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196-033
XHVZE Pages NOT Scanned in this Well History File 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 RESCAN Color items - Pages Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA y Diskettes, No.~~'~ [] Other, No/Type OVERSIZED Logs of various kinds Other Complete COMMENTS: 1 /.-./ ¢ Scanned by: Beved~Vincent TO RE-SCAN Nathan Lowell Notes: Re-Scanned by: Be~edy Dianna Vincent Nathan Lowell Date: Isl ') ) Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907 ~263-457 4 ConocóP'hillips May 23, 2005 RECE'\/ED MAY 242005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 CºmmissionJ Subject: Well Completion Report for Bergschrund 2A (APD #196-033 I 305-055) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent P&A operations on the well Bergschrund #2A . If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ¡¡(.)I/~ M. Mooney Wells Group Team Leader CP AI Drilling and Wells t"'1 2nur .. """NE·n.\ fin I\\! 2 ~(.JJ ~) scA,~ t.,,, nH-\ ~ MM/skad OR\G\t~AL ') D ) STATE OF ALASKA RECEIVE ' ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 2ô l005 WELL COMPLETION OR RECOMPLETION REPORT AND [ G Gas U Plugged [] Abandoned l.::J Suspended 0 WAG 0 M~~dJ:Ws1'S~ b~S CeJn$. Commi;itsion 20AAC 25.105 20AAC 25.110 Development [Alu;hOragl<PloratOry 0 No. of Completions _ Other Service 0 Stratigraphic TesO 12. Permit to Drill Number: 1 a. Well Status: Oil 0 GINJ 0 WINJ 0 WDSPL D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 964' FNL, 1370' FWL, Sec. 9, T11 N, R5E, UM At Top Productive Horizon: 458' FSL, 58' FWL, Sec. 4, T11 N, R5E, UM Total Depth: 525' FSL, 3' FWL, Sec. 4, T11 N, R5E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 390004 y- TPI: x- 388710 y- Total Depth: x- 388656 y- 18. Directional Survey: Yes 0 Nol.::J 5969823 5971264 5971331 Zone-4 Zone-4 Zone-4 21. Logs Run: none 22. 5. Date Comp., Susp., r or Aband.: 4/21/2005 (Abandoned) 6. Date Spudded: February 8, 1996 7. Date TO Reached: March 30, 1996 8. KB Elevation (ft): 43' RKB 9. Plug Back Depth (MD + TVD): surface 10. Total Depth (MD + TVD): 7896' MD 1 7508' TVD 11. Depth where SSSV set: none 19. Water Depth, if Offshore: N/A feet MSL CASING SIZE WT. PER FT. 16" 62.58# 9.625" 53.5# 7" 26# GRADE B L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 43' 110' 43' 110' 43' 1827' 43' 1827' 43' 7866' 43' 7478' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 7368'-7454' MD 6987'-7072' TVD HOLE SIZE 20" 12,25" 8.5" 24. SIZE 3.5" 25. 196-033 1 305-055 13. API Number: 50-103-20232-01 14. Well Name and Number: Bergschrund 2A 15. Field/Pool(s): Colville River Field Alpine Oil Pool 16. Property Designation: ADL 372095 17. Land Use Permit: n/a 20. Thickness of Permafrost: n/a CEMENTING RECORD AMOUNT PULLED 350 sx AS I 335 sx AS I, 550 sx ASIII 270 sx Class G TUBING RECORD DEPTH SET (MD) 7177' PACKER SET 7165' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED SCANNED MAY 2 ? 2005 n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date ofT est Hours Tested Production for OIL-BBL GAS-MCF Plugged & Abandoned WA TER-BBL CHOKE SIZE GAS-Oil RATIO Flow Tubing Casing Pressure press. psi 27. Test Period --> Calculated OIL-BBL GAS·MCF 24-Hour Rate -> WATER-BBL CORE DATA OIL GRAVITY - API (corr) not available Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". .f/v. <i!...:I)).,..!tt:l-u.j~ RBDMS 8FL MAY 2 5 2DD5 ~ ~t~:_,:,..,~,. NONE Form 10-407 Revised 12/2003 CONTINUED ON REVERSE [lRIGI[\iAL ,i.' ~i~ t.?S-- '¡ p; ../ ~\' 28. ) ) 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Bergschrund #2A sent in prior correspondence N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Mooney @ 265-4574 Printed Name Signature J j l'ike Mooney r~ Title: Phone Wells Group Team Leader .2(,~3 --4571./ Date 5/:2 3/ð5 Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ) ) BERGS 2A Well Events Summary Date Summary 03/16/05 REMOVED ALL OF 0.23" ELECTRIC LINE FROM WELL W/INDUCTIVE COUPLER. LINE WAS CONNECTED FROM COUPLING/HANGER AT SURFACE TO COUPLING DOWNHOLE IN XN NIPPLE AT 7131'. VERIFIED WELL IS STILL DEAD. DISCONNECTED J BOX WIRES, LATCHED RETREIVED UPHOLE COUPLING/HANGER FROM WELLHEAD. BACKTHREADED CABLE THRU SURFACE EQUIPMENT & SPOOLED UP 7150' OF CABLE W/DOWNHOLE INDUCTIVE COUPLER. WELL LEFT SHUT IN AT MASTER. BACKED OUT ALL LOCKDOWN SCREWS ON TOP HAT. VR PLUGS HAVE BEEN REMOVED. WELL IS DEAD. 03/17/05 DEMO'D OLD .23 LINE REMOVED FROM BERG2A AND TRAVELED BACK TO KRU 03/17/05 PT TREE TO 3000 PSI, GOOD. PT IA & TBG TO 2500 PSI, GOOD. EQUALIZED & PULLED XXN PLUG W/ PERMANENT PRESSURE GAUGE @ 7131' RKB. PUMP 10 BBLS OF DIESEL DOWN TBG @ 2 BPM 1700 PSI, FOR INJECTIVITY TEST. TAG FILL @ 7452' RKB, EST 2' OF FILL. PULL 1.5" DV @ 7085' RKB. JOB I N PROGRESS. 