 4) Pump 10 bbls of water 5) Displace with 486 bbls of mud 6) Bump Plug The second stage went as follows: 1) Open DV Collar 2) Circulate hole clean 3) Pump 25 bbls of water pre-flush 4) Pump 446 sack of "G" 12.5 ppg cement 5) Pump 15 bbls of water 6) Displace with 206 bbls of mud 7) Bump Plug 8) Close DV collar Injection On March 23, 1998, we ran in the hole with an injection packer to the Vam ported sub. The packer was tested and the ported sub was opened. A total of 1931 bbls of waste drilling mud was injected at two different rates and pressures. These were 2 bbl/min at 600 psi and 7.5 bbl/min at 1100 psi. Immediately following the injection, the ported sub was closed at the casing was tested to 2,700 psi. Temperature Log and Conclusions F611owing the mud injection, a temperature log was run by Schlumberger on wireline to determine which zones took the injected fluids. This log shows the formation temperature deviations from a standard geothermal gradient. Any rock the took fluid shows up as an abnormally cool area, compared with the remainder of the hole. Our conclusions based on the temperature logs, correlated with the previous mud logs are as follows: 1) Major Injection Zone #1 - 3,700' to 3,800' 2) Major Injection Zone//2 - 3,960' to 4,060' 3) Minor flow occurred above, up to 3,200' 4) Minor flow occurred below, down to 4,220' 5) No flow penetrated below a barrier in the annulus at 4,220' Coffee Creek #1 Intermediate Casing Design 20"133#,L-80 13 3/8" 68#, L-80 BTC 90' TOC 1160' 1219' DV Collar 2812' Ported Collar 4013' 9 5/8" 47#, L-80 BTC 7-5/8" 29.04#, L-80 TOC 5260' 6720' 9500' Coffee Creek # 1 Intermediate Casing Design 20"133#, L-80 13 3/8" 68#, L-80 BTC (~ 90' MD, 90' TVD TOC ~: 500' @ 1219' MD, 1219' TVD Collar ;~. 2800' FO Collar (~i 4800' 9 5/8" 47#, L-80 BTC 7-5/8" 29.04~, L-80 TOC @.5300' 6720' MD, 6720' TVD 9500' MD, 9500' TVD AOGCC Cortr--rdn~ial C~er Shed Page1 LEAK OFF t~ll Hame COFFEE CREEK # 1 Perm t Io Dr II # 97-219 ~.ate 3/2:~m8 Operator, ~ORCENE~Y INC. Rel~Unlt N[~AT C~ny ~p~~ M. MURKY Rig ~DI ~ ........ ~O.G.C.q~ ln~~ L~ OFF ~tA " ~ud W~Oht in ~e [P,P.G.~I ;~ ~e Hqle T.D. 1219 S,G. ~ M~ in ~e tl.3 ,~1 Gm~ ~ M~ in ~e ~ ~110~ TVD S~ ~m ~ ~k ~ H~~~ H~d_d Mm suda~~~e~'o ~ B.H.P. ~T.D (~h L~[~~m,~i~) ~d~ ~ ~ to ;10,~n~) ~ E~i~ra!~ M~ ,~'~ S~ ~m ~,~p (1 mince} ~ E~ival~ M~ s~fic ~v[W ~.92 ~d~ ~. {~li,z~) ~ Eq~v~ M~ ~M ~ ~k (P.P.G.) 16.01 '- C~E,TS Is ~is a_~ t~A NO ~i~ ~m~ ~HP m p~ T.D. If Yes ~at ~ I~ t~ E~ ? T.V.D.,.~ T~ V~ume ~ q~d ~m~ d~ L,p.-. 4,~ M.W. n~ to ~la~ ~ls m~ "l~e ~ ~uid ~~ ~ ~e~ ~ M~ ~~ ~11~ for in ~e~v 6ce~ ~o~ ~ ~o~P~ ,. ....... ............ .... , ,, --,, ,, .......... .... L~kofrl B C D I I I . 0 01)3 O.'l] 0.~ 0.~' i. O0 1.~ ].~D 1,7~ 2,00 22-I 2.~0 lt."/~ 3.01 3.2:~ :l.~l l."/l 4.00 43,,~ 4.:~0 4./'!, ~J..O0 :~.,~ ~,.~0 ~J.'iU- ~,00 if3,,5 BARREL~ or STROKES -,u--Max L.O.P- Forcenergy March 17, 1998 Alaska Oil and Gas Conservation Commission Mr. Chuck Scheve 3001 Porcupine Drive Anchorage, Alaska 99501 Coffee Creek//1 DUPLICATE Dear Mr. Scheve' This is a follow-up Sundry Notice confirming our phone conversation with you and Bob Crandall on Tuesday March 17, 1998. A casing schematic showing our design is attached to this letter. The 12 IA" hole section was TD'd at 6,720' and logs have been run across this section. Our plan for the 9 5/8" casing is to run a "Port Tool" at approximately 4,800' This would allow for the injection of Class II drilling fluids in the 9 5/8" annulus between the top of cement at 5,300' and the DV stage collar at 2,800'. Logs indicate that there are several permeable sand formations in this zone that will take fluid readily. If there are any questions, please contact me at 258-8600. Paul White Drilling Manager Forcenergy Inc. HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 TELEPHONE 305/856-8500 FAX REGIONAL OFFICE 310 K Street Suite 700 TELEPHONE 907/258-8600 FAX Forcenergy inc March 16, 1998 Alaska Oil and Gas Conservation Commission Mr. Chuck Scheve 3001 Porcupine Drive Anchorage, Alaska 99501 Re: 9 >i8" Casing Point Depth Change Coffee Creek #1 Dear Mr. Scheve' This is just a follow-up letter cop£1rming our phone conversation with you op. Friday March 13, 1998. What was verbally approved by you was to drill the 12 ¼" hole section to 7,000' vs the plarmed 6,500' The reason for this was that we were lower on the structure than expected. The drilling was stopped at a depth of 6,720', where we began our intermediate logging mn. Thank you for you assistance in expediting this matter. If there are any questions, please contact me at 258-8600. Paul White Drilling Manager Forcenergy Inc. RECEIVED MAR 19 t998 Alas~ Oil & Gas Cons. Commission ~chorage HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 TELEPHONE 305/856-8500 FAX REGIONAL OFFICE 310 K Street Suite 700 TELEPHONE 907/258-8600 FAX STATE OF ALASKA ALASKA OIL ,.,,ND GAS CONSERVATION CU~¢IMISSION APPLICATION FOR SUNDRY APPROVALS i Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: X Pull tubing: Variance: Perforate: Other: 2. Name of Operator Forcenergy Inc. 3. Address 310 K Street, Suite 700 Anchorage, Alaska 99501 4. Location of well at surface 527' FWL 710' FSL Sec 19 T14N R10W At top of productive interval 527' FWL 710' FSL Sec 19 T14N R10W At effective depth 527' FWL 710' FSL Sec 19 T14N R10W At total depth 527' FWL 710' FSL Sec 19 T14N R10W 5. Type of well: Development: Exploratory: X Stratigraphic: Service: 6. Datum elevation (DF or KB) 620' KB 7. Unit or Property name Coffee Creek 8. Well number #1 9. Permit number 97-219 10. APl number 50- 283-20094 11. Field/Pool Wildcat feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 90' Surface 1,219' Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 5,695' 5,695' feet feet feet feet Plugs (measured) Junk(measured) Size Cemented Measured depth True vertical depth 20" N/A 90' 90' 13 3/8" To Surface 1,219' 1,219' ORI6INAL 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: April 4, 1998 16. If proposal well verbally approved: Oil: Bob Crandall March 10, 1998 Namel~approver Date approved Service: 17. ! herel~y ~ertify that the foregoing is true and correct to the best of my knowledge. Sign ed.'~V~ _~ Paul White Gas: X , , Suspended: Title: Drilling Manager FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance~ Mechanical Integrity Test Subsequent form required 10- ~'~¢) -,ed Approved by order of the Commissioner D;.',v;d W, Johnston Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ., '-1' 1 I '~) I' 1 i' I .-. I .-. i . .-. I . "1 i . .-. ~ ~ I ~ I ~ F )l I-- i- - i- - ~ k, ~ -' I I I I I ~ I r I !]//2 ,16 ,15 ,15 ,lo lk8,1 7 I - I I I I I ~ ~--t .... ~ .... ~ .... ~ .......... ~--- , .... ~-- I I I ~ ~ I I I F .... ~- --T ..... ~ .... ~ ............. I L___~ ~ ~ - ; -' ~ .... ~ .... ~~-~-- I I I , , , , ~ I I I 19 ,2~ ,2~, ~1 I I ~ f Force .ergy inc March 10, 1998 Alaska Oil and Gas Conservation Commission Mr. Bob Crandall 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approvals ( Form 10-403) Coffee Creek #1 Dear Mr. Crandall' We are currently drilling 12 ~A" hole in the Coffee Creek #1 well, just above the 9 5/8" casing point. This well is to be drilled as a straight hole. Our original outline procedure, we indicated that the inclination of the wellbore would be held to 5 degrees or less. The well is tending to drift up-dip (northwesterly), and has in the last couple surveys increased to over 5 degrees of inclination. The drift to the northwest is of a geologic advantage. As per our phone conversation, we intend to mn a multi-shot gyro across the 12 ~,~" hole once it is completed and then mn single shot surveys in the 8 1/2" hole at 500' intervals. If there are any questions, please contact me at 258-8600. Paul White Drilling Manager Forcenergy Inc. ': HEADQUARTERS Forcenergy Center TELEPHONE 2730 SW 3rd Avenue 3051856-8500 Suite 800 FAX REGIONAL OFFICE TELEPHONE 310 K Street 907/258-8600 Suite 700 FAX AOGCC Confidential Leakoffl Page 1 "1'1 E3 C~ Frl Z IT1 C III - i . '~-~;~ · . ..... _ _ 123,4:5 e ? SHUT. I~ TIME IN ~ (lot -x-) 10 .~mcxmd -a-Max L.O.P, t).q(~ ~ o.~ 0.~ [.~0 1.25 1,~0 1.7~ 2.00 2,~ ~.~0 ,Z?~ 3,0(1 1,,35 1.,~0 3.7~ 4.~ 4,2~ 4,~) 4,Tls ~.0Q ~ i:~o ~,,~ 6,00 6.~ BARREL'S ~' STROKE8 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnson, DATE: Chairman /' February 22,1998 THRU: Blair Wondzeii, ~.1~,.1t FII.E NO: .doc P. !. Supervisor 3-tt Confidential: Yes_, No:X, Attachment Only... SUBJECT: FROM: Larry Wade, Petroleum Inspector BOP Test PTD 97-219 February 22; Got a call from Force Energy Co. man, Mike Murray at 7 AM and we set up a flight to Beluga at 10 AM. I was picked up at the airport and driven 22 miles to the drilling location. The location is a time capsule with a small flat carved out of the forest and a rig that had been stacked for 10 years without ever drilling a hole. One of the Cat 398 driver motor had 22 hours on it. Everything except the mud system is 60's technology. The cuttings from the well are conveyed to a cement truck where it is mixed with a cement slurry and dumped in a pit. After the well is TD'ed they plan to put a concrete cap on it and its done. The BOP test went Well except for one flange leak on the choke line. Other then a new rig, new crew and an unfamiliarity with doing BOP tests, I thought it went well. The Co. man said that a priority would be daily drills. I caught the flight back and landed in Anchorage at 6:30 PM. SUMMARY:.. I witnessed the initial BOP test on Inlet Drilling Rig #1 with 0 failures. Attachment:a99gbvfe.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: X Workover:~ Drlg Contractor: Inlet Drilling Rig No. 1 PTD # Operator: Force Energy Rep.' Well Name: Coffee Creek #1 Rig Rep.' Casing Size: 13 3/8" Set (~ 2,000 Location: Sec. ... Test: Initial '~. Weekly .... Other ,.. g7-219 DATE: February 22,1998 Rig Ph.# 244-2983 Mike Murray Mike Leslie lg T. 14N R. lOW Meridian ....... : .............. : . : ;L ; : ............... Test Well Sign X Drl. Rig ok Hazard Sec. MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location X , , Standing Order Posted X FLOOR SAFETY VALVES: Upper Kelly /IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. 1 _. 1 , Pressure P/F 250/3,000 IP 250/3,000 ! ~ 250/3,000. .i'P ' BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. VaNes 2 HCR Valves Kill Line Valves 2 Check Vaive '0 Quart. Test Press. 250/3,000 n/a 250/3,000 1 250/3,000 1 250/3,00O 250/3,000 P/F P P P 250/3,000 P CHOKE MANIFOLD: No. Valves 8 No. Flanges , ,15 Manual Chokes ~ Hydraulic Chokes ~ ,,L Test Pressure 250/3,000 250/3, OO0 Functioned Functioned P/F ACCUMULATOR SYSTEM: 250/3,000 System Pressure 3000 ! Pressure After Closure 1700! . MUD SYSTEM: Visual Alarm 200 psi Attained After Closure .___.- minutes..'1~ . sec. Trip Tank X X System Pressure Attained 2 minutes 53 sec. Pit Level Indicators X X Blind Switch Covers: Master: X Remote: X Flow Indicator X X Nitgn. Btl's: 2300, 2450 Meth Gas Detector X X 2350, 2 ~ 50 Psig. H2S Gas Detector X "X" Number of Failures: 0 ,Test Time: 5.0 Hours. Number of valves tested 16 Repair or Replacement of Failec Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. !. Supervisor at 279-1433 REMARKS: Distribution: orig-Wetl File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: W'rtnessed By: Larry Wade Ft-O21L (Rev. 12/94) a99gbvfe.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johns_J,~, DATE: Chairman THRU: Blair Wonclzell, '~-~J~'~ FILE NO: P. I. Supervisor -?~".~,=~ FROM: Chuck Scheve, "' ~ SUBJECT: Petroleum Inspector February 9, 1998 e99kbife. DOC Diverter inspection Sterling AK. Rig 1 Coffee Creek #1 PTD 97-219 Monday February 9, 1998: I traveled to Forcenergy's Coffee Creek #1 location to witness the Diverter function test on Sterling Alaska Drilling's Rig 1. The function test of the Diverter assembly went well. The 10" full opening ball valve opened well ahead of the twenty inch annular preventer closing. The accumulator had a recharge time of 2 minutes 20 seconds. I walked the 10" vent line and found a good solid construction of ample length and solidly anchored. The location though crowded was well organized allowing good access to the rig. The gas detection system and pit volume monitoring system were not completely rigged up at the time of this inspection. Company Rep Ray Springer assured me these systems would be operating properly prior to drilling out the conductor on this well. SUMMARY: I witnessed the Diverter function test on Sterling Alaska Drilling's Rig #1 in advance of drilling Forcenergy's Coffee Creek #1 exploration well. Attachments: e99kbife. XLS X Unclassified Ddg Contractor: Operator: Well Name: Location: Sec. STATE OF ALASKA - . ALASKA OiL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Sterlin~l Alaska Drilling Forcenergy Coffee Creek #1 19 T. 14N R. Date: Operation: Development Exploratory: Rig No. 1 PTD # 97-219 Rig Ph. # Oper. Rep.: Ray Springer Rig Rep.' George Brewster 10W Merdian Seward 2/9/98 X 659-4644 MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok Reserve Pit: n/a Well Sign: ok (Gen.) Ddg. Rig: ok Flare Pit: n/a DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Tums Targeted / Long Radius: 2O yes yes in. in. 130 1 30 ft. yes yes yes NIA ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 3,000 1600 min. 28 2 min. 20 4 ~} 1900 MUD SYSTEM INSPECTION: Tdp Tank: Mud Pits: Flow Monitor: Light Alarm GAS DETECTORS: Methane Hydrogen Sulfide: Light Alarm psig psig sec. sec. psig IMud Pits 10" diverter line 10" Full opening ball valve J30' long =~ ,,.,.~'-10" FULL OPENING KNIFE OI [~] VALVES 20" diverter 1 diverter line 130' long Non Compliance Items 0 Repair Items Within 0 Day (s) And contact the Inspector @ 659-3607 Remarks: Gas detection and Mud monitorin~ equipment not ri~l~led up at this time but will be operational prior to spud Distribution odg. - Well File c - Oper/Rep c - Database c - Trip Rpt File c - Inspector AOGCC REP.: OPERATOR REP.: e99kbife Chuck Scheve Ray SprJnger DVTRINSP.XLT (REV. 1/94) 02/09/98 MON 14:38 FAX 907 258 8601 FORCENERGY ALASKA Force ,-,ergy lnc February 9, 1998 Alaska Oil and Gas Conservation Commission Mr. Blair Wondzell 3001 Porcupine Drive Anchorage, Alaska 99501 Application for Sundry Approvals ( Form 10-403) Coffee Creek #1 Dear Mr. Wondzell: This letter is in reference to the Application for Sundry Approval that was submitted February 6, i998, concerning Fomenergy's Coffee Creek #1 well. There is some concern that the kick tolerance while drilling the 12 IA" hole will be abnormally small if a good leak-off is not obtained on the 13 3/8" casing shoe. We propose to perform two successive Leak of Tests to the 13 3/8" shoe to determine exactly what our limits are in the 12 Iff" hole. If a good leak-off is not obtained, one possible solution would be to perform a cement squeeze on the casing shoe. If all else fails, the 9 5/8" casing depth will be adjusted accordingly, to provide a safe margin on the kick tolerance. If there are any questions, please contact me at 258-8600. Rob Stinson Drilling Engineer Forcenergy Inc. Oil & G~ Cons. Commi~ion ~homge HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 Miami, Florida 33129-2237 TELEPHONE 30,,/856-8500 FAX 305/856-4300 REGIONAL OFFICE 310 K Street Suite 700 Anchorage, Alaska 99501 TELEPHONE 907/258-8600 FAX 907/258-8601 02/06/98 FRI 16' 4 0 FAX 9 0 7 2 $ 8 $ 6 01 FORCENERGY ALASKA STATE OF ALASKA ALASKA Oil_ AND GAS CONSERVATION C( --MMISSION APPLICATION FOR SUNDRY APPROVALS OO3 1. Type' of Request: Abandon: Suspend: "' Operatlon shutd~vm Re-enter suspended well: Alter casin9; × Repair well; Plugging: Time extension: Stimulate: C, h, ange approved p-'"~og...mm: X Pull tu'--'~Ing: VariAnce; PsrfOrat~"~.'