03/20/05 SET 2.81" STANDING VALVE @ 7131' RKB. DISPLACED TBG & IA W/290 BBLS OF 9.6 BRINE. PULLED STANDING VALVE @ 7131' RKB. 03/20/05 ICE ROAD AND ICE PAD COSTS INITIAL PLUS ADDITION 03/23/05 CTU WAITED ON LOCATION TO BE SET-UP. 03/24/05 COMPLETED CEMENT SQUEEZE AND PLUG. UNABLE TO GET PAST OLD CEMENT COLLAR @ 7315' RKB. PUMPED 26 BBLS OF 15.8# CLASS G CEMENT W/ ADDITIVES. BULLHEADED 1 ST 4.5 BBLS FROM 7305' RKB AND LAYED IN THE THE REMAINING 21.5 BBLS FROM 7305' RKB UP TO 5800' RKB. WELL 4 BBLS OF CEMENT. PLACED 5 BBLS OF CEMENT IN IA. LEFT BOTH TBG AND IA FULL OF 9.7# BRINE. EST. CEMENT TOP @ 6375' RKB. 03/25/05 DRIFT TUBING TO 2.25" CENTRALIZER TO 6020' WLM, DRIFT TUBING WITH 2.809" G-RING TO 1300'WLM, PT TUBING & IA TO 1500# FOR 30 MIN EACH BOTH HELD SOLID W/ NO LOSSES. PERFORMED NO FLOW TEST ON BOTH TBG AND IA (PASSED) [Tag] 03/26/05 SET BAKER N2 BRIDGE PLUG WITH MID ELEMENT AT 1010' (TOP AT 1009.5') -- SHOT 9 TBG PUNCHER HOLES (SMALL CHARGES) FROM 1002' TO 1004'. CIRCULATED 1 BBL AND VERIFIED GOOD RETURNS. BLED TBG, lA, & OA TO 0 PSI. 03/28/05 PUMPED SURFACE CEMENT PLUG USING 42 BBLS OF 15.8# AS1 CEMENT. CIRCULATED CEMENT DOWN TBG AND UP IA UNTIL GOOD CEMENT RETURNS WERE SEEN. WITNESSED BY STATE INSPECTOR [Cement-Poly Squeeze] 04/01/05 BEGIN EXCAVATION OF WELL FOR WELLHEAD CUT-OFF 04/02/05 COMPLETED EXCAVATION OF WELL - READY FOR WELDERS 04/04/05 CUT CONDUCTOR CASING WINDOWS - DRILLED 9 5/8" AND HAD DIESEL TO SURFACE - DRILLED, TAPPED AND ADDED A 1/4" VALVE TO SECURE WELL - PLAN FORWARD IN PROGRESS 04/06/05 PUMPED.5 BBLS DIESEL TO 1000 PSI THREE TIMES -100 PSI LOSS IN 30 MINUTES - BLED BACK TO ZERO - OA CONTINUED TO BUILD PRESS. AFTER BLEEDING ) ) BERGS 2A Well Events Summary 04/07/05 BLED OFF 30 PSI ON 133/8" - DRILLED AND TAPPED FULL OPENING 3/4" VALVE ON 133/8" CASING FOR BRINE SWEEP - TAGGED CEMENT TOP @ 23' (.7 BBLS) 04/08/05 Bleed OA for well secure, assist roustabouts in prep for P&A. - RIG UP TANK AND DISPLACE CASING FLUIDS WITH 9.7# CACL - WELL CONTINUED TO BUILD PRESS. AFTER BRINE JOB - READY TO CEMENT [ANN COM ISSUES, WH Maintenance] 04/09/05 PUMPED 1.7 BBLS CEMENT TO SEAL 9 5/8" ANNULUS - PERFORMED THREE HESITATION SQUEEZES TO 500 PSI TO SEAL ANNULUS [Cement-Poly Squeeze] 04/10/05 DRILLED OUT 1/4" BALL VALVE AND 3/4" BALL VALVE ON 95/8" TO CHECK FOR PRESSURE POST CEMENT JOB - NO PRESSURE SEEN BUT SLIGHT AMOUNT OF DIESEL - UNABLE TO USE TORCH 04/12/05 0 PSI ON OA. FOUND RATTY (DIESEL CONTAMINATED) CEMENT IN OA WELLHEAD VALVE. CHECKED LOWER TAPPED VALVES ON OA, FOUND CEMENT OF SAME CONSITENCY @ THESE VALVES ALSO. REMOVED TAPPED VALVES AND PROBED INSIDE OF OA DUG AND CHIP OUT CEMENT IN OA. LOOKS OK. 04/13/05 CHECKED OA NO PRESSURE & NO FLUID. 04/19/05 REMOVED WELLHEAD, CUT OFF CONDUCTOR, CSGS, & TBG 3' BELOW THE TUNDRA. DRESSED UP STUB FOR UPCOMING CAP INSTALLATION AFTER AOGCC INSPECTION. 04/21/05 P & A COMPLETED. WELDED DATA CAP ON TOP OF WELL. AOGCC ON LOCATION TO WITNESS CEMENT LEVELS AND CAPPING. COVERED WELL WITH EXISTING OVERBURDEN AND GRAVEL. PHilliPS Ala~.la Inc. A Subsidiary of PHILLIPS PETROLEUM'COMPANY r 1 ¡BERGSCHRUND 2A , I API: 501032023201 SSSV Type: Nipple Annular Fluid: CONDUCTOR (0-110, 00:16.000, Wt:62.58) TUBING (0-7177, 00:3.500, ID:2.992) SURF CASING (0-1827, 00:9.625, Wt:53.50) NIP (7046·7047, OD:3.500) Gas Lift landrel/Dummy Valve 1 (7085-7086, OD:6.018) NIP (7131·7132, OD:3.500) PKR (7165-7166, 00:6.059) PROD CASING (0-7866, 00:7.000, Wt:26.00) Perf (7368-7454) FISH (7490-7510, OD:3.5QO) ) Well Type: EXPLOR Orig Completion: 4/5/96 Last W/O: 4/7/01 Ref Log Date: TO: 7896 ftKB Max Hole Angle: 26 deg @J 5440 Size 16.000 9.625 7.000 Top o o o Bottom 110 1827 7866 Bottom 7177 -: I TVD 6800 VMfr BERGSCHRUND2A Angle @J TS: deg @J Angle @J TO: 9 deg @J 7897 Rev Reason: Set permanent PANEX gauges by ImO Last Update: 5/2/01 TVD 110 1827 7478 Wt 62.58 53.50 26.00 Grade B L-80 L-80 Thread BTC Reference Log: Last Tag: 7453 Last Tag Date: 3/31/01 ! Casing String· ALL Description CONDUCTOR SURF CASING PROD CASING Tubing String· TUBING Size I Top I 3.500 0 I Perforations Summary , ~ Interval I TVD I Zone I Status I 8F6t SP4 FI Date I Type I Comment 7.368 -7454 6987 - 7072 4/8/96 .IPERF 4spf(?)~ unconfirmed Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 7085 6710 CAMCO MMM CAMCO Other (plugs, :equip., etc.) - JEWELRY Depth TVD Type 7.046 6672 NIP 7131 6755 NIP 7165 6788 PKR . Fish . FISH I Depth I 7.490 FISH . General Notes' Date Note 4/15/96 Cut Tubing Tail off at 7177' MD wlmechanical cutter. 4/2/01 Tubing & IA loaded with 10.3 ppg brine with 2000' diesel cap 4/7/01 Set permanent PANEX gauge assembly w/electric wire communication to surface. Wt 9.30 I Grade I L-80 Thread EUE 8RD MOD DMY V Type V OD Latch Port TRO o Date Run 4/4/96 Vlv Cmnt Description 1.5 TG 0.000 Otis 'X' Landing Nipple Otis 'XN' Landing Nipple - set permanent PANEX gauge 4/7/01 Baker 'FAB-1' Packer, w/10' GBH·22 Locator Seal: 7164 -7174' Description I Comment I Perf Guns and cut off Tail Pipe (lengths unknown) ID 2.813 2.7.50 4.000 Re: Alpine 1 Band Berg2A P & A ) ~~y~U - \~Io-O ~ 7 Subject: Re: AlpinelB and Berg2A P & A From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Mon, 18 Apr 2005 12:52:19 -0800 To: "Schwartz, Guy L" <Guy.L.Schwartz@conocophillips.com> Guy, Thanks for the update. Good idea to monitor 1 B for a few more days as you plan. Good that it is not building up. Tom Schwartz, Guy L "Wrote: Tom, Quite update on these wells. Berg2A OA still at 0 psi. We are planning on cutting the wellhead in the next day and finishing the P & A. Alpine 1 B OA has been bled to 0 psi over the weekend. Has stayed there for 2 days now. We are continuing to mon itor it.. Thanks, Guy Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.l. schwartz@conocophillips.com SCANNED J~PR 1 820D5 1 of 1 4/18/2005 1 :28 PM Alpine 1 B and Bergschrund 2A P & A ) ) ('tS"-O:)_·:Ü . - Subject: Alpine IB and Bergschrund 2A P & A From: "Schwartz, Guy L" <Guy.L.Schwartz@conocophillips.cOln> Date: Thu, 14 Apr 2005 16:21 :58 -0500 To: tom_maunder@admin.state.ak.us CC: "Mooney, M" <M.Mooney@conocophillips.com> \<;<o-'O~ 7 Tom, To followup our conversation this morning here is a brief history of each well regarding the OA pressure we have seen: Berg 2A: Lower cement plug was pumped with no issues and pressure tested good. Upper cement plug from 1000' in both the IA and tubing went as planned also. OA showed some pressure (approx. 20psi) but could not be bled down. Check cement level in OA with plumb bob and found ledge down about 30'. Pumped cement from surface into OA and got in about 1.7 bbl of AS1 into the annulus. Well is currently dead and we are continuing to monitor it before we proceed to cut the well head string below ground level. Alpine 1B: The lower cement plug was placed and tested with no issues. Upper cement plug from 1000' in IA and tubing went as planned. This well also showed about 28 psi on the OA before operations started and attempts to bleed down were not successful. Could bleed to zero but would build back up to 28 psi in matter of hours. Pumped 17 bbls of AS 1 cement from surface and still have some residual pressure. Have done several bleed cycles and it is currently down to 10 psi after sitting overnight. Our plan is to continue the bleed cycles and see if we can further reduce the pressure. We can still pump another cement squeeze on this well but the volume will be very small based on our last plumb bob measurement. Summary: As we discussed it is most likely hydrates causing the trapped pressure migrating up a micro-annulus in the OA '. cement column (in both wells). With the continued wellwork (cementing, fluid swaps etc) warming, up the annulus mo re gas is released. With Alpine 1 B the well should reach equilibrium soon since activity on the wèll has stopped.. We have some time here (ice road limited) to bleed, possibly cement again, and monitor the situation before making a final call whether to move forward with cutting the wellhead. Berg 2A seems to be dead in the OA but will continue to monitor. We will keep you posted on the operation. Thanks, Guy Schwartz Drilling and Wells Engineer offi ce: 907-265-6958 Cell: 240-5696 ATO-1512 guy.l.schwartz@conocophillips.com 1 of 1 4/18/2005 1 :28 PM ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg . ]?æJ if{Z1Ið5' P. I. Supervisor {( DATE: March 28, 2005 FROM: John Crisp, Petroleum Inspector SUBJECT: Surface Cement Job Bergschrund 2A Conoco/Phillips Alaska PTD 196-033 March 28, 2005: I traveled to Alpine well Bergschrund 2A to witness the surface cement permanent abandonment plug. I arrived on Location & the cement unit was rigging up on the tubing to pump cement down the 3.5" tubing & up the 7" casing. Permanent packer is installed in the 3.5" tubing @ 1010' MD. Tubing is perforated from 1004' MD to 1002'MD. I witnessed 15.8 ppg arctic set cement pumped down the tubing to a depth of 1 004' MD. 38bbl's were:away when cement was observed @ surface from the<· 3.5"x 7" annulus. 42 total bbl's cement was pumped. Final circulating pressure was 1200 psi @ 4bpm. . Summa·rv: I witnessed 15.8 arctic set cement pumped down the tubing & up the annulus on Alpine Bergschrund 2A. The swab valve on the tree & the IA valve were closed after cement was observed @ surface. Attachments: None Non-Confidential ~SCj\NNED MAY 3 1. 2005 Surface Cement Job Bergschrund 2A 03-28-05 JC-l.doc Re: Alpine 1B and Bergschrund 2A P & A (pilings) ) ,) '4. Subject: Re: Alpine IB and Bergschrund 2A P & A (pilings) From: Thomas Maunder <tom_lnaunder@admin.state.akus> Date: Mon, 14 Mar 2005 16:30:17 -0900 To: "Schwartz, Guy L" <Guy.L.Schwartz@conocophillips.com> ~.