.' Other: -- 2. i~lame of Operator 5, Typ'~'of well; 6. Da{um elevation (DF or KB) '" Force.n. ergy Inc, ,., , Development: 620' KB feet 3. Address Exploratory.' ~ '~. Unit or Propert~ ~e 310 K Street, Suite 700 $1rafigraphic: Coffee Creek Anchorage, Alaska 99501 Service: 4. Loca{ion of well at surface ........... 8. Well number: ........ 527' FWL 710' FSL Sec 19 T14N R10W #1 At top of productive interval '~, Permit number .............. 527' FWL 710' FSL Sec 19 T14N R10W 97-219 At effective depth 10, APl numb~ 527' FWL 710' FSL Sec 19 T14N R1OW 50- 283-20094 At total depth 11, ~eld/Pool 527' FWL 710' FSL Sec 19 T14N Rt0W Wildcat 12, 'Present well condition sU'~lmary ........... Total depth: measured feet Plugs (measured) true vertical feet Efl'ectlve depth; measured feet Junk (measured) true vertical feet Casing Length Size Cerllented Measured depth True vertical depth Structural Conductor Surface Production ..... Perf~ir;t~rO~ depth: measuredORI61NAL true vertical .'~,'.4.$k~ Oi!.~° d~S O0~S, Cornmissior~ Tubing (si~e, grade, and measured depth) Packers and 8SSV (type and measured depth) 13, Attache~'e"nts O~soription summary of proi~osah X ...... De--tailed operations program; BOP sketch; 14, 'Estimated date for comm;~'~cing operation 15; S~us of well classification as; ' February 9, 1998 16,'1f proposal Well verbally a~proved; " Oil; Gas: Suspended: Name of approver Date approved ,~ Service; 17', '1 hereb~~~e best of my knowledge. ' ........ Signed;v '-"' ~ -'l~bert Stlnson -F~tle; Drilling Engineer ..... Date; 216/98 FOR COMMISSION USE ONLY Conditions'0f Plugappr°val"integrltyNC;ii~ CommiSsiOnBop$O represer;~atlveTest may witnesSLocation clearance"' {Approval No, ~_~ Mechanical Integrity Test.__._. Subsequent form required 10- ~--~'~' OaYkt W. dohaston Approved by order Of the Commissioner Commissioner Date C;~ "' ~'" Form 10-403 Rev 06/15~88 rr~,¢ed OO9~ SUBMIT IN TRIPLICATE 02/06/98 FRI 16:40 FAX 907 258 8601 FORCENERGY ALASKA ~004 COFFEE CREEK #1 PRESSURE INFORMATION Procedure for Cal,culatin. R_ Anticipated Surface Pressure ASP is determined as the lesser of 1 ) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) the wellbore full of gas from bottom hole to surface. 1) ASP = ((FG x .052)- 0,115) x Dc where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ff 0.115 = gas gradient in psi/ft Dc -- true vertical Depth of casing seat in ff RKB OR 2)ASP= (PP x 0.052 x D) - (0,I 15 x D) where; PP = Formation Pore Pressure ( in lb/gal equivalent mud weight) at the next casing point which is tied back to surface or at TD (total depth) D = Depth of the deepest point where the caslng will be exposed. ~..SP. Calculations Drilling below surface casing (13-318" at 1000') Pore pressure = 9.3 ppg EMW, Anticipated Fracture Gradient - 13.8 ppg EMW, ASP or = ((FG x .052) - 0.115) x D = ((13.8 x .052) - 0.115) x 1000' = 603 psi ASP (PP x 0.052 x D)-(0.115 x D) (9.3 x.052 x 6500)-(,115 x 6500') 2176 - 517 2396.psi Therefore ASP = 603 psi Drilling below intermediate casing (9-5/8' at 6500') Pore pressure = 9.3 ppg EMW, Anticipated Fracture Gradient = 15,6 ppg EMW, ASP or ((FG x .052) - 0.115)x D ((15,6 x .052) - 0,115) x 6500' 4526 psi 02/06/98 FR! 16:40 FAX 907 258 8601 FORCENERGY ALASKA ~oo5 ASP = (PP x 0.052 x D)- (0.115 x D) = (9.3 x .052 x 9500) -(.115 x 9600') = 4594 - 1093 = 3501 psi Therefore ASP = 3501 psi 02/06/98 FRI 16:40 FAX 907 258 8601 FORCENERGY ALASKA ~uuz Fo .e y Inc February 6, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approvals ( Form 10-403) Coffee Creek #1 Enclosed is Forcenergy's Application for Sundry Approval for changes to the casing program and total depth of Coffee Creek #1. The latest geophysical information and interpretation has indicated the possibility of gas zones between 1,500' MD/TVD and 2,000' MD/TVD. Surface pipe is requested to be set itt 1,000' MD/TVD with full BOPE in order to penetrate these sands safely_ Forcenergy recognizes that the 13 3/8" x 9 5/8" annulus will no longer be available for drilling fluids injection due to exposed fresh water sands. The 9 5/8" setting depth is requested deepened to 6,500' MD/TVD from 4,500' MD/TVD in order to better evaluate the primary target of this welt. A cementing stage collar will be used to bring cement from 2000' MD/TVD to inside the 13 3/8" shoe. The additional information also suggests potential below the previously approved total depth of 7,000' MD/TVD. A change in total depth is requested to 9,500' MD/TVD. Thc new maximum anticipated pressures and casing design calculations are attached, in addition to the revised cement program. All other inlbrmation remains the same. If there are any questions, please contact me at 258-8600. Paul White Drilling Manager Forcenergy Inc. HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 Miami, Florida 33129-22~37 TELEPHONE 305/856.8500 FAX 305/856-4300 ,._ REGIONAL OFFICE 310 K Street Suit~ 700 Anchorage, Alaska 99501 TELEPHONE 907/258-8600 FAX 907/258-8601 02/06/98 FRI 16:40 FAX 907 258 8601 FORCENERGY ALASKA ~oo6 Casing Pro,ram COFFEE CREEK #1 CASING DESIGN Setting Depth Size Specifications Top Bottom Hole Casing Weight Grade Coupling Length MD TVD MD -I'VD Driven 20" 133 K,55 Welde 100' Surf. Surf, 90' 90' 'I 7%" 13-3/8" 72 L-80 BT&C 1000' Surf. Surf. 1000' 1000' 12¼" 9-5/8" 47 L-80 BT&C 6500' Surf, Surf. 6500' 6~00' 8W' 7-5/8" 29.7 L-80 FL4 3300' 6200' 6200' 9500' 9~00' Casing Properties S/zc Type Burst Collapse Tension Torque 13-3/8" 72 ppf L~80 BTC 5,380 psi 2,670 psi 1,561,000 lbs to base of triangle 9-5/8" 47 ppf L.80 BTC 6,870 psi 4,750 psi 1,086,000 lbs to base of triangle 7-5/8" 29.7 ppf L-80 FL-4S 6,890 psi 4,790 psi 511,000 lbs 7530 ft-lbs 2.0" Conductor Casin~ This casing string is not designed to hold pressure. _'1_3-318" Surface Casing. 72~..L~80 BT&C @ t000' MD/TVD Basis: Pore pressure at casing shoe = 9.3 ppg EMW (0.484 psi/E) Mud weight at casing shoe = 9.5 ppg (0.494 psi/fi), buoyancy factor: .855 Fracture Gradient at casing shoe = 13.8 ppg EMW Pore pressure at next casing point (4,500') = 9.3 ppg EMW (0.484 psi/E) Tension = buoyed weight of casing = I000' x 72# x .855 b.f. -- 62K Casing Rated = 1661K Safety Factor: 26.7 Burst = anticipated surface pressure (lesser of full column of gas from next casing point or full column of gas from the fracture gradient) = ((13.8 x .052)-0.115) x 1000'-- 603 psi or = (9.3 x .052 x 6500) - (.115 x 6500') = 2395 psi ASP -- 603 psi Casing rated 5380 psi Safety Factor = 8.9 Collapse = full evacuation -- (9.5 x ,052 x 1000') = 494 psi Casing rated = 2670 psi Safety Factor- 5.4 02/06/98 FRI 16:41 FAX 907 258 8601 FORCENERG¥ ALASKA ~uu/ 9-5/8".lntermediate/_Productio~3 Casing 47# L-80 BT&CJ~ 6500' MD/TVD Basis: Pore pressure at casing shoe = 9.3 ppg EMW (0.484 psi/fi) Mud weight at casing shoe = 9.9 ppg (0.515 psi/fi) buoyancy factor = .849 Fracture Gradient at casing shoe = 15.6 ppg EMW Pore pressure at next casing point (9,500') = 9.3 ppg EMW (0,484 psi/fi) Tension = buoyed weight of casing = 6,500' x 47# x .849 b,f. = 260K Casing Rated Safety Factor = 1086K =4.17 Burst = as production casing the design basis is a full column of gas from total depth. = (9.3 x .052 x 9500)- (.115 x 9500') = 3501 psi Casing rated 6870 psi Safety Factor = 1.96 Collapse = full evacuation = (9.9 x .052 x 6500')- (.115 x 6500) - 2590 psi Casing rated = 4750 psi Safety Factor = 1.82 7-518" Production Liner 29.7# Lw80 FL-4S. ,from 6.20.0 to 9.500' MD/'rv_D Basis: Pore pressure at casing shoe = 9.3 ppg EMW (0.484 psi/fi) Mud weight at casing shoe = 10.0 ppg (0.520 psi/fi) buoyancy factor = ,847 Tension = buoyed weight of casing = 3300' x 29.7# x .847 b,f, = 83K Casing Rated = 511K Safety Factor = 6.15 Burst = a full column of gas from total depth to the top of the liner less the pore pressure backup. internal pressure = (9.3 x .052 x 9500) - (.I 15 x 3300') = 4215 psi External pressure = (9.3 x ,052 x 6200) = 2998 psi Internal-external = 4215-2998 = 12t7 psi Casing rated 6890 psi Safety Factor -- 5.6 Collapse - full evacuation (production) = (9,3 x .052 x 9500')- (,115 x 9500) = 3501 psi Casing rated = 4790 psi Safety Factor = 1.36 02/06/98 FRI 16:41 FAX 907 258 8601 COFFEE CREEK #1 CEMENT DESIGN Cement Program Casing Cement Type Depth Density Yield mix wtr W/L Free Water 13-3/8" Lead Lead 500' to surface 12.5 2.06 fi3/sx 11..8 n/c 0 Tail G 1000'-500' 15.6 1.I6 ft3/sx 5.11 n/c 0 9-5/$" Lead Lead 6000'-5000' 12.5 2.06 ~/sx 11,8 n/c 0 Tail G 6500'-6000' 15.6 1,15 fl~/sx 4.95 n/c 0 DV Lead 2000'-500' 12.5 2,06 fl3/sx 11.8 n/c 0 7-5/8" liner G 9500'-6200' 15,6 1.15 f~/sx 4,95 150 cc/30 mia 0 13-3/8" surface casing Cement to surface, use inner string method, cement with filler until cement contaminated mud returns reach the surface then pump 500' of tail, Samples of the rig site cement and the mix water to be used should be sent the lab several days before the job. The recipe should be modified based on the results of the tests Prcflush- 10 bbl of water, Lead - Class G + 2% A.2 + 0.4% CD-32 + 0,5% A-7 * 1 ghs FP-61 thickening time 6:00 hfs Tail - Class G + 0.25% CD~32 + 1.3% A-7 .I- 1 ghs FP-6L Thickening time 4:00 his 9-5/8" Production / Intermediate casing - TWO STAGE First Stage Cement with 1000' Lead and 500' of tail cement through shoe, If there are shows in the 12 %" hole the program will be altered to ensure tell cement coverage. ,Second `stage Through DV stage collar at 2000' pump lead type cement for coverage to 500' within the 13 3~8" shoe, Preflush - 50 bbls water containing 1% MCS-A Lead- Class G + 2% A-2 + 0.4% CD-32 + 0.5% A-7 + I ghs FP-61 thickening time 6;00 hfs Tail - Class G -I- 0.25% CD~32 + 0,25% A-7 + 1 ghs FP-6L thickening dine 3:30 hfs 7-5/8" Production Liner Cement with one type of cement for the entire section. Bring the cement to 100' above the top of the liner. Preflush - 30 bbls of MCS-4 spacer Tail - Class G + 0.6% FL.33 +0,2% CD-32 + 0.1% A-2 + 1 glas FP~6L thickening time 3:30 h~s 02/06/98 FRI 16:41 FAX 907 258 8601 FORCENERGY ALASKA ~009 Alaska Division WELLHEAD Vetco Gray OWCY 1~,5/8" ,3M x 11" SM DIRECTIONAL Forcenergy Inc Cook Inlet, AK Coffee Creek #1 Proposed Wellbore Schematic Conductor Pipe, 20" Surface Pipe, 13-3/8". ::~.., 7~ L-,o .TC ~ ~000' .~:i: Top of liner at 6,200' Intermediate Casing 9-5/8' 47#,L-80, BTC @ 6,500' '[ _. Production Casing 7-5/8" 39# P-110 FL4S, @ 9,~00' RKB - GL = 20' ~ment to sude~e (500' of tail) DV Collar at 2000' .=,. 02/06/98 FRI 16:39 FAX 9O7 255 8601 FORCENERGY ALASKA Forcenergy Inc 310 K Street, Suite 700 Anchorage, Alaska 99501 (907) 258-8600 258-8601: FAX FAX TRANSMITTAL SHEET ~ UU~ DATE: PAGES TO FOLLOW FAX' ,~ ?d' .',,_7( ~Z Phone: CONFIDENTIALITY NOTE: The Information In thls facsimile transmittal is legally prlvileaed and confidentipl (nf0rml~1iqnJ Intended 0nly for the use of the individual or entity named above, if the reader of this moss-age is not the intended reoiplent, you are hereby notified that any dlssemlnaxlon, distribution or copy of the transmltlal Is ~tri~tly prohlbited. If you re~eive this transmittal in error, please immediately notify us by telephone, and return the orlglnal transmittal to us at the above address via the United States Postal Service. Thank you. F^XALA.DOC 2/I 1/97 MESSAGE: OFFICE OF THE GOVERNOR OFFICE OF MANAGEMENT AND BUDGET DIVISION OF GOVERNMENTAL COORDINATION SOUTHCENTRAL REGIONAL OFFICE 3601 "C" STREET, SUITE 370 ANCHORAGE, ALASKA 99503-5930 PH: (907) 269-7470~FAX: (907) 561-6134 CENTRAL OFFICE P.O. BOX 110030 JUNEAU, ALASKA 99811-0030 PH: (907) 465-3562/F~: (907) 465-3075 January 5, 1998 · J~' TONY KNOWLES, GOV~ ..~ [~ 411 WEST4THAVENUE, SUI~2C ANCHORAGE, A~S~ 99501~23~ PH: (907) 271~ 17~: John D. Amundsen Forcenergy Inc. 310 K Street, Suite 700 Anchorage, Alaska 99501 Dear Mr. Amundsen: JAIq 08 1998 SUBJECT: Forcenergy Inc. Coffee Creek Project FINAL CONSISTENCY DETERMINATION STATE I.D. NO. AK 9710-17PA k.,cho~sge The Division of Governmental Coordination (DGC) has completed coordinating the review of the proposed Coffee Creek oil and gas exploration well for consistency with the Alaska Coastal Management Program (ACMP) and has developed this final consistency determination based on reviewers' comments. Forcenergy Inc. proposes to drill an onshore oil and gas exploration well in the Upper Cook Inlet area. Project Description Forcenergy Inc. proposes to drill one well approximately 35 miles west of Anchorage and 13 miles north of Tyonek in the Matanuska-Susitna Borough (Section 19, T14N and R1 OW). Six miles of road and a 200-foot by 300-foot gravel pad would be constructed to support drilling and testing operations. Cook Inlet Region, Inc. owns the surface and subsurface acreage at the wellsite. Neither the road or the pad are located in wetlands. A more complete description of this project may be found in the plan of operations (dated October 10, 1997) that was distributed with the ACMP review start-up letter dated October 28, 1997. Forcenergy Inc. has modified the original plan of operations that required a solid waste disposal permit from the Department of Environmental Conservation (DEC). The current plan involves the construction of a concrete building pad using continuous solidification of drill cuttings and muds derived from the Coffee Creek exploration well. The building pad will be used for development purposes that may include the placement of structures or production equipment. 