~ \~Co-'Q~ ~ Thanks for the notice Guy. You might get with Tom Brassfield from Drilling or Randy Kanady from Enviro regarding some sort of cutter. I think there have been several old pads abandoned in the past couple of years and some of them had piles to remove. No sense reinventing the wheel. Good luck with the work. Tom Maunder Schwartz, Guy L "Wrote: Tom, As per our conversation today the Berg 2A and Alpine 1 B wells each have 5 pilings (18" aD pipe) set up as a protective barrier facing the upstream side of the wellhead. (shaped like a V). Plan is to excavate or use some type of piling cutter to remove these 3' below the tundra level the same as the wellhead. Thanks, Guy Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 Ruy.l.schwartz@cqnocophíllips.com 1 of 1 4/18/2005 1 :27 PM ," ) ~'" ~.-:, I'M" '~I~r¡i" .. \ ¡' I. ¡: /\', ~{(1 LJ , ~',,," } ,:~ \ ,',8 \ !; / £1":. ,,\\~ f ,,\ / ð\\. \,' '=:~qJ\\i\I" ;" I \ j ~ iLJU I,~ LII \ \ / r' I 1 ) Ifr; -ð33 ~@ iTfÆÆ íì iŒ~; rñi fL ,[I í I l I ¡ \ i. I' l ¡ ~ f fi, :¡ '. ; U;. "I-E" ~ t,.' AlfA~KA. OIL AND GAS CONSERVATION COMMISSION I I / I / / FRANK H. MURKOWSK'J GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mike Mooney Wells Group Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Colville River Bergschrund #2A Sundry Number: 305-055 Dear Mr. Mooney: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a h iday or weekend. A person may not appeal a Commission decision to Superior urt unless rehearing has been requested. sL "'\. ~ ì--CZ' tJ . No Chai DATED this ~ day of March, 2005 Enc!. 8Ci~N~ED, MAI~ (} 2 2005 ) ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocóPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 February 25, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 !--r"8i"ì I!ìì . ~- C'~ ,¿; it) Subject: Application for Sundry Approval for Bergschrund #2A (APD # 196-033) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval to plug and abandon the well Bergschrund #2A.. If you have any questions regarding this matter, please contact me at 263-4574 or Guy Schwartz at 265-6958. Sincerely, 4J h1~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells M M/skad 0 0 I ';'~\ r :,\ ì ,I (,\ (\ i t:q !,IJ ( ". STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL FE'S 2 t; lOG5 20 MC 25.280 . 0 Suspend 0 Operation Shutdown 0 Perforate m~ If.l~'iM\F~ 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time E*tenslioHi,: ::,EJj; 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 50-103-20232-01 9. Well Name and Number: Bergschrund #2A 10. Field/Pool(s): Colville River Field 1 Alpine Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7490' Burst Plug Integrity ~ BOP Test 0 Mechanical Integrity Test 0 Location Clearance ~ Other: ~~~r\'S~C-~\- \-o~~~~, . ~'~\-\-I"\', ~"::. ~.\\~\..\\~"> ~\\~,~ -\\a\)~,\e~<rJ~Q-a.ç\(Jt'-'~\\\JCJ\(. ,\)\ C,~ /it " Approved b:;0Y,-- ../' Form 10-403 Revised 12/2003 RBDMS 8Ft MAR 0 1 2005 BY ORDER OF ?.1P LO( THE COMMISSION Da~:z i~¿~e ) ) 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): 43' RKB 4. Current Well Class: Development Stratigraphic 0 0 Exploratory 0 Service 0 8. Property Designation: ADL 372095 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 7896' 7508' 7453' Length Size Casing MD TVD 110' 110' 1827' 1827' 7866' 7478' Conductor Surface 70' 1787' 16" 9-5/8" Production 7826' 7" Perforation Depth MD (ft): 7368'-7454' Packers and SSSV Type: 4.5" x 7" Baker FAB-1 packer @ no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Perforation Depth TVD (ft): 6987'-7072' Tubing Size: 3.5" Packers and SSSV MD (ft) 7165' March 11 2005 Date: 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Contact: Title: Signature ~~o~~ Phone Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 0 r-~ Ìi i'-" i t~'\ ~ L) ¡ ¡ L - COMMISSIONER INSTRUCTIONS ON REVERSE 4-- dfd~ ~,'" ql\I''''~:,i'tt:!~;:~I{WI.:: ¡ 0 ,d.¡¡s.nnular UISp. Other 0 5. Permit to Drill Number: 196-033 6. API Number: Collapse Tubing Grade: L-80 Tubing MD (ft): 7177' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Mike Mooney @ 263-4574 Wells Group Team Leader Date 2/Z5/65 Sundry Number: .s(;)S--O~~ ) ) Bergschrund 2A Plug and Abandon 10-403 Summary Well history: The Bergschrund 2A (Berg 2A) well was drilled as an exploration well in April 1996. Permanent gauges were later installed to utilize Berg 2A as an observation well. As Alpine development continued, injectors near the Berg 2A well were brought online (see map below). As a result, the Berg 2A downhole reservoir pressure and temperature is influenced by nearby injectors C01-26 and C01-03. As this well's surface location is far from the C01 pad, the instrumentation is costly to maintain in the arctic environment for minimal benefit in data gathering. In addition, HSE risks arise in the spring when the well is in the path of ice thaw and drift. Maintenance costs and operational risks will be eliminated by plugging and abandoning this well. Reservoir pressure in the Berg 2A area will be monitored using Pool Rules approved methods (static bottom hole and surface fall-off pressure measurements. -_\ "1~k~ Ð~-" ~\~c;.~\<é:.CJ.,Sc. P & A summar"Y) 'ß'-~ ,",o...~ ~ a..~ \k>r\. \-{ 1. Notify BLM/AOGCC 48hrs in advance of all pressure testing and suspension operations. 2. Pull permanent gauge completion. 3. Pressure test lA, OA (OA cemented already) and perform injectivity test on the formation with 9.4 ppg NaCI brine. 4. Pull lower GLM dummy at 7085' , tag TO and circulate 9.4 ppg brine down tubing and up IA. (Circulate all diesel out of tubing and annulus). ~ - - 5. RU CTU and pump 26 bbls cement for lower plug. Hesitate squeeze in cement to cover perfs then open 3 %" x 7" annulus and displace 8 bbls of cement up the IA. (this leaves -. about 300' of cement in the IA and tbg above the GLM) (;) Rig up Eline and tag cement plug after 24 hrs . Pr<?ssure test to 1500 psi for 30min. (put on chart). ~\o.~~ :t:.,-s>\,<<-,:\Ð\ 7. Set plug at 1000' in 3 %' tubing. Perf through tubing only. OA has been cemented already. 8. Establish circulation from tubing up the IA. 9. Circulate cement down tubing taking returns up IA until cement is at surface. Shut -in IA. //:~xcavate wellhead and cut all casing strings 3' below original ground level. Add cement ~s need to bring cement in all strings to surface. Weld on cover plate and backfill. coc"h\- r"S~~\\,\\or--\o ~(~,t'--~ ~\u:-\e ') ) Bergschrund 2A Plug and Abandon 10-403 Summary Well history: The Bergschrund 2A (Berg 2A) well was drilled as an exploration well in April 96. Permanent gauges were later installed to utilize Berg 2A as an observation well. As Alpi e development continued, injectors near the Berg 2A well were brought online (see map b ow). As a result, the Berg 2A downhole reservoir pressure and temperature is influenced by n rby injectors CD1-26 and CD1-03. As this well's surface location is far from the CD1 pad, th instrumentation is costly to maintain in the arctic environment for minimal benefit in data gathe ng. In addition, HSE risks arise in the spring when the well is in the path of ice thaw and drift. Maintenance costs and operational risks will be eliminated by plugging and abandoning t s well. Reservoir pressure in the Berg 2A area will be monitored using Pool Rules approved .ethods (sta, ti~bottomhole". and surface fall-off pressure measurements. C\ ..... ;) l . S\.J ~X'-~~ I;)-.~ - (S.\&~ ~\-1.~ .~ ~<èc..Sk:: P & A summary, ß\.-k ~.~ ú..~'~ 't\A,,-t 1. Notify BLM/AOGCC 48hrs in advance 0 II pressure testing an~ suspension operations. 2. Pull permanent gauge completion. 3. Pressure test lA, OA (OA cement already) and perform injectivity test on the formation with 9.4 ppg NaCI brine. 4. Pull lower GLM dummy at 7 5', tag TD and circulate 9.4 ppg brine down tubing and up IA. 5. RU CTU and pump 26 tbls cement for lower plug. Hesitate squeeze in cement to cover perfs then open 3~" 7" annulus and displace 8 bbls of cement up the IA. (this leaves ;;;~'''''\.bout 300' of ceme in the IA and tbg above the GLM) ~i9 up Eline and ag cement plug after 24 hrs . Press~re test to 150Q psi for 30min. (put on chart). <:..o1\.~~*~:IJ~~~~)\ 7. Set plug at 00' in 3 ~'tubing. Perf through tubing only. OA has been cemented already. 8. Establ~circulation from tubing up the IA. "..9. Circy(ate cement down tubing taking returns up IA until cement is at surface. Shut -in IA. r~~ EI~avate wellhead and cut all casing strings 3' below original ground level. Add cement ~is need to bring cement in all strings to surface. Weld on cover plate and backfill. ill ~~~\- I~c~,'~~o, -\0 ~fu~ v.\0e- , í , ,PS PHilliPS Alaska, Inc. À subsîdiary of PHILLIPS PETROLEUM COMPANY r - 1_---'--1: ~~~~SCH_~~_~9~~~()~320L__~___Well"!)r:!e'I_EXPLO~-------_.H____~~9~_@J"_~9~- ---- --_sssv T~r:!e: '.!":!!P2!~ - - _____Qr!9 ýomr:!letion:- 4/5/9~ ---- --'___~~9_1~@.I~?:.~~~g-@ 78~?:__- , Annular Fluid: Last WIO 4/7101 Rev Reason: Set permanent PANEX gauges by ImO Reference Log:--==------------____----=_RefJoQ Dätë: _____Last Update: 5/21.9.1,___--------_.- ------- Last Tag: ]4~:}__,_---------------_--.-IQ- 7896 ftKB ----,------------------,-------- ._-~~l.~ Date: 3/3,1/0 L__,___--------_ßtta.x Hole- Angle: _,g,ê..9~g_@.§44Q___,_._----,------------------------- .CaslngStdng -ALL --.---,--.-. - .---------,-.------- Description -- Size_____~- Bottom ---_!YJL_-,,-,~J_- Grade Thread CONDUCTOR 16.000 0 110 110 62.58 B SURF CASING 9.625 0 1827 1827 53.50 L-80 PROD CASING 7.000 ----------Õ----- 7866 --74-78--26~OÕ-------T=ao------Bfc'----- Tubiñg~ïrrñ~-TUBfNG -----------, -,,--- -----------,_._--'-------_._-"-'-'---'-'--- c-_- :.