01-A35LH --- Coffee Creek, Forcenergy Inc. STATE I.D. NO. AK 9710-17PA January 5, 1998 The DEC will allow the waste to be managed as exempt under 18AAC60.005(b). The DEC has received a letter of non-objection to the activity and use of drill cuttings from the land owner Cook Inlet Region Incorporated (CIRI), dated December 19, 1997. Scope of this Review This review addresses activities related to the drilling of an oil and gas exploration well. Because the road and the surface and subsurface areas are not owned by the state, no Plan of Operations is required by the Department of Natural Resources, Division of Oil and Gas. In addition, because the site is not located in wetlands, no permit is required from the Army Corps of Engineers. The permits needed for this project are listed below: Alaska Department of Environmental Conservation (DEC) Oil Spill Prevention and Contingency Plan Alaska Department of Natural Resources (DNR) Temporary Water Use Permits Alaska Department ofFish and Game (DFG) Tile 16 Fish Habitat Permits Alaska Oil and Gas Conservation Commission (AOGCC) Permit to Drill Consistency Determination Based on the review of your project by the Alaska Departments of Environmental Conservation, Fish and Game, and Natural Resources and the Matanuska-Susitna Borough coastal district, the state concurs with your certification that the project is consistent with the ACMP provided the conditions outlined in the following stipulation are met. The following stipulation was adopted pursuant to AS 46.40 and 6 AAC 50 (Project Consistency with the ACMP) and is necessary to ensure that your project is consistent with the ACMP. 1) Within the 75 foot shoreline setback, the applicant must minimize the disturbance of natural vegetation. Coffee Creek, Forcenergy Inc. STATE I.D. NO. AK 9710-17PA January 5, 1998 Rationale: The intent of this stipulation is to provide natural filtering of surface water runoff flowing into a water body, minimize erosion and potential flood damage, and provide separation between the water body and potential sources of pollution such as fertilizer, fuel spills, and other items which would have a significant adverse impact to water quality and fish and wildlife habitat. This stipulation is necessary to ensure consistency with Matanuska - Susitna Borough Coastal Management Program (MSBCMP) Enforceable Policy Coastal Habitats Policy 2. Advisories l) Please be advised that if any portion of this project is located in a federally designated Flood Hazard Area, in accordance with MSB 17.29.100 Development permit required, a permit is required before any development begins in Zone A (federal Flood Hazard Area). MSB 17.29.040 defines development as "any man-made change to improved or unimproved real estate, including but not limited to buildings or other structures, mining, dredging, filling, grading, paving, excavation or drilling operations located within the area of special flood hazard." 2) The project or action must comply with all roles applicable to special land use districts or geographic areas affected, including but not limited to MSB Title 15, 16, and 17. 3) Please be advised that although the state has found the project consistent with the ACMP, based on your project description and any stipulations contained herein, you are still required to meet all applicable state and federal laws and regulations. Your consistency determination may include reference to specific laws and regulations, but this in no way precludes your responsibility to comply with other applicable laws and regulations. 4) If changes to the approved project are proposed prior to or during its siting, construction, or operation, you are required to contact this office immediately to determine if further review and approval of the revised project is necessary. If the actual use differs from the approved use contained in the project description, the state may amend the state approvals listed in this final consistency determination. 5) Should cultural or paleontological resources be discovered as a result of this activity, we request that work which would disturb such resources be stopped, and that the State Historic Preservation Office (269-8720) and the U.S. Army Corps of Engineers (COE) (753-2712) be contacted immediately so that consultation per section 106 of the National Coffee Creek, Forcenergy Inc. STATE I.D. NO. AK 9710-17PA January 5, 1998 6) Historic Preservation Act may proceed. This final consistency determination does not obligate DNR to issue authorization under AS 38.05 nor does it supersede the statutory obligations thereunder. You may not proceed with any specific land use activity on state lands until authorized by DNR. Should you have any questions, please contact me at (907) 271-4317 by telephone, (907)272- 0690 by fax, or by electronic mail at GPavia~Pipeline.state.ak.us. Sincerely, ~ ~e) Pavia Project Review Coordinator enclosure: Matanuska Susitna Borough Coastal Habitats Policy 2. cc: Ken Hudson, Mat-Su Borough, Wasilla Glenda Landua, Kenai Peninsula Borough, Kenai Thede Tobish, Municipality of Anchorage, Anchorage Ted Moore, DEC, SPAR, ,a. mchorage Dennis Gnath, DFG, Anchorage Don McKay, DFG, Anchorage Mark Fink, DFG, Anchorage Matt Rader, DNR, DOG, Anchorage Kris O'Conner, DNR, DOG, Anchorage Judy Bitmer, SHPO, Anchorage Buz Kuby, DNR, Division of Mining and Water, Anchorage Suzanne Fisler, DNR, Kenai Center Robert Dolan, DEC, Anchorage Paul McLamon, DEC, Solid Waste, Anchorage Jim Baumgartner, DEC/Air, Juneau Bob Crandall, AOGCC, Anchorage USFWS, Anchorage Coffee Creek, Forcenergy Inc. STATE I.D. NO. AK 9710-17PA January 5, 1998 Ted Rockwell, EPA, Anchorage Jeanne Hanson, NMFS, Anchorage Rory Dabney, Cook Inlet RCAC, Kenai A1 Hastings, Cook Inlet Region, Inc., Anchorage- Peter Merryman, Tyonek j~N 0 8 1998 ,~as~ 0~ & Gas Cc~s. Commis~ Coffee Creek, Forcenergy Inc. STATE I.D. NO. AK 9710-17PA January 5, 1998 Matanuska Susitna Borough Coastal Management Program Enforceable and Administrative Policies Coastal Habitats, Policy 2. Proposed uses and activities within 75 feet of the ordinary high water (OHW) line of rivers, streams, and lakes that require local, state, or federal authorization must be reviewed to protect water quality and fish and wildlife habitat. Water-dependent structures such as docks, piers, marinas, float plane hangers, or boathouses, and access to such structures are allowable within 75 feet of OHW provided they are constructed and used in a way that minimizes adverse impacts to water quality and fish and wildlife habitat. Other uses and activities within 75 feet of OHW are also allowable if the proposed development will have no significant adverse impact to water quality and fish and wildlife habitat, and complies with other applicable federal, state, and local requirements. OFFICE OF THE GOVERNOR OFFICE OF MANAGEMENT AND BUDGET DIVISION OF GO VERNMENTAL COORDINATION SOUTHCENTRAL REGIONAL OFFICE 3601 'C" STREET, SUITE 370 ANCHORAGE, ALASKA 99503-5930 PH: (907) 269-7470~FAX: (907) 561-6134 CENTRAL OFFICE P.O. BOX 110030 JUNEAU, ALASKA 99811-0030 PH: (907) 465-3562~FAX: (907) 465-3075 TONY KNO WLE$, GO VERNOR PH: (907) 271.4317~FAX: (907) 272-0690 December 30, 1997 John D. Amundsen Forcenergy Inc. 310 K Street, Suite 700 Anchorage, Alaska 99501 Dear Mr. Amundsen: SUBJECT: Forcenergy Coffee Creek Project PROPOSED CONSISTENCY DETERMINATION STATE I.D. NO. AK 9710-17PA - The Division of Governmental Coordination (DGC) is currently coordinating the review of the proposed Coffee Creek oil and gas exploration well for consistency with the Alaska Coastal Management Program (ACMP) and has developed this proposed consistency determination based on reviewers' comments. Forcenergy Inc. proposes to drill an onshore oil and gas exploration well in the Upper Cook Inlet area. Project Description This review covers the drilling of an oil and gas exploration well in the Upper Cook Inlet area. Forcenergy Inc. proposes to drill one well approximately 35 miles west of Anchorage and 13 miles north of Tyonek in the Matanuska-Susitna Borough (Section 19, T14N and R10W). Six miles of road and a 200-foot by 300-foot gravel pad would be constructed to support drilling and testing operations. Cook Inlet Region, Inc. owns the surface and subsurface acreage at the wellsite. Both the road and the pad are not located in wetlands. A more complete description of this project may be found in the plan of operations (dated October 10, 1997) that was distributed with the DGC Review start-up letter dated October 28, 1997. Forcenergy Inc. has modified the original plan of operations that required a solid waste disposal permit from DEC. The current plan involves the construction of a concrete building pad using continuous solidification of drill cuttings and muds derived from th~ C~[~ ~l[ep~olem exploration well. The resulting building pad will be used beneficiagyg~ol~eqelb~ent purposes 01-A 35U-I Coffee Creek, Forcenergy Inc. STATE I.D. NO. AK 9710-17PA December 30, 1997 which may include the placement of structures or production equipment. The DEC approves the plan and will allow the waste to be managed as exempt under 18AAC60.005(b). The DEC has received a letter of non-objection to the activity and use of drill cuttings from the land owner Cook Inlet Region Incorporated (CIRI), dated December 19, 1997. Scope of this Review This review addresses activities related to the drilling of oil and gas exploration wells. Because the road and the surface and subsurface areas are not owned by the state, no Plan of Operations is required by the Department of Natural Resources, Division of Oil and Gas. In addition, because the site is not located in wetlands, no permit is required from the Army Corps of Engineers. The permits needed for this project are listed below: Alaska Department of Environmental Conservation Oil Spill Prevention and Contingency Plan Alaska Department of Natural Resources Temporary' Water Use Permits Alaska Deparm~ent of Fish and Game Tile 16 Fish Habitat Permits Alaska Oil and Gas Conservation Commission Permit to Drill Consistency Determination Based on the review of your project by the Alaska Departments of Environmental Conservation, Fish and Game, and Natural Resources and the Matanuska-Susitna Borough coastal district, the state concurs with your certification that the project is consistent with the ACMP provided the conditions outlined in the following stipulation is met. ]-he following stipulation was adopted pursuant to AS 46.40 and 6 AAC 50 (Project Consistency with the ACMP) and is necessary to ensure that your project is consistent with the ACMP. 1) Within the 75 foot shoreline setback, the applicant must minimize the disturbance of natural vegetation. Coffee Creek, Forcenergy Inc. STATE I.D. NO. AK 9710~17PA December 30, 1997 Rationale: The intent of this stipulation is to provide natural fiitering of surface water runoff flowing into a water body, minimize erosion and potential flood damage, and provide separation between the water body and potential sources of pollution such as fertilizer, fuel spills, and other items which would have a significant adverse impact to water quality and fish and wildlife habitat. This stipulation is necessary to ensure consistency with ?vfatanuska - Susitna Borough Coastal Management Program (MSBCM;P) Enforceable and Administrative Policies Coastal Habitats Policy 2. Advisories 1) Please be advised that if any portion of this project is located in a federally designated Flood Hazard Area, in accordance with MSB 17.29.100 Development permit required, a permit is required before any development begins in Zone A (federal Flood Hazard Area). MSB 17.29.040 defines development as "any man-made change to improved or unimproved real estate, including but not limited to buildings or other structures, mining, dredging, filling, grading, paving, excavation or drilling operations located within the area of special flood hazard." .- 2~ The project or action must comply with all rules applicable to special land use districts or geographic areas affected, including but not limited to MSB Title 15, 16, and 17. 3) Please be advised that although the state has found the project consistent with the ACMP, based on your project description and any stipulations contained herein, you are still required to meet all applicable state and federal laws and regulations. Your consistency determination may include reference to specific laws and regulations, but this in no way precludes your responsibility to comply with other applicable laws and regulations. 4) If changes to the approved project are proposed prior to or during its siting, construction, or operation, you are required to contact this office immediately to determine if further review and approval of the revised project is necessary. If the actual use differs from the approved use contained in the project description, the state may amend the state approvals listed in this proposed consistency determination. 5) Should cultural or paleontological resources be discovered as a result of this activity, we request that work which would disturb such resources be stopped, and that the State Historic Preservation Office (269-8720) and the U.S. Army Corps of Engineers (COE) (753-2712) be contacted immediately so that consultation per section 106 of the National Coffee Creek, Forcenergy Inc. STATE I.D. NO. AK 9710-17PA December 30, 1997 6) Historic Preservation Act may proceed. This proposed consistency determination does not obligate DNR to issue authorization under AS 38.05 nor does it supersede the statutory obligations thereunder. You may not proceed ~vith any specific land use activity on state lands until authorized by DNR. Elevation You must respond within five calendar days of your receipt of this proposed determination to indicate whether or not you concur with this determination. If you, the applicant, are not prepared to concur within the five-day period, you may either: (a) request an extension of the review schedule pursuant to 6 AAC 50.110(b)(8) if you need more time to consider this determination, or (b) r_equest that the state reconsider this determination, by submitting a written statement requesting "elevation" of the determination, describing your concerns, and proposing an alternative consistency determination. This alternative determination must demonstrate ho~v your project is consistent with the referenced standards of the ACMP and district policies. Other review participants wSth elevation rights pursuant to 6 AAC 50.070(j) may also request an elevation if they submit the information required in (b) above to DGC within five calendar days of receipt of the proposed determination. Petition Citizens of the Matanuska-Susitna Borough coastal district, who submitted written consistency comments on this project on or before the comment deadline established in accordance with 6 AAC 50.070(e), may file a petition under AS 46.40.100(b)(1) seeking a review by the Coastal Policy Council oft his proposed consistency determination. Any petition must be filed with this office within five calendar days after issuance of the proposed consistency determination. The petition must: (a) show how the district coastal management plan is not being implemented, enforced, or complied with; Coffee Creek, Forcenergy inc. STATE I.D. NO. AK 9710-17PA December 30, 1997 (b) (c) (d) include the petitioner's previous ~,witten comment on the consistency of the project; describe how the petitioner believes his or her previous consistency comment was not fairly considered by the coordinating agency during the consistency review; and provide the petitioner's mailing and street address, telephone number and, if available, fax number. If DGC does not receive a request for extension or an elevation statement from you, the applicant, or any other review participant with elevation rights, or a petition from a citizen of an affected coastal district meeting the requirements outlined above within the deadlines specified above, this proposed consistency determination will be issued as a final consistency determination. Should you have any questions, please contact me at (907) 271-4317 by telephone, (907)272- 0690 by fax, or by electronic mail Gpavia~Pipeline.state.ak.us. Project Review Coordinator cc: Ken Hudson, Mat-Su Borough, Wasilla Glenda Landua, Kenai Peninsula Borough, Kenai Thede Tobish, Municipality of Anchorage, Anchorage Ted Moore, DEC, SPAR, Anchorage Dennis Gnath, DFG, Anchorage Don McKay, DFG, Anchorage Mark Fink, DFG, Anchorage Matt Rader, DNR, DOG, Anchorage Kris O'Conner, DNR, DOG, Anchorage Judy Bittner, SHPO, Anchorage Buz Kuby, DNR, Division of Mining and Water, Anchorage Suzarme