~~~ l T~P -r---Bf~~ml--~~---r-- ~r--1 G~_~~e 1-- EU~~~~~OD------ ; PeriorationsSummary Interval I TVD I zon-ë----I StatusT'-F[JSPFI-,---p~te_-I-_lYpe-l-------- Commeni-~-=-~ 7368 - 7454----- 6987 - 7072 - 1-- 86 1 4 4/8/96 IPERF 4 spf (?) - unconfirmed Gas Lift MandrelsNalves St MD TVD Man Man V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Ty~____---------_._-------------,----------------- Run Cmnt 1 7085 6710 CAMCO MMM CAMCO DMY 1.5 TG 0.000 0 4/4/96 [-Óther-'(pìugS~-j~~~~ij~~QEWËIRY------'-"------'-"--,----,--------------,-'_._-----'-'---'-----"--'----'---,-----,-----,----,--,-----------,.. _Depth TVD Ty~____- Description ID 7046 6672 - NIP Otis 'X' Landing..l':l..1P.~ - 2.813 __.113..1.- 675!L_- NIP __9tis 'XN' Landin9l!Jpple - set permanent PANEX 9..~ge 4/7/01 -------____-1.750- 7165 6788 PKR Baker 'FAB-1' Packer, w/10' GBH-22 Locator Seal: 7164 -7174' 4.000 Fish - FISH Depth I -.--"Cescriptlon 7490 FISH General Notes Date Note 4/15/96 Cut Tubing Tail off at 7177' MD w/mechanical cutter. ----..---- 4/2/01 Tubing & IA loaded with 10.3 ppg brine with 2000' diesel cap -----,------- -- 4/7/01.. Set permanent PANEX g~¡¿g~ assen:!þ"!y'_~!'~~-~~~jæ_communication!9_~!face. ---_____.n______----- CONDUCTOR (0-110, OD:16,000, Wt:62.58) TUBING (0-7177, OD:3,500, 10:2,992) SURF CASING (0-1827, 00:9,625, Wt:53,50) NIP (7046-7047, 00:3,500) Gas Lift landrel/Oummy Valve 1 (7085-7086, 00:6,018) NIP (7131-7132, 00:3.500) PKR (7165-7166, 00:6,059) PROO CASING (0-7866, 00:7.000, Wt:26,00) Perf (7368-7454) FISH (7490-7510, 00:3,500) -- - -.-..-"- ---.,-----. .- . ... ........... .. .1.....- ) ) BERGSCHRUND2A =l;:~~uns ~_nd cut off T§I,~.flr:!..e~~;~:~~knOWn)____~~~=~=-'-'='~~=-~-=-= ---~._. --'-------- -'.- '-"'-"---,,~,-,,-,-~- --.-_u_.- . -_.---------_._-------------------~_...,---_.,--"-_._-----.-------------..'- .. -- -- ---.-..---..--".' ~-- - RE: Alpine Well Abandonments ) ) Subject: RE: Alpine Well Abandonments From: "Schwartz, Guy L" <Guy.L.Schwartz@conocophillips.com> Date: Mon, 28 Feb 2005 14:05:23 -0600 To: Thomas Maunder <tom - maunder@admin.state.ak.us> Tom, AS per your request Alpine IB now reflects the fact that the OA is cemented already. Step 4 takes care of the diesel removal issue. resending the summary pages for you. I am Thanks for the help, Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 9~~.Y...:".!...:",.§"s:.~~~,9.:F.~,~.~?q,,?p':.?..~g.p"þ',~,,~..!.~.P'..~...=""q,9.!~ -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent : Monday, February"'."2"S"':"'"''''2''õ'ö'S'''''''îo''';'''3'''9'''''''ÞJvi'''''''''.."............"",,,,...,,...........................,.................,,,,,.,,,..,,..,,.,,,..,,. To: Schwartz, Guy L Subject: Re: Alpine Well Abandonments Guy, Have you been able to resolve the questions on these wells?? Torn Thomas Maunder wrote: Guy, I left you a message regarding the Alpine lB. According to what I can see in the well file, the 13-3/8" x 7" annulus shows to already be cemented. On both wells your drawings indicate that the freeze protection goes down to 2000'. You are planning to plug from 1000' to surface which appears acceptable. In your procedure, you need to provide for the removal of the diesel in the tubing and annulus. This would appear to be fairly simple to circulate out (of the annulus) or bullhead away as you do your injectivity test down the tubing. Have a look at these points and get back to me. Tom Maunder, PE AOGCC > Alpine IB P & A summary.doc Content-Description: Alpine 1B P & A summary. doc Content-Type: application/msword Content-Encoding: base64 Bergschrund 2A P & A summ d Content-Description: Bergschrund 2A P & A ary. oc summary. doc Content-Type. I.. . app lcatIon/msword 1~2 2/28/2005 11: 13 AM PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Erwin Phone (907) 265-1478 Fax: (907) 265-6224 September 4, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations Bergschrund #2A(1,96,033~1:399-038) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the well conversion on the well Bergschrund #2A. If there are any questions, please contact me at 265-1478. Sincerely, M. Erwin Alpine Operations Engineer Alpine Engineering ME/skad ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown_ Pull tubing _ 2. Name of Operator: 15. Phillips Alaska, Inc. I 3. Address: . P.O. Box 100360 Anchorage, AK 99510-0360 Stimulate__ Alter casing _ Type of Well: Development _. Exploratory ~. Stratagrapic ~ Service X. Plugging _ Perf(jj'ate Repair well _ Other¥_Well ~onversion 6. Datum of elavation (DF or KB feet): RKB 42 ft above SL 7. Unit or Property: Colville River Unit 4. Location of well at surface: 964' FNL, 1370' FWL, Sec. 9, T11 N, R5E, UN At top of productive interval: 