Fisler, DNR, Kenai Center Robert Dolan, DEC, Anchorage Coffee Creek, Forcenergy Inc. STATE I.D. NO. AK 9710-17PA December 30, 1997 Paul McLarnon, DEC, Solid Waste, Anchorage Jim Baumgarmer, DEC/Air, Juneau u"B-ob Crandall, AOGCC, Anchorage USFWS, Anchorage Ted Rockwell, EPA, Anchorage Jeanne Hanson, NMFS, Anchorage Rory Dabney, Cook Inlet RCAC, Kenai A1 Hastings, Cook Inlet Region, Inc., Anchorage Peter Merryman, Tyonek Matanuska Susitna Borough Coastal Management Program Enforceable and Administrative Policies Coastal Habitats, Policy 2. Proposed uses and activities within 75 feet of the ordinary high water (OHW) line of rivers, streams, and lakes that require local, state, or federal authorization must be reviewed to protect water quality and fish and wildlife habitat. Water-dependent structures such as docks, piers, marinas, float plane hangers, or boathouses, and access to such structures are allowable within 75 feet of OHW provided they are constructed and used in a way that minimizes adverse impacts to water quality and fish and wildlife habitat. Other uses and activities within 75 feet of OHW are also allowable if the proposed development will have no significant adverse impact to water quality and fish and wildlife habitat, and complies with other applicable federal, state, and local requirements. TONY KNOWLE$, GOVERNOR OFFICE OF THE GOVERNOR OFFICE OF MANAGEMENT AND BUDGET DIVISION OF GOVERNMENTAL COORDINATION /SOUTHCENTRAL REGIONAL OFFICE l~ CENTRAL OFFICE 3601 'C' STREET, SUITE 370 P.O. BOX 110030 ANCHORAGE, ALASKA 99503-5930 JUNEAU, ALASKA 99811-0030 PH: (907) 269-7470/FAX: (907) 561-6134 PH: (907) 465-3562./FAX: (907) 465-3075 December 10, 1997 John D. Amundsen Forcenergy Inc. 310 K Street, Suite 700 Anchorage, Alaska 99501 RECEIVED Dear Mr. Amundsen: Alaska Oil & (las Cons. ¢ammissio~ Anchorage SUBJECT: Forcenergy Coffee Creek Project Re-Start of Review STATE I.D. NO. AK 9710-17PA PIPELINE COORDINATOR'S OFFICE 411 WEST 4TH AVENUE, SUITE 2C ANCHORAGE, ALASKA 99501-2343 SR GEOL I At the request of the Department of Environmental Conservation (DEC) and the Department of Fish and Game (DFG) the Division of Governmental Coordination (DGC) is re-starting the review for the Coffee Creek Project today. The DGC extended the consistency review deadlines on November 21, 1997 at the request of the DEC and DFG for a request for additional information to properly address the State's interests in response resources, deployment strategies, and blowout plume trajectory, modeling for the protection of the immediate environment for shore based activities. The revisions to the Oil Discharge and Contingency Plan were submitted by your office to DEC, DFG and other review participants on December 5, 1997. Ted Moore at DEC and Mark Fink at DFG have informed me that this submission satisfies the request for additional information. I have enclosed a copy of your cover letter to the revisions, record of revisions, and revised table of contents. By copy of this letter, I am notifying all reviewers who have not received the revisions, that they can be obtained by contacting you at 258-8600. The remaining review deadlines are as follows. Request for more Information ............................................................................ December 10, 1997 Comment Deadline .......................................................................................... December 19, 1997 Proposed Determination ..................................................................................... December 29, 1998 Final Determination ................................................................................................. January. 4, 1998 01-A35LH Coffee Creek. Forcenergy STATE I.D. NO. AK 9710-17PA 9 December ~ 1997 Should you have any questions, please contact Glenn Gray at (907) 465-8792 by telephone or by electronic mail Glenn Gray ~(-~gov.state.ak.us, or contact me at 271-4317 by telephone or by electronic mail at Gpavia~Pipeline.state.ak.us. Sincerely, Eugene Pavia Project Review Coordinator CC: Ken Hudson, Mat-Su Borough, Wasilla Glenda Landua, Kenai Peninsula Borough, Kenai Thede Tobish, Municipality of Anchorage, Anchorage Ted Moore~ DEC, SPAR, Anchorage Dennis Gnath, Don McKay, DFG, Anchorage Mark Fink, DFG, Anchorage Matt Rader, DNR, DOG, Anchorage Kris O'Conner, DNR, DOG, Anchorage Judy Bittner, SHPO, Anchorage Kellie Litzen, DNR, Division of Mining and Water. Anchorage Suzanne Fisler, DNR. Kenai Center Robert Dolan. DEC, Anchorage Paul McLamon, DEC, Solid Waste, Anchorage Jim Baumgartner, DEC/Air. Juneau Bob Crandall, AOGCC, Anchorage USFWS, Anchorage Ted Rockwell, EPA, Anchorage Tim Jennings, COE, Anchorage Jeanne Hanson, NMFS, Anchorage Rory Dabney, Cook Inlet RCAC, Kenai A1 Hastings, Cook Inlet Region, Inc., Anchorage Force::ergy Inc December 5, 1997 Mr. Ted Moore Alaska Department of Environmental Conservation 555 Cordova Street Anchorage, Alaska 99501 Re: Oil Discharge Prevention and Contingency Plan Cook Inlet Exploration Program, Southcentral Alaska Dear Ted, Enclosed are the revised pages for the referenced Oil Discharge Prevention and Contingency Plan for your review. We believe that we have addressed' ali of the points covered in your letter dated November 24, 1997. The general context of our responses is believed to be consistent with our discussions on December 4, 1997. In addition to those items we have also replaced Appendix 3.7.A to include current in situ burn permit forms. Should you have any questions, please don't hesitate to contact either me or Bob Britch at your earliest convenience. John AmundCen Safety, Health, and Environment Manager cc: Glenn Gray- DGC Mark Fink- ADF&G Kris O'Conner- DNR Mike Munger- ADEC Glenda Landua - KPB Anne McCord - CIRCAC HEADQUARTERS Forcenergy Center 2730 SW 3ra Avenue Suile 800 TELEPHONE 305/856-8500 FAX REGIONAL OFFICE 3 I0 K Street Suite 700 TELEPHONE 907/258-8600 FAX q~7/?RR-RR~I FORCENERGY INC OIL DISCHARGE PREVENTION AND CONTINGENCY PLAN COOK INLET AREA EXPLORATION PROGRAM RECORD OF REVISIONS Page/Section RevisionI instruction~ I Initial When Number Date . , Completed Page 6 ! 12/4/97 i Replace Page Table of Contents I 1214197 I Replace Entire Section Pages 1-i thru 1-ivt 12/4/97I Delete Pages - Redundant Page 1.1-6 'I 12/4/97 i Replace Page Appendix 1.1.A I 12/4/97 -i Delete Appendix - Moved to Sec. 1.8 Section 1.2 't 12/4/97 I Replace Entire Section Page 1.3.A-1 l 12/4/97 ! Replace Page Page 1.4-1 i 12/4/97 I Replace Page Section 1.5 12/4/97,i Replace Entire Section Pages 1.6-1 thru 1214197 I Replace Pages 1.6-6 I Appendix 1.6.A I 12/4/97 Delete Appendix - Moved to Sec. 1.8 Page 1.8-1 12/4/97 Replace Page Appendix 1.8.A 12/4/97 Add New Appendix Pages 2-i thru 2-ii 12/4/97 Delete Pages - Redundant Page 2.3-2 I 12/4/97 I Replace Page Pages 3-i thru 3-iv t 12/4/97I Delete Pages - Redundant I Section 3.1 i 12/4/97 I Replace Entire Section Appendix 3.1.A ! 12/4/97 ! Delete Appendix- Moved to Sec. 1.8 Section 3.2 I 12/4/97 I Replace Entire Section Appendix 3.2.A i 12/4/97I Delete Appendix - Moved to Sec. 1.8 Section 3.4 i 12/4/97 ! Replace Entire Section Section 3.6 ! 12/4/97 I Replace Entire Section Appendix 3.7.A 12/4/97 i Replace Entire Appendix , Page 3.8-1 12/4/97 I Replace Page Section 3.9 12/4/97 I Replace Entire Section " Page 3.10-1 12/4/97I Repi.ace Page Appendix 3.10.A i 12/4/97 [ Delete Appendix - Moved to Sec. 1.8 Pages 4-i thru 4-ii 12/4/97 I Dele'te Pages - Redundant . 6 Revised 12/4/97 TABLE OF CONTENTS PART 1 - RESPONSE ACTION PLAN SECTION 1.1 - EMERGENCY ACTION PLAN CHECKLIST ............................................... 1.1-1 i.1.1 General .............................................................................................................. 1.1-1 1.1.2 First Person to See the Spill .............................................................................. 1.1-1 1.1.3 On-Site Drilling Foreman ................................................................................... 1.1-1 1.1.4 Incident Commander ......................................................................................... 1.1-2 1.1.5 ICS Response Levels and Contacts .................................................................. 1.1-2 1.1.5.1 Level lResponse ............................................................................. 1.1-2 1.1.5.2 LevelllResponse ............................................................................ 1.1-8 1.1.6 Emergency Contact Numbers ............................................................................ 1.1-8 SECTION 1.2 - REPORTING AND NOTIFICATION ............................................................. 1.2-1 1.2.1 Reporting and Notification Within the Alaska Region ........................................ 1.2-1 !.2.2 Forcenergy Command Center ........................................................................... 1.2-1 1.2.3 Response Contractor ......................................................................................... 1.2-1 1.2.4 Emergency Contacts ......................................................................................... 1.2-1 SECTION 1.3 - SAFETY ...................................................................................................... 1.3-1 1.3.1 General Safety Procedures ............................................................................... 1.3-1 1.3.2 General Safety Precautions During Spill Response .......................................... 1.3-1 1.3.3 Personal Protective Equipment ......................................................................... 1.3-2 Appendix 1.3.A Site Control and Emergency Response Form Appendix 1.3.B Matenal Safety Data Sheets SECTION 1.4 - COMMUNICATIONS ................................................................................... 1.4-1 1.4.1 General .............................................................................................................. 1.4-1 _ 1.4.2 CISPRI's Communication System ...................................................................... 1.4-1 SECTION 1.5 - DEPLOYMENT STRATEGIES .................................................................... 1.5-1 1.5.1 General .............................................................................................................. 1.5-1 1.5.2 Immediate Response Strategies--Forcenergy Personnel .................................. 1.5-1 1.5.2.1 General Strategy .............................................................................. 1.5-1 1.5.2.2 Utilization of On-Site Resources ...................................................... 1.5-1 1.5.2.3 Response to Operational Spills ........................................................ 1.5-2 Revised 12/4/97 CONTENTS (Cont'd) 1.5.3 Utilization of Spill Contractor .............................................................................. 1.5-2 1.5.3.1 General Strategy .............................................................................. 1.5-2 1.5.3.2 On Land Spill Response .................................................................. 1.5-3 1.5.3.3 Offshore Spill Response .................................................................. 1.5-9 1.5.4 Other Response Equipment Mobilization ......................................................... 1.5-10 1.5.4.1 Transporting Equipment and Personnel in Adverse Weather ........ 1.5-10 1.5.4.2 Skimming Devices Necessary to Meet the 50,000-Barrel Planning Standard .............................................................................. 1.5-10 SECTION 1.6 - RESPONSE STRATEGIES ........................................................................ 1 1.6.1 Procedures to Stop the Discharge ..................................................................... 1 1.6.1.1 Scenario No. 1-Well Blowout ........................................................... 1 1.6.1.2 Scenario No. 2-Drilling Site Diesel Tank Failure .............................. 1 1.6.1.3 Scenario No. 3-Minor Fuel Spill ....................................................... 1 1.6.2 Fire Prevention and Control ............................................................................... 1 1.6.3 Blowout Control (Applicable Only to Scenario #1) ............................................. 1 1.6.3.1 Pdmary Control ................................................................................ I 1.6.3.2 1.6.3.3 1.6.3.4 1.6.3.5 1.6.4 Discharge Secondary Control ........................................................................... 1 Blowout Well Control ....................................................................... 1 Blowout Ignition ............................................................................... 1 Relief Well ....................................................................................... 1 Tracking ............................................................................................ 1 .6-1 .6-2 .6-2 .6-2 .6-2 .6-2 .6-3 .6-3 .6-4 .6-4 .6-4 .6-5 .6-5 1.6.5 Protection of Environmentally Sensitive Areas .................................................. 1.6-8 1.6.6 Containment and Control Strategies .................................................................. 1.6-9 1.6.6.1 Scenario No. 1 - Well Blowout ......................................................... 1.6-9 1.6.6.2 Scenarios No. 2 and 3 - Fuel Spills .................................................. 1.6-9 1.6.7 Recovery Strategies ........................................................................................ 1.6-10 1.6.7.1 General .......................................................................................... 1.6-10 1.6.7.2 Free Hydrocarbon Recovery from the Ground ............................... 1.6-10 1.6.7.3 Hydrocarbon Contaminated Soil .................................................... 1.6-11 1.6.7.4 Hydrocarbon Contaminated Snow ................................................. 1.6-11 1.6.7.5 Hydrocarbon Contaminated Vegetation and Debris ....................... !.6-11 1.6.8 Damaged Tank Transfer and Storage ............................................................. 1.6-11 ii Revised 12/4/97 CONTENTS (Cont'd) 1.6.9 Recovered Oil Transfer and Storage ............................................................... 1.6-1 1 1.6.9.1 Scenario 1-Well Blowout ................................................................ 1.6-12 1.6.9.2 Scenano 2 and 3-Fuel Spills .......................................................... 1.6-13 1.6.10 Temporary Storage and Ultimate Disposal .................................................... 1.6-13 1.6.1 1 Wildlife Protection .......................................................................................... 1.6-13 1.6.12 Shoreline Cleanup Plans ............................................................................... 1.6-14 SECTION 1.7 - NON-MECHANICAL RESPONSE INFORMATION ...................................... 1.7-1 1.7.1 Blowout Ignition ................................................................................................. 1.7-1 1.7.2 In Situ Burning ................................................................................................... 1.7-2 1.7.3 Dispersants ........................................................................................................ 1.7-2 1.7.4 Incineration ........................................................................................................ 1.7-2 SECTION 1.8 - FACILITY DESCRIPTIONS/DIAGRAMS ..................................................... 1.8-1 Attachment 1.8.A Coffee Creek Prospect PART 2 - PREVENTION PLAN SECTION 2.1 - PREVENTION PLANS IN PLACE ............................................................... 2.1-1 2.1.1 General .............................................................................................................. 2.1-1 2.1.2 Prevention Training Programs ........................................................................... 2.1-1 2.1.2 Substance Abuse Programs .............................................................................. 2.1-2 2.1.2.1 General Policies ................................................................................ 2.1-1 -- 2.1.2.2 Definitions and Guidelines ................................................................. 2.1-2 2.1.4 Medical Programs .............................................................................................. 2.1-3 2.1.5 Secudty Program ............................................................................................... 2.1-4 2.1.6 Transfer Procedures .......................................................................................... 2.1-5 2.1.7 Fuel Storage Tanks ........................................................................................... 2.1-5 2.1.8 Description of Secondary Containment Areas ................................................... 2.1-5 2.1.9 Facility Piping Corrosion Control and Leak Detection Programs ....................... 2.1-5 2.1.10 Emergency Tow and Escort Vessels Program ................................................ 2.1-5 2.1.1 1 Vessel Inspections and Maintenance Programs .............................................. 2.1-5 2.1.12 Crude Oil Transmission Pipelines .................................................................... 2.1-5 Appendix 2.1.A Drug and Alcohol Policies ,.o ~ll Revised 12/4/97 CONTENTS (Cont'd) SECTION 2.2 - DISCHARGE HISTORY .............................................................................. 2.2-1 SECTION 2.3 - SPILL POTENTIAL ..................................................................................... 2.3-1 SECTION 2.4 - OPERATIONAL AND SITE-SPECIFIC CONDITIONS ................................. 2.4-1 2.4.1 General .............................................................................................................. 2.4-1 2.4.2 2.4.3 2.4.4 2.4.5 2.4.7 2.4.8 Climate ..................... - ........... ' ........... : .................................................................. 2.4-1 Frequency and Severity of Storms .................................................................... 2.4-1 Winds ................................................................................................................ 2.4-2 Sea States, Tides, and Currents ....................................................................... 2.4-2 Hours of Daylight ............................................................................................... 2.4-4 Earthquakes ...................................................................................................... 2.4-4 SECTION 2.5 - EXISTING AND PROPOSED DISCHARGE DETECTION .......................... 2.5-1 SECTION 2.6 - RESPONSE PLANNING STANDARDS EXEMPTIONS .............................. 2.6-1 SECTION 2.7 - COMPLIANCE SCHEDULE AND WAIVERS .............................................. 2.7-1 PART 3 - SUPPLEMENTAL INFORMATION SECTION 3.1 - FACILITY DESCRIPTION AND OPERATIONAL OVERVIEW .................... 3.1-1 3.1.1 General .............................................................................................................. 3.1-1 3.1.2 3.1.3 3.1.4 3.1.5 3.1.6 3.1.7 3.1.8 3.1.9 Oil Storage Container Information ..................................................................... 3.1ol Type and Amount of Oil ..................................................................................... 3.1-1 Vessel Routes ................................................................................................... 3.1-1 Vessel Plans and Diagrams ............................................................................... 3.1-1 Transfer Procedures .......................................................................................... 3.1-2 Facility Descriptions ........................................................................................... 3.1-2 Disposal of Oil Waste for Vessels ..................................................................... 3.1-2 Additional Information ........................................................................................ 3.1-2 SECTION 3.2 - RECEIVING ENVIRONMENT ...................................................................... 3.2-1 iv Revised 12/4/97 CONTENTS (Cont'd) SECTION 3.3 - COMMAND SYSTEM .................................................................................. 3.3-1 3.3.1 Overview ............................................................................................................ 3.3-1 3.3.2 Incident Commander ......................................................................................... 3.3-1 3.3.3 Unified Command .............................................................................................. 3.3-1 3.3.4 Command Staff ................................................................................................. 3.3-3 3.3.5 Operations Section Chief ................................................................................... 3.3-3 3.3.6 Planning Section Chief ...................................................................................... 3.3-5 3.3.7 Logistics Section Chief ...................................................................................... 3.3-6 3.3.8 Finance Section Chief ....................................................................................... 3.3-8 Appendix 3.3-A Incident Command System Forms SECTION 3.4 - REALISTIC MAXIMUM RESPONSE OPERATING LIMITATIONS .............. 3.4-1 3.4.1 General .............................................................................................................. 3.4-1 3.4.2 General Adverse Weather Conditions ............................................................... 3.4-1 3.4.2.1 Wind ............................................................................................... 3.4-1 3.4.2.2 Visibility ........................................................................................... 3.4-2 3.4.3 Sea States, Tides, and Currents ....................................................................... 3.4-2 3.4.3.1 Currents Off Shore .......................................................................... 3.4-2 3.4.3.2 Currents On Shore .......................................................................... 3.4-2 3.4.4 Ice and Debris 3.4-3 3.4.4.1 Open Water .................................................................................... 3.4-3 3.4.4.2 On Land .......................................................................................... 3.4-3 3.4.5 Hours of Daylight ............................................................................................... 3.4-4 SECTION 3.5 - LOGISTICAL SUPPORT ............................................................................ 3.5-1 3.5.1 General .............................................................................................................. 3.5-1 3.5.2 Marine Logistics ................................................................................................. 3.5-1 3.5.3 Air Logistics ....................................................................................................... 3.5-1 3.5.4 Inspections ........................................................................................................ 3.5-1 Appendix 3.5.A CISPRI Vendors SECTION 3.6 - RESPONSE EQUIPMENT .......................................................................... 3.6-1 V Revised 12/4/97 CONTENTS (Cont'd) SECTION 3.7 - NON-MECHANICAL RESPONSE INFORMATION ...................................... 3.7-1 Appendix 3.7.A Oil Spill Response Checklist: In Situ Burning Appendix 3.7.B Material Safety Data Sheet for Sure-Fire Ignition Agent SECTION 3.8 - CONTRACTOR INFORMATION ................................................................. 3.8-1 Appendix 3.8.A Statement of Contractual Terms Appendix 3.8.B Forcenergy Inc and CISPRI Contract Appendix 3.8.C Other Contracts and Agreements SECTION 3.9 -TRAINING ................................................................................................... 3.9-1 3.9.1 General .............................................................................................................. 3.9-1 3.9.2 OSHA Requirements ......................................................................................... 3.9-1 3.9.3 ADEC Requirements ......................................................................................... 3.9-1 3.9.4 Forcenergy's Training Programs ........................................................................ 3.9-1 3.9.4.1 General ........................................................................................... 3.9-1 3.9.4.2 Forcenergy's Spill Response Training ............................................ 3.9-4 3.9.5 CISPRI Training Programs ................................................................................ 3.9-4 SECTION 3.10 -PROTECTION OF ENVIRONMENTALLY SENSITIVE AREAS .............. 3.10-1 SECTION 3.11 - ADDITIONAL INFORMATION ................................................................. 3.11-1 SECTION 3.12 - BIBLIOGRAPHY ..................................................................................... 3.12-1 PART 4 - BEST AVAILABLE TECHNOLOGY REVIEW SECTION 4.1 - BEST AVAILABLE TECHNOLOGY REVIEW ............................................. 4.1-1 4.1.1 Applicable Technologies .................................................................................... 4.1-1 4.1.2 4.1.3 4.1.4 4.1.5 4.1.6 4.1.7 Source Control Procedures ............................................................................... 4.1-2 Trajectory Analysis ............................................................................................ 4.1-4 Wildlife Capture, Treatment, and Release Programs ........................................ 4.1-6 Leak Detection Systems .................................................................................... 4.1-7 Liquid Level Monitoring ...................................................................................... 4.1-9 Communications .............................................................................................. 4.1-11 vi Revised 12/4/97 LIST OF TABLES 1.1-1 1.1-2 1.2-1 1.2-2 1.4-1 1.6-1 Initial Spill Response Team/Emergency Contacts .................................................. 1.1-6 Emergency Contacts .............................................................................................. 1.1-8 Agency Notification Chart ....................................................................................... 1.2-2 List of Other Contacts ............................................................................................. 1.2-5 Forcenergy On-Site Communications ..................................................................... 1.4-2 Partitioning of a 15-Day Blowout Without and With Ignition ................................... 1.6-7 2.3-1 2.4-1 2.4-2 Maximum Discharges of Liquid Hydrocarbons for Proposed Oil and Gas Exploration Activities ............................................................................................... 2.3-2 Extreme Wind Estimates for Anchorage International Airport .................................. 2.4-2 Summary of Tidal Data at the Kenai Peninsula (from National Ocean Survey Data) ....................................................................................................................... 2.4-3 3.5-1 3.5-2 3.5-3 3.5-4 3.5-5 3.6-1 3.9-1 3.9-2 3.9-3 CISPRI Response Vessels ...................................................................................... 3.5-2 CISPRI Response Vessels and Equipment ............................................................. 3.5-3 Ports and Anchorages in the Cook Inlet Region ...................................................... 3.5-5 Aircraft Available for Spill Response ........................................................................ 3.5-6 Airports in the Cook Inlet Region ............................................................................. 3.5-7 On-Site Spill Response Equipment .......................................................................... 3.6-2 OSHA Emergency Response Training Requirements ............................................ 3.9-2 OSHA Hazardous Waste Operations Training Requirements ................................ 3.9-3 Summary of Forcenergy and CISPRI Training Programs ....................................... 3.9-5 4.1-1 4.1-2 4.1-3 4.1-5 4.1-6 BAT Review for Source Control Procedures ............................................................ 4.1-3 BAT Review for Trajectory Analysis for On-Land Spills ........................................... 4.1-5 BAT Review for Leak Detection Systems ................................................................. 4.1-8 BAT Review for Liquid Level Determinations ......................................................... 4.1-10 BAT Review for Communications Systems ............................................................ 4.1-12 vii Revised 12/4/97 LIST OF FIGURES 1.1 -1 1.1 -2 1.1 -3 1.5-1 1.5-2 1.5-3 Spill Report Form .............................................................................................. 1.1-3 Forcenergy's Incident Command Organization Level I Response ..................... 1.1-4 Forcenergy's Incident Command Organization Level Ii Response .................... 1.1-5 Ground Response Times from Kenai and Anchorage ....................................... 1.5-5 Aviation Response Times and Airport Locations ................................................ 1.5-6 Madne Response Times from Nikiski Dock, Anchorage, and Homer ................ 1.5-8 3.3-1 Incident Command System (ICS) Organization Chart for a Major Spill ........... 3.10-4 viii Revised 12/4/97 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION December 22. 1997 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Paul White Drilling Manager Forcenergy Inc. 310 K St.. Suite 700 Anchorage, AK 99501 Re; Coffee Creek No. 1 Forcenergy Ilm. Permit No: 97-219 Sur. Loc. 527'FWL, 710'FSL. Sec. 19, T14N, R10W. SM Btmhole Loc. 527'FWL. 710'FSL, Sec. 19, T14N, R10W. SM Dear Mr. White' Enclosed is thc approved application for permit to drill thc above referenced ,,,,'ell. The permit to drill docs not exempt you from obtaining additional permits required by law from other govermnental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. This approval includes annular disposal of drilling wastes and is contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT) - cementing records. FIT data. and any CQLs are to be submitted to thc Colnmission prior to fire start of disposal operations. A weekly status report is required from tim time file well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for thc Commission's internal use. Blowout prevention equipment (BOPE) must be tested in accordance v,'ith 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below thc surface casing shoe must be given so that a representative of thc Commission ma5' witness the test. Notice may be given bv contacting the Commission at 279-1433. , Chairman ' BY ORDER OF THE COMMISSION dlffEnclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA ~.