458' FSL 58' FWL, Sec. 4, T11 N, R5E, UN At effective depth: At total depth: 530' FSL, 3' FWL, Sec. 4, T11 N, R5E, UN 12. Present well condition summary 8. Well number: Bergschrund #2A 9. Permit number/approval number: 96-33 / 399-038 10. APl number: 50-103-20232-01 11. Field/Pool: Colville River Field / Alpine Oil Pool Total Depth: measured true vertical 7896 feet Plugs (measured) 7508 feet Effective Depti measured true vertical 7774 feet Junk (measured) feet Casing Length Size Conductor 70' 16" Surface 1787' 9-5/8" Production 7826' 7" Cemented 350 sx AS 1 335 sx AS 1 & 550 sx AS III 270 sx Class G Measured depth 110' 1827' 7866' True vertical depth 110' 1827' 7478' Liner Perforation Depth measured 7368' - 7454' (open hole' true vertical 6987' - 7072' (open hole' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 EUE Mod @ 7164' ME Packers and SSSV (type and measured depth) 4-1/2" x 7" Baker FAB-1 Packer @ 7165' ME: SEP Alaska Oil & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured~ N/A Intervals treated (measured) 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure N/A N/A Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil _ Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sign.ed//~'fV~,,~~~ ~ Title'. Alpine Operations Engineer Questions? Call Michael Erwin 265-1478 Prepared by Sharon Allsup-Drake SUBMIT IN DUPLICATE - 0RIGIN. A,L Date Comment BERG #2A Event History 04/07/00 04/08/00 04/09/00 04/14/00 04/15/00 04/16/00 REMOVED BPV & VR PLUGS AND PREPPED FOR ADDITIONAL WELLHEAD VALVING INSTALLED ADDITIONAL WELLHEAD VALVING AND PT'D. PRESSURED UP IA TO 2000 PSI. HELD GOOD FOR 30 MINS. VOLUME REQUIRED FOR IA TEST 1.2 BBLS. PULL 2.81" XXN PLUG @ 7131' RKB & TAG BOTTOM @ 7231' RKB. RETRIEVED SAMPLE OF CEMENT. WAIT ON TANKS AND FLUID - FLANGE UP FOR SMALL WELLHEAD - PRESSURE TEST TOOLS AND HARD LINE. UNDERREAM HARD CEMENT FROM 7909' CTM TO 7987' CTM - RAN OUT OF TANK ROOM - UNABLE TO GET STALL - DROP BALL TOP OPEN CIRC SUB-FREEZE PROTECT AND SHUT DOWN FOR NIGHT. UNDERREAM CEMENT FROM 7288' TO 7291' - CHANGEOUT BHA TO 2.70" MILL AND MOTOR - DRILLED THROUGH CAP AND COMPLETE FILL CLEANOUT TO 7490' (7510' MD) - READY FOR SLICKLINE. 04/20/00 LOADED TBG W/45 BBLS OF 10.9# BRINE & 17 BBL DIESEL FREEZE PROTECTION CAP. SET 2.81 XXN W/PANEX EMR'S TO STAY IN WELL FOR 1 YEAR. PT'D TBG & IA (BOTH TESTED GOOD) 04/21/00 INSTALLED BPV IN TBG HANGER, VR PLUG IN THE IA, & VR PLUG IN THE CA. CHAINED AND LOCKED ALL VALVE HANDLES. RE-SET WELLHOUSE. 03/24/01 REMOVED 3" ISA BPV FROM THE HANGER & 2" VR PLUGS FROM BOTH THE IA AND CA. 03/25/01 BAIL SALT FROM 7112' WLM TO 7121 WLM. ABLE TO LATCH PLUG BUT UNABLE TO PULL. STILL HAS FILL INSIDE OF THE PLUG. JOB IN PROGRESS. 03/26/01 BAIL SALT & PIPE SCALE OFF PLUG AT 7121' WLM (7131' RKB) 03/27/01 BAIL & PULL 2.813" XXN PLUG W/PANEX BHP GAUGES FROM 7121' WLM (7131' RKB) RECOVERED EVERYTHING - JOB COMPLETE - TAKE PANEX'S TO Y PAD SHOP 03/31/01 LOGGED RST SIGMA FROM TD AT 7453 FT MD (1' FILL) TO 7070 FT MD - 3 PASSES AT 30 FPM EACH. LOGGED RST CARBON OXYGEN FROM TD TO 7150 FT MD AT 200 FPH. RECORDED TEMP & PRESSURE IN SIGMA AND C/O. SBHP= 3050 PSI. --~,~-~-?-(~- ................ ~i~i~..?~..i~.~.~.5i.~.~.~.i...i~i5~.~q..:fi~i~.:~..§.~.E.§:i.§~.~.~.~..~.~..~?.~.~.~.~Y.~ ~-~-~-~-~-~--i~--~-~--~-i-~ ........ PT TBG TO 2000 PSI. SET DEBRIS CATCHER ON ~N PLUG. PULL 1-1/2" DGLV FROM GLM AT 7085'. 04/0~01 STAND BY WHILE LRS DISP~CES W/10.3~ BRINE W/2000' DIESEL CAP. SET 1-1/2" DGLV AT 7069' WLM PT TO 2000 PSI HELD PERFECT BOTH SIDES PULL DEBRIS CATCHER & DUMP BAIL 2-1/2 GALLONS OF FLUORINERT ON TOP OF PLUG AT 7129' WLM - READY FOR ELINE. 04/04/01 STABBED INTO GAUGE COUPLING W/STINGER NUMEROUS TIMES. WAS NOT ABLE TO COMMUNICATE WITH GAUGE AFTER APPARENT COUPLING PROBLEM. JOB IN PROGRESS. 04/05/01 PULL DGLV, CIRCULATE BRINE INTO IA, RERUN DGLV, PT IA, PULL X-LOCWGAUGES, TEST GAUGE, RE-RUN GAUGE, PT TBG, RUN CATCHER SUB. JOB IN PROGRESS. 04/06/01 PULL DGLV, CIRC 10.3ff BRINE BACK INTO TBG S IA W/DIESEL CAP TO 2000' ON BOTH. SET DGLV. PT'D TBG & IA TO 2000 PSI WLM PULL CATCHER DUMP FLOURINERT ON TOP OF PLUG/GAUGE AT 7131' RKB. READY FOR ~L. -b-~76'~'6~ ............... ~~i~5~iV~6~f~i~.~.~.~~.i~.~7~~.~.~i.~.~i~L.~:~.~.