-,,-AND GAS CONSERVATION ..... ..OMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work: Drill [] Redrill [] I lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []I Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 6. Datum elevation (DF or KB) 10. Field and Pool Forcenergy Inc. 620' KB feet 3. Address 310 K Street, Suite 700 6. Property Designation Wildcat Anchorage, Alaska 99501 C-061466 4. Location of well at surface 7. Unit or Property name 11. Type Bond (see 20AAC 25.025) 527' FWL 710' FSL Sec 19 T14N R10W Coffee Creek Statewide P&A Bond At top of productive interval 8. Well number Number 527' FWL 710' FSL Sec 19 T14N R10W #1 434032C At total depth 9. Approximate spud date Amount 527' FWL 710' FSL Sec 19 T14N R10W December 15, 1997 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15 Proposed depth (MD and TVD) property line Tipco Pretty Creek #1 527' FWL 71~3' FSL feet 29,222' feet 2528 acres 7000' MD/TVD feet 16. To be completed for deviated wells 17. Anticipated Pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth n/a feet maximum hole angle n/a o Maximum Surface 2580 psig. At total depth (TVD) 3385 psig. 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD ']'VD MD 'I'VD (include stage data) driven 20" 133# welded 80' 0 0 80' 80' driven 17½" 13-3/8" 72# L-80 BTC 2000' 0 0 2000' 2000' 1470 sacks (to surface) 12¼" 9-5/8" 47# L-80 BTC 4500' 0 0 4500' 4500' 460 sacks (to 3,000') 8½" 7-5/8" 29.7# L-80 FL4S 2800' 4200' 4200' 7000' 7000' 290 sacks (to top of liner) 19. To be completed for Redrill, Re-entry, and Deepen Operations, Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural sCu°nd.da;ectOrR EC E IV E D 'pnrtoe: umc;id:ante ORIGINAL Liner Perforation depth: measured true vertical iJ~$kJ~ 011 & Gas Cons. C0mm~ion A.n. chn_rn~ 20 Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] "Drilling Program [] Drilling Fluid Program [] Time vs. Depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify that the f~,re~oing is true and correct to the best of my knowledge. Signed: Paul D. Whi Title: Drilling Manager Date: 11/17/97 FOR COMMISSION USE ONLY Permit Number JAPI number JApproval date Jsee cover letter ~7- ~--/~;;> 50_ 2..(~-- ~.,<::::~O ~" J ~,,'O~¢:~_ C>),"~ Jfor other requirements Conditions of approval Samples required ~ Yes I--I No Mud log required .~ Yes [] No Hydrogen sulfide measures [] Yes ~ No Directional survey required [] Yes [] No Required working pressure for BOPE [] 2M; [] 3M; j~ 5M; [] 10M; [] 15M Other: .,.,g,r~al ~gnea By (,~.vld W. Johnston by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate Attachments o 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. Application Form Property Plats BOP sketch Choke Manifold Sketch Diverter Sketch BOP equipment list Pressure Information including Shallow gas analysis and sonic log analysis Drilling Program Drilling Fluids Program Drilling Fluid System Sketch Casing Design Cement Calculations Time vs Depth Plot Application for Permit for Annular Disposal of Drilling Waste Log analysis of Superior Chuit State #1 F:~ACC'RGUEST3\Coffee Creek~permit cover, doc Date Modified: 11/15/97 Date Prepared: 11/4/97 kto Forcer, rgy Inc November 19, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' Robert P. Crandall Re: Application for Permit to Drill Coffee Creek #1 Well Dear Mr. Crandall: Attached is a copy of the seismic section previously submitted. This version is in a smaller format. Also attached is map showing the well location and the seismic line in relation to the well. If there are any questions please contact our Drilling Manager, Mr. Paul White or Geophysicist, Mr. Robert Jeffery. Both can be reached at 258-8600. Ii 18,-Ii',, '.y'O~ ?:Oi' yOi.i '- ~'~: .... ' .... po~,ui ,uu ~n; i~,F,, ,u us ui~u~i~i iu [he s[a;e requirements. Sincerely, Kelly Olds Lead Well Engineer Halliburton Energy Services attachments RECEIVED 20 \\FGEANCH\SYS~ACC'r~GUEST3\Coffee Creek~seismic cover.doc Date Modified: 11/19/97 Date Prepared: 11/19/97 kto HEADQUARTERS Forcenergy Center TELEPHONE 2730 SW 3rd Avenue 305/856-8500 Suite 800 FAX .... ~, . , ~.~,-,,~ r-,,"-,t-,--~ ~r~r"l~','", A~f"~/'~ REGIONAL OFFICE 310 K Street Suite 700 A ,-, ,-, k ,-, ,- ,.-, ,.-~ ,-, TELEPHONE 907/258-8600 FAX OR7/9~9_gR~l 2676000 TI ' I ~1 I ~ I ~x ~ ~ ' " , ' · --~ .... ~-~ ...... ~---~___~__A___ ~ h , ~ ~ ~ ---~---~ .... ~-~-~T-~-~-- 2670000 , I I '~ ' ' I 2664000 - --/ ....... ~ ....... ~-~ ..... __ _~ ..... , , ~ " I " ~"' ~.1% ~ .- i ~ i ,, 7e~~ _. ' 2652000 ~ ~ ~ ~ ~ { I , I __4 .... ~_~ ...... L ........ 2646000 , i ~ I I ~ I {~¢5 ~ t l/ :--F ....... ~ ..... n ....... ~ ..... T ....... I I I I I I I o o o o o o o o o o o o o o O' 1700' ! 5400' I" = 7700 feet Force ,ergy Inc November 17, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill Coffee Creek #1 Well Dear Sir or Madam: Attached is a revision to our previously submitted application for a Permit to Drill for the Coffee Creek #1 well. The 13-3/8" and 9-5/8" casing points were revised to protect the fresh water near the surface. The well is to be drilled with the Steding Alaska Drilling Rig #1. The planned spud date for the well is December 15, 1997. If there are any questions, please contact me at 258-8600. 5~cerely, Paul White Drilling Manager F:VkCC~GUEST3\Coffee Creek~permit cover, doc Date M~ifi~: 11/15/97 Date Prepare: 11/4/97 kto HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 TELEPHONE 305/856-8500 FAX REGIONAL OFFICE 310 K Street Suite 700 TELEPHONE 907/258-8600 FAX T '14 N T 13 N i ,~ . i . I i i i i l I. ~ J ~ 4 ........... ' . ~ . ... ~ I I I I I I I , .l I I I I I I I I '1 I i I I i I i i ~ i i I I I I I I i I i i I I I i I I I i i i I I i I I I I i i i I I i R11W RIOW, Seward Meftdlan Alaska Division · COFFEE CREEK AREA JOINT OPERATING AGREEMENT Exhibit "B" Date: September 16. 1997 I::h-aw~ by: Mapmakers Alaska Forcenergy Inc Alaska Division Coffee Creek #1 Well Location Plat sec 12 sec 7 sec 8 ; ; ; ; sec14 sec13 i sec18 i sec17 ! sec16 ~ sec 19 _. sec 23 sec 24 i 710' F.~L sec 20 i sec 21 i ." i : -" .. sec 25 i sec 30 sec 29 T14N R11W T14N R1 OW T13N R11W 1'13N R10W Sterling Alaska Drilling Rig #1 13-5/8" 5000 psi BOP Stack I Shaffer 5M Annular I 4½" Pipe Ram Hydrill Type V 5M Double I Blind Ram I I , 9-5/8" 5M Drilling Spool 13-5/8" 3M Casing Head ,I1 13-3/8" casing I I I Choke Line Ill 2 1 Hydraulically Controlled Valve 5M working pressure 2 Manual valve 5M working pressure BOP drawing.xls Sterling Alaska Drilling Rig #i 5000 psi Choke Manifold 2" manual choke I I all valves 5M to choke line II I 2" remote hydraulic Ichoke I I I to degasser RECEIVED NOV 19 199~' Alaska 0!! & c~ ..q.o.n~ Commission Anchora~je Choke Manifold.xls Forcenergy Inc Coffee Creek #1 Well Diverter Sketch I l PreventerI 10" vent line, staked to the ground / 20" Annular "~ J ~ Annular preventer ! and hydraulic drilling spool valve I 211/2' 2M I manifolded such that one ~ ~ two hydraulic vent line valves is always open ~ ~ e~manifOlded such that One/ Drilling Spool is always open target 10" full opening valve drain valve to prevent freeze-ups? Weld on flange 20" drive pipe 10" vent line, staked to the ground ead Equipment List 1 20" drive pipe 133 ppf K-55, 3060 psi burst rating ~. 2 weld on flange 2M Rating 3 drilling spool 2M rating 4 20" Annular preventer 2M Rating 5 10" full hydraulic opening spool valve (150 psi rating) 6 two 10" hydraulic full opening vent line valve (150 psi rating) 7 two 10" vent lines - arranged 180° apart, spaced to vent over 100' from wellhead 8 Hydraulic control system to control annular preventer, spool valve, and two vent line valves. annular preventer and spool valve manifolded such that one is always open. two vent line valves manifolded such that one is always open. 9 Freeze protection: Vent lines set such that any fluid in the lines will drain out Operating procedure 1 On rig up - Test the system as follows: a. Close the annular preventer, make sure the spool valve opens. b. Close the vent line valve, make sure the other vent line valve automatically opens. c. Pump through the system to make sure it is not blocked. d. Check to make sure all the lines drain. 2 While drilling - keep the downwind vent line open. 3 On indications of a kick: a. Maintain maximum flow rate b. Space out drill sting such that the lower safety valve is above the drill floor. c. Close the diverter element, make sure diverter lines are open d. Shut down all non-essential equipment to minimize sources of ignition e. Evacuate non-essential personnel f. If necessary, change the diverter line base on changing wind direction - vent the gas downwind. g. Monitor the area for gas breaking through outside the conductor. If gas breakthrough is indicated then evacuate all personnel diverter sketch.xls Blow Out Prevention Equipment Description Sterling Alaska Drilling Rig #1 One 13-5/8" 5000 psi WP Shaffer SPH Annular BOP w/studded top and flanged bottom, H2S trim One 13-5/8" 5000 psi WP Hydril Type V Double gate BOP w/studded top and bottom, w/4-1/16" flanged outlets, H2S trim One 13-5/8" 5000 psi WP 25" H drilling spool w/4-1/16" flanged outlets, H2S trim Closing Unit - Valvcon 6 station w/9 x 15 gallon accumulator bottles, FMC model 606 triplex pump w/10 hp electric motor Remote Closing Unit - Valvcon 6 station w/air tube bundle to closing unit Choke Manifold - Barton 5000 psi WP w/ one 4"x 2" cross One Barton 4-1/16" 5000 psi WP valve Two Barton 2-1/16" 5000 psi WP valves Two WKM 2-1/16" 5000 psi WP valves Two 2" crosses One 2" positive choke One 2" Flocon adjustable choke Barton 4-1/16" 5000 psi WP HCR valve Degasser 2'x 10' Shop build degasser Remotely operated choke w/control panel COFFEE CREEK #1 PRESSURE INFORMATION The anticipated pressure at the total depth of 7,000' is 9.3 ppg mud weight equivalent. This equals 3385 psi bottom hole pressure. There are no anticipated overpressure zones and shallow gas is not expected. Shallow Gas The seismic over the proposed location has been reviewed and shows no indication of shallow gas down to 2,000' depth. A seismic section covering this zone is attached. Even though there are no indications of gas, we will still take precautions as if there were. The diverter will be rigged up and operational and the procedures as shown on the diverter sketch will be followed. Lost circulation and weighting material will be available on site for use if needed. Crews will be alerted to the possibility of gas and trained in the use of the diverter. Overpressures The pore pressures anticipated on the Coffee Creek #1 well were calculated based on offset wells that are producing from the Tyonek formation in Cook Inlet. The seismic data available are of average quality and velocity information derived from the seismic will not change the time vs depth information provided by the wells in the area. Instead of a seismic analysis, sonic logs of two offset wells were plotted and are enclosed. Plots of the sonic vs depth for the Superior Chuit State #1 and Tipco Pretty Creek #1 show what could possibly be a higher than normal pressure profile from 5,900' to 6,200' in each of the wells. The normal approach to determining overpressure would be to establish a normal compaction trend line for shales with the sonic log. Unfortunately, in the case of the Cook Inlet, there are no 'real' shales to use for this method. The deviation from trend line is still valid but only as a gas indicator. When density and neutron logs are plotted there is an indication that there is a gas effect present from 5,000' to 6,200' in the Pretty Creek well. The resistivity curve bears this out. The Chuit State #1 shows the same sonic trend at 6,200-6,400' but due to limited log coverage, density and neutron logs are not available. The resistivity curve does suggest the potential for gas in this interval. There are no other indications that anomalous pressure gradients will be encountered in the Coffee Creek well. Therefore our conclusion is that the well is normally pressured down to the 7,000' TD. Procedure for Calculating Anticipated Surface Pressure ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) the wellbore full of gas from bottom hole to surface. 1) ASP = ((FG x.052)-0.115) x Dc where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.115 = gas gradient in psi/ft Do = true vertical Depth of casing seat in ft RKB OR ORIGINJL 2) ASP= (PP x 0.052 x D) - (0.115 x D) where: PP = Formation Pore Pressure ( in lb/gal equivalent mud weight) at the next casing point which is tied back to surface or at TD (total depth) D = Depth of the deepest point where the casing will be exposed. ASP Calculations Drilling below surface casing (13-3/8" at 2000') Pore pressure = 9.3 ppg emw, Anticipated Fracture Gradient = 13.8 ppg emw. ASP or = ((FG x .052) - 0.115)x D = ((13.8 x .052) -0.115) x 2000' = 1205 psi ASP = (PP x 0.052 x D) - (0.115 x D) = (9.3 x .052 x 4500) - (.115 x 4500') = 2176 - 517 = 1659 psi Therefore ASP = 1205 psi Drilling below intermediate casing (9-5~8" at 4500') Pore pressure = 9.3 ppg emw, Anticipated Fracture Gradient = 15.6 ppg emw. ASP or = ((FG x .052) - 0.115)x D = ((15.6 x .052)- 0.115) x 4500' = 3133 psi ASP = (PP x 0.052 x D) - (0.115 x D) = (9.3 x .052 x 7000) - (.115 x 7000') = 3385 - 805 = 2580 psi Therefore ASP = 2580 psi Chuit State #1 Sec 8 T12N R11W Cook Inlet 1000 2000 3000 4OO0 5000 6000 7OOO 10 ...' 100 1000 Sonic Travel Time (ps/fi) Pretty Creek #1 Sec 2 T14N R10W Cook Inlet 1000 2000 3000 4000 5000 6000 7000 10.00 100.00 Sonic Log Travel Time (ps/fi) 1000.00 FORCENERGY INC COFFEE CREEK #1 DRILLING PROCEDURE , 2. 3. 4. 5. 6. 7. , 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Move in and rig up Sterling Alaska Drilling Rig #1 Rig up and drive 20" casing to refusal. The expected depth is 80' Nipple up and test diverter. Spud well. Drill 17¼" hole to surface casing point at 2,000 ft. Rig up electric line and log. Rig up casing crew and run 13-3/8" casing to TD. Run drillpipe and stab into the shoe. Circulate the casing and hole. Cement casing to surface. Nipple down diverter. Nipple up and test BOP and choke. Pick up bit and BHA. RIH. Test casing to 1,500 psi (casing burst strength 5,380 psi). Drill float collar and shoe. Drill 10' of new hole. Perform shoe test to leak off (for annular disposal). Drill to intermediate casing depth at 4,500'. POH. Rig up wireline. Log. Rig up casing crew. Run 9-5/8" casing. Circulate and condition mud. Rig up cementers. Cement casing to 3,000'. Leave space between top of cement and shoe of the 13-3/8" to inject drilling waste. Set slips. Nipple up wellhead and BOP. Test BOP. Pick up new BHA. RIH, test casing to 1,500 (casing burst is 6,870). Drill float collar and shoe. Drill 10' of new hole. Perform shoe test to 11.3 ppg or leak off, whichever comes first. Drill to TD. Circulate and condition mud. POH. Rig up wireline. Log. Make a conditioning trip between runs if necessary. Make a conditioning trip before running liner if hole conditions dictate. Rig up casing crew. Run 7-5/8" flush joint liner. Circulate. Cement liner. Set liner hanger. Set liner top packer Reverse out cement. RIH with 8¼" bit and clean out casing to top of liner. Test liner lap to 1750 psi. POH. RIH with 6%" bit. Clean out liner to float collar. Test liner to 1750 psi. POH. Rig up wireline and run bond log. Prepare to test well. Test program depends on log interpretation. Coffee Creek #1 Drilling Fluids Program Surface Hole: 17¼" Hole 133/_8'' Casing 2000' Mud Type: Fresh water / Gel Spud Mud Anticipated Fluid Properties Mud weight Plastic Viscosity Yield Point APl Fluid Loss Drilled Solids 8.8-9.5 ppg 5-10 cp 8-25 lb/100ft2 n/c 5% or less This interval will be drilled with a mud system built with fresh water, barite, bentonite, soda ash, caustic, and polymer extender. Potential problems that exist include gas kicks, hole cleaning, gravel, swelling clay, and lost circulation. If gravel is encountered raise viscosity with bentonite and polymer extender. Save this fluid for use in the intermediate hole section. Intermediate Hole: 12¼" Hole 95~'' Casing 4500' Mud Type: Fresh water / Gel Anticipated Fluid Properties Mud Weight Plastic Viscosity Yield Point APl Fluid Loss Drilled Solids 9.0-10.0 ppg 7-12 cp 7-20 Ib/100ft2 8-10 5-10% This interval will utilize the surface mud system. Treat this system for cement contamination. Build additional volume as required. Potential problems that may be encountered are hole cleaning, tight hole, bit bailing, gas kicks, and coal sloughing. In addition to the products used in the surface system the following products may be used, Desco CF, bicarbonate of soda, lignite, and Soltex. A tracer will be used in this section to distinguish formation fluids from mud filtrate on any tests. Drilling Fluid Program.doc Production Hole 8¼" Hole 7~'' Casing 7000' Mud Type: KCI Polymer Anticipated Fluid Properties Mud Weight Plastic Viscosity Yield Point APl Fluid Loss Drilled Solids 9.5-10.0 ppg 8-14 cp 12-25 Ib/100ft2 6 or less 5 % or less This interval will be drilled with a 3-6% KCI - Polymer mud system. The products used in this interval will be KCI, FIo-Vis, Drispac, Soltex, bentonite, caustic, soda ash, Resinex, and barite. Potential problems that may be encountered are gas kicks, lost circulation, and coal sloughing. A tracer will be used in this section to distinguish formation fluids from mud filtrate on any tests Drilling Fluid Program.doc STERLING ALASKA DRILLING Rig #1 DRILLING MUD SYSTEM 10ft Degasser ~ 38 ff ~.~ 38 ff b Possum Belly Shale Shaker Shaker Tank Desilter/Desander Combination Intermediate Tank Tank #1 - Shaker 10'Wx 38' L x 8¼' H 575 bbl Tank #2 - Volume 10'Wx 38' Lx 8¼' H 575 bbl 5.62 bbl/in 5.62 bbl/in Mud Pumps Two Gardner Denver PZ-9 triplex mud pumps, 1000 hp, 7" x 9" fluid end, Sumlar 20A-5000 pulsation dampener, compound driven. Tank #1 - Shakers 10' W x 38' Lx8¼' H 575 bbl Mud Tank System (1725 bbl. total volume) 5.62 bbl/in Tank #1 - Suction tank - 575 bb110'W x 38'L x 8¼' H wi3 compartments, slant bottom, internal plumbing, walkways, stairs, safety rails. Tank #2 - 575 bb110'W x 38'L x 8¼' H wi3 compartments, slant bottom, internal plumbing, walkways, stairs, safety rails Suction Pit Slugging Pit 38 ft Tank #3 - Shaker tank - 575 bb110'W x 38'L x 8¼' H wi3 compartments, slant bottom, internal plumbing, walkways, stairs, safety rails 10ft~ Mud System Equipment Shale Shaker - Tri-FIo tandem, double screen vibrating shale shaker w/2 Pacemaker 3 hp electric motors Desilter - Tri-FIo desilter w/16 x 4" cones Degasser Mud Hopper w/one Demco 6" x 8" Centrifugal pumps w/Reliance 75 hp electric motor One Demco 6" x 8" Centrifugal pump w/Reliance 75 hp electric motor Two Demco 5" x 6" Centrifugal pumps each w/Reliance 75 hp electric motor Agitators - four Morse mud agitators w/10 hp electric motors, One agitators w/5 hp electric motor Mud Guns Casing Program COFFEE CREEK #1 CASING DESIGN Setting Depth Size Specifications Top Bottom Hole Casing Weight Grade Coupling Length MD TVD MD TVD Driven 20" 133 K-55 Welde 100' Surf. Surf. 80' 80' 17½" 13-3/8" 72 L-80 BT&C 2000' Surf. Surf. 2000' 2000' 12%" 9-5/8" 47 L-80 BT&C 4500' Surf. Surf. 4500' 4500' 8%" 7-5/8" 29.7 L-80 FL4 2800' 4200' 4200' 7000' 7000' 20" Conductor Casing This casing string is not designed to hold pressure. 13-3/8" Surface Casing. 72# L-80 BT&C @ 2000' MD/TVD Basis: Pore pressure at casing shoe = 9.3 ppg emw (0.484 psi/fi) Mud weight at casing shoe = 9.5 ppg (0.494 psi/fi), buoyancy factor = .855 Fracture Gradient at casing shoe = 13.8 ppg emw Pore pressure at next casing point (4,500') - 9.3 ppg emw (0.484 psi/fi) Tension = buoyed weight of casing = 2000' x 72# x .855 b.f. = 123K Casing Rated = 1661K Safety Factor = 13.5 Burst = anticipated surface pressure (lesser of full column of gas from next casing point or full column of gas from the fracture gradient) = ((13.8 x .052)-0.115)x 2000'= 1205 psi or = (9.3 x .052 x 4500) - (.115 x 4500') = 1659 psi ASP = 1205 psi Casing rated 5380 psi Safety Factor = 4.5 Collapse = full evacuation = (9.5 x .052 x 2000') = 988 psi Casing rated = 2670 psi Safety Factor = 2.7 9-5/8" Intermediate/Production Casing 47# L-80 BT&C @ 4500' MD/TVD Basis: Pore pressure at casing shoe = 9.3 ppg emw (0.484 psi/fi) Mud weight at casing shoe - 9.9 ppg (0.515 psi/fi) buoyancy factor = .849 Fracture Gradient at casing shoe - 15.6 ppg emw Pore pressure at next casing point (7,000') - 9.3 ppg emw (0.484 psi/ft) Tension = buoyed weight of casing = 4500' x 47# x .849 b.f. = 180K Casing Rated = 1086K Safety Factor = 6.1 Burst - as production casing the design basis is a full column of gas from total depth. = (9.3 x .052 x 7000) - (.115 x 7000') = 2580 psi Casing rated 6870 psi Safety Factor = 2.7 Collapse = full evacuation = (9.9 x .052 x 4500') = 2317 psi Casing rated = 4750 psi Safety Factor = 2.1 7-5/8"' Production Liner 29.7# L-80 FL-4S from 4,200 to 7000' MD/TVD Basis: Pore pressure at casing shoe: 9.3 ppg emw (0.484 psi/ft) Mud weight at casing shoe = 10.0 ppg (0.520 psi/ft) buoyancy factor = .847 Tension = buoyed weight of casing = 2800' x 29.7# x .847 b.f. = 70.4K Casing Rated = 511K Safety Factor = 7.3 Burst = a full column of gas from total depth to the top of the liner less the pore pressure backup. Internal pressure = (9.3 x .052 x 7000) - (.115 x 2800') = 3063 psi External pressure = (9.3 x .052 x 4200) - 2031 psi Internal- external = 3063-2031 - 1032 psi Casing rated 6890 psi Safety Factor = 6.7 Collapse = full evacuation = (10.0 x .052 x 7000') = 3640 psi Casing rated = 4790 psi Safety Factor = 1.3 Forcenergy lnc Alaska Division COFFEE CREEK #1 CEMENTING PROGRAM t 3-3/8" Casing 13-3/8" casing x 17½" hole 13-3/8" casing x 20" casing 13-3/8" capacity Cement Yield - Lead Cement Yield - Tail Lead 0.6946 ft3/ft 0.9377 ft3/ft 0.8315 ft3/ft 2.06 ft3/sack 1.16 ft3/sack Open Hole 1500 fl - 80 ft x Cased hole 80 ft ft x Sacks 1850.41 ft3 / 2000 fl- 40 ff Tail Cement Open Hole Shoe Sacks 658.4 ft3 / Casing Shoe 2000 Previous Casing 80 Shoe Length 40 Top of Lead 0 Top of Tail 1500 0.695 ff3/~+ 80% excess = 1,775.40 0.938 ff3/ff+ 0%excess = 75.02 2.06 ft3/sack = 898 sacks 1,850.41 ft3 1500 ft x 0.695 ft3/ft + 80% excess = 625.14 ft3 x 0.832 ft3/ft + 0% excess: 33.26 ft3 568 sacks 1.16 ft3/sack = 658.40 Total Cement 898 sackslead + 568 sacks tail = 1466 Total sacks 9-5/8" Casing 9-5/8" casing x 12¼" hole 9-5/8" casing x 13-3/8" casing 9-5/8" capacity Cement Yield - Lead Cement Yield - Tail Lead 0.3132 ft3/ft 0.3262 ft3/f[ 0.411 ft3/ft 2.06 ft3/sack 1.15 ft3/sack Open Hole 4000 ft- 3000 ft x Cased hole 0 ft ft x Sacks 469.8 ft3 / 4500 fi- 80 fl Tail Cement Open Hole Shoe Sacks 267.78 ft3 / 0.313 f'[3/ft + 0.326 ft3/ft + 2.06 ft3/sack = Casing Shoe 4500 Previous Casing 2000 Shoe Length 80 Top of Lead 3000 Top of Tail 4000 50% excess = 469.80 ~3 0% excess = - fl3 228 sacks 469.80 fi3 4000 ff x 0.313 ff3/ff+ 50%excess = 234.90 x 0.411 ff3/ff+ 0% excess = 32.88 233 sacks 1.15 ft3/sack = 267.78 fi3 Total Cement 228 sackslead + 233 sacks tail = 461 Total sacks Cement Volumes.xls Page I of 2 7-5/8" Liner 7-5/8" casing x 8¼" hole 7-5/8" casing x 9-5/8" casing 7-5/8" capacity 9-5/8" capacity Cement Yield - Tail Open Hole Cased hole Shoe Above Liner Top 7000 ft- 300 ft 8O ft 100 ft Sacks 330.511 ft~ / 0.077 ft3/ft 0.0939 ft3/ft 0.2577 ft3/ft 0.411 1.15 ft3/sack Casing Shoe Previous Casing Shoe Length Liner Lap Feet above Liner Top 4500 ft x x x x 0.077 ft3/ft + 25% excess = 0.094 ft3/ft + 0% excess = 0.258 ft3/ft + 0% excess = 0.411 ft3/ft + 0% excess = 1.15 ft3/sac = 287 sacks 7000 45OO 8O 300 100 240.63 ft3 28.17 ft3 20.62 ft3 41.10 ft3 330.51 ft3 Cement Volumes.xls Page 2 of 2 Force~gy Inc Alaska Division COFFEE CREEK #1 Sec 19 T14N R10W 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 ' - ...... 0 5 10 15 20 25 30 35 40 45 DAYS SINCE SPUD Application for Annular Disposal of Drilling Waste Forcenergy Inc Coffee Creek #1 Forcenergy hereby applies for permission to dispose of the waste generated by drilling the Coffee Creek #1 well in the 13-3/8" x 9-5/8" annulus of that well. The information required is as follows: Location: 527' FWL 710' FSL of Sec 19 T14N R10W Depth to base of fresh water (there is no permafrost in the area): There are no water wells within ¼ mile. A nearby offset well, the Superior Chuit State #1 has been analyzed. Based on the water resistivity (Rwa), the base of the fresh water is just above 1900'. The computer analysis of the log is attached. Receiving and Confining Zone: The waste will be injected between the 13-3/8" and 9-5/8" casing strings. The 13-3/8" surface casing will be set at 2,000 ft in the Upper Tyonek formation. This formation is about 1,200 ft thick and consists of sandstone with interbedded coals. It is anticipated that the waste will enter the sandstone formations and be confined there by the coals. The Chuit State #1 log shows a confining coal at 1930 ft. The confining coal is about 15 ft thick. Volume and Density of Waste - The volume of waste to be disposed will include the surface mud system volume and the hole volume. The surface active system is approximately 1600 bbl and the hole volume is estimated to be 600 bbl based on hole enlargement from the 8½" drill bit size to 9½". This equals a total of 2,200 bbls. At the end of the well the mud density is anticipated to be 10 lb/gal. Estimated Pressure - The estimated pressure at the surface is equal to the fracture pressure at the injection point less the hydrostatic pressure plus the friction pressure. Fracture Gradient at 13-3/8" shoe- 13.8 lb/gal Friction pressure assuming injection at 10 bbl/min = 75 psi (from hydraulics analysis) ((13.8 lb/gal- 10.0 lb/gal) x 0.052 x 2000 ft) + 75 psi = 470 psi surface pressure The casing strings are rated as follows 13-3/8" 72 Ib/ft L-80 BTC 5380 psi burst 9-5/8" 47 Ib/ft L-80 BTC 6870 psi burst 2670 psi collapse 4750 psi collapse · WELL PERMIT CHECKLIST COMPANY .,,~"_.r,-_~_.h~.,.-... ~.~ WELL NAME~i~,',~. ~__f.¢,..~ ¢¢...~ PROGRAM: exp~C'dev [] redrll [] serv [] wellbore seg ~ ann. disposal para re~" FIELD& POOL /I.,,/~ INIT CLASS ~,,,,'.,,~"_,~.,. ~"'/// / GEOL AREA ~.~..--~2 UNIT:/¢ ,,4_2,,z~ ON/OFF SHORE ADMINISTRATION ENGINEERING A,~..~ DATE ' GEOLOGY _ REMARKS,.-, 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. (~ N 4. Well located in a defined pool .................. ~--.~"~¢.,-~-_.~-) --~----/~ 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells ..........'- 7, Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ....... /¢~, .~ .... Y N 9. Operator only affected party ................... ~ N 10. Operator has appropriate bond in force ............. ~ N 11. Cermit can be issued without conservation order ........ (~ N 12. Permit can be issued without administrative approval ...... ~ N 13. Can permit be approved before 15-day wait ........... (~ N 14. Conductor string provided ................... (~N 15. Surface casing protects all known USDWs ........... (~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... ~~ 17. CMT vol adequate to tie-in long string to surf csg ........ Y 18. CMT will cover all known productive horizons .......... ~ N 19. Casing designs adequate for C, T, B & permafrost ....... k.~ N 20. Adequate tankage or reserve pit ................. ~ N 21. If a re-drill, has a 10-403 for abandonment been approved... --Y--N. 22. Adequate wellbore separation proposed ............. ~ N 23. If diverter required, does it meet regulations .......... (~ N 24. Drilling fluid program schematic & equip list adequate ..... 25. DOPEs, do they meet regulation ................ 26. DOPE press rating appropriate; test to ~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ LY~ N 28. Work will occur without operation shutdown ........... f,,-Y~J~L, 29. Is presence of H2S gas probable ................. Y 30. Permit can be issued w/o hydrogen sulfide measures ..... (~ N 31. Data presented on potential overpressure zones ....... (~,,N 32. Seismic analysis of shallow gas zones .............. 33. Seabed condition survey (if off-shore) ...... ,,/.¢_.Z., .,~/.,.. Y N DATE z 34. Contact for we_eklyprogress reports ....... (~ N /////~/~-'"'Y~"~ name/phone lexploratory only] GEOLOGY: RPC/f¢~/~ ENGINEERING: COMMISSION: BEW (~/¢'/'~ DWJ~ RNC~ JDH_/~ co f_,~ - Comments/Instructions' HOW/Ijt - A:\FORMS\cheklist rev 09~97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : FORCENERGY, INC. WELL NAME : COFFEE CREEK #1 FIELD NAME : WILDCAT BOROUGH : MAT-SU STATE : ALASKA API NUMBER : 50-283-20094-00 REFERENCE NO : 98181 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-APR-1998 15:24 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/04/22 ORIGIN : FLIC REEL NAME : 98181 CONTINUATION # : PREVIOUSREEL : COf4~ENT : FORCENERGY INC., COFFEE CREEK #1, API# 50-283-20094-00 **** TAPE HEADER **** SERVICE NAM~ : EDIT DATE : 98/04/22 ORIGIN : FLIC TAPE NAME : 98181 CONTINUATION # : 1 PREVIOUS TAPE : COM~UENT : FORCENERGY INC., COFFEE CREEK #1, API# 50-283-20094-00 **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION · O01AiO DATE : 98/04/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ******************************************************************************* ******************************************************************************* ** ** ** SCHLUAiBERGER WELL SERVICES ** ** ** ** ** ******************************************************************************* ******************************************************************************* COMPANY NAME: Forcenergy, Inc. WELL: Coffee Creek #1 FIELD: Wildcat BOROUGH: Mat-Su STATE: Alaska API NUMBER: 50-283-20094-00 LOCATION: 527' FWL & 710' FSL SECTION: 19 TOWNSHIP: 14N RANGE: iOW PERMANENT DATUM: Ground Level Elevation: 620' LOG f~EASURED FROM KB 21.4' ABOVE PERMANENT DATUM LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-APR-1998 15:24 PAGE: ELEVATIONS CASING 1: CASING 2: BIT SIZE 1: BIT SIZE 2: KB: 641.4' DF: 640' GL: 620' 13.375" @ DRILLER DEPTH OF 1219' AND LOGGER DEPTH OF 1224' 9.625" @ DRILLER DEPTH OF 6715' AND LOGGER DEPTH OF 6719' 12.25" @ 6720' 8.5" @ 9757' ******************************************************************************* RUN #1 DATE LOGGED: 16-Mar-1998 TD DRILLER: 6720' TD LOGGER: 6719' TYPE FLUID IN HOLE: dispersed DENSITY: 10.35 VISCOSITY: 53 PH: 9.5 FLUID LOSS: 5 MUD RESISTIVITY: 2.1 @ 72 DEGF FILTRATE RESISTIVITY: 2.05 @ 64 DEGF MUD CAKE RESISTIVITY: 2.37 @ 64 DEGF MAXIMUM TEMP RECORDED: 114 ******************************************************************************* RUN #2 DATE LOGGED: 06-Apr-1998 TDDRILLER: 9757' TDLOGGER: 9763' TYPE FLUID IN HOLE: Polymer DENSITY: 9.5 PH: 9.3 MUD RESISTIVITY: 2.13 FILTRATE RESISTIVITY: 1.91 MUD CAKE RESISTIVITY: 1.84 MAXIMUM TEMP RECORDED: 149 VISCOSITY: 52 FLUID LOSS: 4.4 @ 53 DEGF @ 53 DEGF @ 53 DEGF LOGGING DISTRICT: LOGGING ENGINEER: WITNESS: Kenai, Alaska John Majcher Richard Nelson JOB REFERENCE NO: 98181 LDP/ANA: R KRUWELL THIS FILE CONTAINS THE MERGE MAIN LOG DATA FOR RUNS 1 AND 2 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-APR-1998 15:24 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 160 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 CIDP DTE ~iHO 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 IDPH DTE 0H~1094458 O0 000 O0 0 1 1 1 4 68 0000000000 CIMP DTE ~I~0 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 IMPH DTE OPiUM lO94458 O0 000 O0 0 1 1 1 4 68 0000000000 CILD DTE M~HO 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 ILD DTE 0H~I1094458 O0 000 O0 0 1 1 1 4 68 0000000000 CILMDTE MFIHO 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 ILM DTE OH~f1094458 O0 000 O0 0 1 1 1 4 68 0000000000 SFLU DTE OHMMi094458 O0 000 O0 0 1 1 1 4 68 0000000000 SP DTE MV 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 GR DTE GAPI 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DTE LB 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMDTE DEGF 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 f~RES DTE 0H~4~1094458 O0 000 O0 0 1 1 1 4 68 0000000000 HTENDTE LB 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 DT BHC US~Fl094458 O0 000 O0 0 1 1 1 4 68 0000000000 TT1 BHC US 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 TT2 BHC US 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 TT3 BHC US 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 TT4 BHC US 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 MRES BHC 0H~41094458 O0 000 O0 0 1 1 1 4 68 0000000000 MTE~BHC DEGF 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 GR BHC GAPI 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-APR-1998 15:24 PAGE: 4 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) TENS BHC LB 1094458 O0 000 O0 0 1 1 1 4 HTENBHC LB 1094458 O0 000 O0 0 1 1 1 4 DPHI LDT PU 1094458 O0 000 O0 0 1 1 1 4 RHOB LDT G/C3 1094458 O0 000 O0 0 i 1 1 4 DRHO LDT G/C3 1094458 O0 000 O0 0 1 1 1 4 PEF LDT 1094458 O0 000 O0 0 1 1 1 4 CALI LDT IN 1094458 O0 000 O0 0 1 1 1 4 NPHI CNL PU 1094458 O0 000 O0 0 1 1 1 4 RTNR CNL 1094458 O0 000 O0 0 1 1 1 4 TNPH CNL PU 1094458 O0 000 O0 0 1 1 1 4 TNRA CNL 1094458 O0 000 O0 0 1 1 1 4 NPOR CNL PU 1094458 O0 000 O0 0 1 1 1 4 RCNT CNL CPS 1094458 O0 000 O0 0 1 1 1 4 RCFT CNL CPS 1094458 O0 000 O0 0 1 1 1 4 CNTC CNL CPS 1094458 O0 000 O0 0 1 1 1 4 CFTC CNL CPS 1094458 O0 000 O0 0 1 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 9825.500 CIDP.DTE 22.406 IDPH.DTE IMPH. DTE 105.313 CILD.DTE 23.547 ILD.DTE 42 ILM. DTE 101 . 375 SFLU. DTE 51 . 844 SP.DTE 401 TENS.DTE 3730. 000 MTEM. DTE -999.250 MRES.DTE -999 DT.BHC 66.200 TT1.BHC 431.600 TT2.BHC 300 TT4.BHC 290.400 ~ES.BHC -999.250 MTEM. BHC -999 TENS.BHC -999.250 HTEN. BHC -999.250 DPHI.LDT 7 DRHO.LDT 0.039 PEF. LDT 0.000 CALI.LDT 2 RTNR.CNL 1.931 TNPH. CNL 11.443 TNRA.CNL 1 RCNT. CNL 3687.211 RCFT. CNL 1884.578 CNTC. CNL 3805 DEPT. IMPH. DTE ILM. DTE TENS. D TE DT. BHC TT4. BHC TENS. BHC DRHO. LDT RTNR. CNL RCNT. CNL 158.500 CIDP.DTE -999.250 CILD.DTE -999.250 SFLU. DTE 1007 000 MTEM. DTE -999 250 TT1.BHC -999 250 ~ES.BHC -999 250 HTEN. BHC -999 250 PEF. LDT -999 250 TNPH. CNL -999 250 RCFT. CNL -999.250 IDPH.DTE -999.250 ILD.DTE -999. 250 SP. DTE 82. 898 ~ES. DTE -999. 250 TT2. BHC -999.250 MTEM. BHC -999.250 DPHI.LDT -999.250 CALI.LDT -999.250 TNRA.CNL -999.250 CNTC. CNL 44 594 CIMP.DTE 438 CILM.DTE 000 GR.DTE 250 HTEN. DTE 000 TT3.BHC 250 GR.BHC 414 RHOB.LDT 729 NPHI.CNL 791 NPOR.CNL 196 CFTC. CNL -999.250 CIMP.DTE -999.250 CILM.DTE -999.250 GR.DTE 1.668 HTEN. DTE -999.250 TT3.BHC -999.250 GR.BHC -999.250 RHOB.LDT -999.250 NPHI.CNL -999.250 NPOR.CNL -999.250 CFTC. CNL 9. 492 9. 859 65. 125 -999.250 423.600 -999.250 2.583 17.072 11.443 2151.071 -999.250 -999.250 30.493 1119.743 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-APR-1998 15:24 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01AiO DATE : 98/04/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01A10 DATE : 98/04/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : COMPANY NAME: Forcenerg]z, Inc. WELL: Coffee Creek #1 FIELD: Wildcat BOROUGH: Mat-Su STATE: Alaska API iVUM~ER: 50-283-20094-00 LOCATION: 527' FWL & 710' FSL SECTION: 19 TOWNSHIP: 14N RANGE: iOW PERMANENT DATUM: Ground Level Elevation: 620' LOG MEASURED FROM KB 21.4' ABOVE PERMANENT DATUM ELEVATIONS KB: 641.4' DF: 640' GL: 620' CASING 1: CASING 2: 13.375" @ DRILLER DEPTH OF 1219' AND LOGGER DEPTH OF 1224' 9.625" @ DRILLER DEPTH OF 6715' AND LOGGER DEPTH OF 6719' BIT SIZE 1: 12.25" @ 6720' BIT SIZE 2: 8.5" @ 9757' ******************************************************************************* RUN #1 DATE LOGGED: 16-Mar-1998 TDDRILLER: 6720' TD LOGGER: 6719' TYPE FLUID IN HOLE: dispersed DENSITY: 10.35 VISCOSITY: 53 PH: 9.5 FLUID LOSS: 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-APR-1998 15:24 PAGE: MUD RESISTIVITY: FILTRATE RESISTIVITY: MUD CAKE RESISTIVITY: 2.1 @ 72 DEGF 2.05 @ 64 DEGF 2.37 @ 64 DEGF MAXIMUM TEMP RECORDED .. 114 LOGGING DISTRICT: LOGGING ENGINEER: WITNESS: Kenai, Alaska John Majcher Richard Nelson THIS FILE CONTAINS THE REPEAT DATA FOR RUN #1 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 160 4 66 1 5 66 6 73 7 8 9 11 12 13 14 15 16 0 0.5 FT 6 65 68 65 66 68 66 0 65 FT 66 68 66 1 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 CIDP DR1 f~HO 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 IDPH DR1 OH~M1094458 O0 000 O0 0 2 1 1 4 68 0000000000 CIMP DR1 ~i~0 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 IMPH DR1 0PL~1094458 O0 000 O0 0 2 1 1 4 68 0000000000 CILD DR1 MFiHO 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 ILD DR1 OH~ff~ 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 CILMDR1 ~4~0 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 ILM DR1 0I~4M1094458 O0 000 O0 0 2 1 1 4 68 0000000000 SFLU DR1 OH~M1094458 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-APR-1998 15:24 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SP DR1 MV 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 GR DR1 GAPI 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 TENS DR1 LB 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 MTEMDR1 DEGF 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 ~RES DR1 0H~4~1094458 O0 000 O0 0 2 1 1 4 68 0000000000 HTENDR1 LB 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 DT BR1 US~Fl094458 O0 000 O0 0 2 1 1 4 68 0000000000 TT1 BR1 US 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 TT2 BR1 US 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 TT3 BR1 US 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 TT4 BR1 US 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 f~RES BR1 0H~1094458 O0 000 O0 0 2 1 1 4 68 0000000000 MTEMBR1 DEGF 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 GR BR1 GAPI 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 TENS BR1 LB 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 HTENBR1 LB 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 DPHI LR1 PU 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 RHOB LR1 G/C3 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 DRHO LR1 G/C3 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 PEF LR1 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 CALI LR1 IN 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CR1 PU 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 RTNR CR1 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 TNPH CR1 PU 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 TNRA CR1 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 NPOR CR1 PU 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 RCNT CR1 CPS 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 RCFT CR1 CPS 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CR1 CPS 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CR1 CPS 1094458 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA DEPT. 6742.500 CIDP.DR1 IMPH.DR1 16.483 CILD.DR1 ILM. DR1 16.081 SFLU.DR1 TENS.DR1 2283.000 MTE~.DR1 DT. BR1 -999.250 TT1.BR1 TT4.BR1 -999.250 MRES.BR1 TENS.BR1 -999.250 HTEN. BR1 DRHO.LR1 0.054 PEF.LR1 RTNR.CR1 6.000 TNPH. CR1 RCNT. CR1 1450.712 RCFT. CR1 DEPT. 6100.000 CIDP.DR1 IMPH.DR1 6.828 CILD.DR1 ILM. DR1 9.341 SFLU. DR1 TENS.DR1 3291.000 MTEM.DR1 DT.BR1 -999.250 TT1.BR1 73.796 76.000 17.119 112 816 -999 250 -999 250 -999 250 2 623 118 938 239 355 150.204 110.664 6.586 113.721 -999.250 IDPH.DR1 13.551 CIMP.DR1 ILD.DR1 13.158 CILM. DR1 SP.DR1 -30.000 GR.DR1 ~4RES.DR1 1.153 HTEN. DR1 TT2.BR1 -999.250 TT3.BR1 MTE~.BR1 -999.250 GR.BR1 DPHI.LR1 15.334 RHOB.LR1 CALI.LR1 12.332 NPHI.CR1 TNRA.CR1 5.574 NPOR.CR1 CNTC. CR1 1448.746 CFTC. CR1 IDPH.DR1 6.658 CIMP.DR1 ILD.DR1 9.036 CILM. DR1 SP.DR1 -18.125 GR.DR1 ~RES.DR1 1.157 HTEN.DR1 TT2.BR1 -999.250 TT3.BR1 60.670 62.185 128.955 103.409 -999.250 -999.250 2.448 65.713 118.938 264.213 146.458 107.056 68.689 1154.678 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-APR-1998 15:24 PAGE: TT4.BR1 -999.250 MiRES.BR1 TENS.BR1 -999.250 HTEN. BR1 DRHO.LR1 -0.004 PEF. LR1 RTNR.CR1 3.763 TNPH. CR1 RCNT. CR1 2380.591 RCFT. CR1 -999.250 MTE~.BR1 -999.250 DPHI.LR1 3.349 CALI.LR1 31.099 TNRA. CR1 676.049 CNTC. CR1 -999.250 GR.BR1 10.745 RHOB.LR1 13.004 NPHI.CR1 3.300 NPOR.CR1 2377.146 CFTC. CR1 -999.250 2.526 30.641 31.751 730.542 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01AIO DATE : 98/04/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01AIO DATE : 98/04/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : COMPANY NAME: Forcenergy, Inc. WELL: Coffee Creek #1 FIELD: Wildcat BOROUGH: Mat-Su STATE: Alaska API ArUM~ER: 50-283-20094-00 LOCATION: 527' FWL & 710' FSL SECTION: 19 TOWNSHIP: 14N RANGE: iOW PERMANENT DATUM: Ground Level Elevation: 620' LOG MEASURED FROM KB 21.4' ABOVE PERMANENT DATUM ELEVATIONS KB: 641.4' DF: 640' GL: 620' CASING 1: CASING 2: 13.375" @ DRILLER DEPTH OF 1219' AND LOGGER DEPTH OF 1224' 9.625" @ DRILLER DEPTH OF 6715' AND LOGGER DEPTH OF 6719' BIT SIZE 1: 12.25" @ 6720' BIT SIZE 2: 8.5" @ 9757' LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-APR-1998 15:24 PAGE: RUN #2 DATE LOGGED: 06-Apr-1998 TD DRILLER: 9757 ' TD LOGGER: 9763 ' TYPE FLUID IN HOLE: Polymer DENSITY: 9.5 PH: 9.3 MUD RESISTIVITY: 2.13 FILTRATE RESISTIVITY: 1.91 MUD CAKE RESISTIVITY: 1.84 MAXIMUM TEMPRECORDED: 149 VISCOSITY: 52 FLUID LOSS: 4.4 @ 53 DEGF @ 53 DEGF @ 53 DEGF LOGGING DISTRICT: LOGGING ENGINEER: WITNESS: Kenai, Alaska John Majcher Richard Nelson JOB REFERENCE NO: 98181 LDP/ANA: R KRUWELL THIS FILE CONTAINS THE REPEAT DATA FOR RUN #2 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 128 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 8 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-APR-1998 15:24 PAGE: 10 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 CIDP DR2 I~!HO 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 IDPH DR2 OP24M1094458 O0 000 O0 0 3 1 1 4 68 0000000000 CIMP DR2 IvR~HO 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 IMPH DR2 0P2~41094458 O0 000 O0 0 3 1 1 4 68 0000000000 CILD DR2 I~fHO 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 ILl) DR2 Otff4M1094458 O0 000 O0 0 3 1 1 4 68 0000000000 CILMDR2 I~4JfO 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 ILM DR2 0P24~1094458 O0 000 O0 0 3 1 1 4 68 0000000000 SFLU DR2 0HJ~41094458 O0 000 O0 0 3 1 1 4 68 0000000000 SP DR2 MV 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 GR DR2 GAPI 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 TENS DR2 LB 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 DT BR2 US/F 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 TT1 BR2 US 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 TT2 BR2 US 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 TT3 BR2 US 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 TT4 BR2 US 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 DPHI LR2 PU 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 RHOB LR2 G/C3 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 DRHO LR2 G/C3 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 PEF LR2 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 CALI LR2 IN 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CR2 PU 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR CR2 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH CR2 PU 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA CR2 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR CR2 PU 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 RCNT CR2 CPS 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT CR2 CPS 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CR2 CPS 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CR2 CPS 1094458 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9814.000 CIDP.DR2 19.859 IDPH.DR2 50.344 CIMP.DR2 IMPH.DR2 52.875 CILD.DR2 20.906 ILD.DR2 47.813 CILM. DR2 ILM. DR2 51.125 SFLU. DR2 46.688 SP.DR2 394.250 GR.DR2 TENS.DR2 4190.000 DT.BR2 65.400 TT1.BR2 434.000 TT2.BR2 TT3.BR2 432.400 TT4.BR2 306.800 DPHI.LR2 7.811 RHOB.LR2 DRHO.LR2 0.040 PEF.LR2 3.094 CALI.LR2 2.729 NPHI.CR2 RTNR.CR2 1.655 TNPH. CR2 8.105 TNRA.CR2 1.535 NPOR.CR2 RCNT. CR2 3650.273 RCFT. CR2 2183.061 CNTC. CR2 3767.077 CFTC. CR2 DEPT. 9455.500 CIDP.DR2 49.594 IDPH.DR2 20.141 CIMP.DR2 IMPH. DR2 18.453 CILD.DR2 50.688 ILD.DR2 19.719 CILM. DR2 ILM. DR2 20.125 SFLU. DR2 18.938 SP.DR2 395.750 GR.DR2 TENS.DR2 5340.000 DT.BR2 75.300 TT1.BR2 482.800 TT2.BR2 18.891 19.547 75.625 298.000 2.576 13.269 8.105 2491.740 54.156 49.656 53.906 346.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-APR-1998 15:24 PAGE: 11 TT3.BR2 484.000 TT4.BR2 DRHO.LR2 0.040 PEF. LR2 RTNR.CR2 2.263 TNPH. CR2 RCNT. CR2 3513.403 RCFT. CR2 350.400 DPHI.LR2 2.887 CALI.LR2 16.841 TNRA.CR2 1403.268 CNTC. CR2 14.009 RHOB.LR2 8.555 NPHI.CR2 2.164 NPOR.CR2 3571.715 CFTC. CR2 2.470 17.164 16.394 1653.136 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION . O01AiO DATE : 98/04/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE · 98/04/22 ORIGIN : FLIC TAPE NAME : 98181 CONTINUATION # : 1 PREVIOUS TAPE : COI~ENT : FORCENERGY INC., COFFEE CREEK #1, API# 50-283-20094-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/04/22 ORIGIN : FLIC REEL NAME : 98181 CONTINUATION # : PREVIOUS REEL : COf~f : FORCENERGY INC., COFFEE CREEK #1, API # 50-283-20094-00