~ ..... COMMUNICATIONS THROUGH THE FMC HANGER AT SURFACE- SYSTEMS ALL WORKING. BHP AT GAUGE= 2795 PSI. BHT AT GAUGE= 151 F. Page 1 of 1 9/7/01 ARCO Alaska, in ~ost Cifice ~cx !:i03~6 April 21, 1999 Commissioner Robert Christenson Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Application for Alpine Observation Wells Colville River Unit, North Slope Basin Dear Mr. Christenson: Please by advised that ARCO Alaska, Inc. will be delayed in completion of its proposed conversion of two wells in the Colville River Field to observation wells. The sundries as approved reported start-up of the project as March 15, 1999. Due to various constraints, this work has been postponed until the ice road season of 1999-2000, with a revised commencement date of February 15, 2000. ARCO Alaska, Inc received the following sundry approvals dated March 12, 1999, for conversion of two wells to observation service in the Colville River Field. Permit No. Sundry_ Approval Alpine lB 95-20 399-035 Bergschrund 2A 96-33 399-038 Inquiries regarding clarification may be directed to either Scott Redman or myself at this office. Sincerely, ./),I;I . - ? ...., , ... _ / Michael D. Erwin Alpine Operations Engineer Sundry Revision Page 2 CC: Mr. Kenneth A. Boyd, Director Alaska Department of Natural Resources Division of Oil & Gas 3601 C Street, Suite 1380 Anchorage, Alaska 99503-5948 Ms. Teresa Imm, Resource Development Manager Arctic Slope Regional Corporation 301 Arctic Slope Avenue, Suite 300 Anchorage, Alaska 99518-3035 Mr. Joe Nukapigak, President Kuukpik Corporation PO Box 187 Nuiqsut, Alaska 99789-0187 Todd Liebel Anadarko Petroleum Corporation PO Box 1330 Houston, Texas 77251-1330 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS · Type of request: Abandon _ Suspend _ Operation Shutdown _ Reenter suspended well _X_ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program Pull tubing Variance Perforate Olher _ 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development_ RKB 42 ft above SL 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360, Anchorage, Ak, 99510-0360 SlTatagraplc_ Colville River Unit Service X 4. Location of well at surface: 8. Well number: Bergschrund #2A 964' FNL & 1370' FWL, Sec 9, T11 N, R5E, UM At top of productive interval: 9. Permit number: 96-33 458' FSL & 58' FWL of Sec 4, T11 N, R5E, UM At effective depth: 10. APl number: 50-103-20232-01 At total depth: 11. Field/Pool: Colville River Field 530' FSL & 3' FWL of Sec 4, T11 N, R5E, UM Alpine Oil Pool 12. Present well condition summary Total Depth: measured 7896 feet Plugs (measured) true vertical 7508 feet Effective Depth: measured 7774 feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Conductor 70 feet 16" 62.58# Gr 'B' 350 sx ASI 110 feet 110 feet Surface 1787 feet 9-5/8" 53.5# L-80 335 sx ASI 1827 feet 1827 feet 550 sx ASIII Production 7826 feet 7" 26# L-80 270 sx Class G 7866 feet 7478 feet ORIGINAL Perforation Depth measured 7368 - 7454' (open hole) , : , . ! .,,, , . true vertical 6987 - 7072 (open hole) Tubing (size, grade, and measured depth) 3-1/2", 9.3 ppf, L-80 EUE-Mod @ 7,164' MD Packers and SSSV (type and measured depth) 4-1/2"x 7" Baker FAB-1 Packer @ 7,165' MD 13. Allachments Description summan/of proposal _X Detailed operations program _ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: March 15, 1999 Oil_ Gas_ Suspended_ 16. If proposal was verbally approved Name of approver Date approved Service Observation 17. I hereby certify that the forgoing is true and correct to the best of my knowledge. Signed Title: Staff Operations Engineer Date C FOR COMMISSION USE ONLY Conditions of approval: Notify Comission so representitive may witness JApprova. No. Plug integrety_ BOP test / Location clearance _ _ Mechanical integrety test_ Subsequent form required 10-~ ORIGINAL SIGNED BY Approved by order of the Commissioner R0b~rl' N ~hH~f..,-,~,-,,., Com.m. issioner Date '"" Form 10-403 Rev 06/15/88 od600P~ SUBMIT IN TRIPLICATE Conversion Procedure Colville River Field Bergschrund #2A Conversion operations will commence following ice road construction on or about March 15, 1999. Completion is expected on or about 4/1/98. This procedure is designed to convert a "Suspended" for use as an "Observation" well. This provides invaluable full-time reservoir surveillance data. The well will be useful in monitoring reservoir pressures, as well as interference or pulse test data in lieu of gathering similar data in the production and injection wells. The pressure gauges will be equipped for surface readout with data transmitted to the Field Control Office. 1. Slickline drift and tag cement plug below packer. 2. Drill out the cement plugs from 7220'MD to 7304'MD with CTU. 3. Wash out the sand plugs, exposing the perfs from 7368'MD to 7454'MD. 4. Circulate clean kill weight brine and freeze protect the tubing. 5. Secure well with a "PX" plug set in the "XN" profile at 7131'MD. 6. Install the pressure and temperature gauges in the "PX" plug. 7. Test the gauges. Pressure test the tubing. 8. Leave the wellhead secured, with 100 psi on tree. 9. Move off equipment. 10. Clean location. - --Colville River Field Bergschrund #2A APl #50-103-20232-01 964' FNL, 1370' FWL S/9 T/111N R5E 16" 62.58# Gr. "B" Conductor @ 110' MD 16" cemented to surface w/350 sx AS1 3-1/8" FMC Gen IV tubing hanger with 3" ISA BPV (BPV/VR plugs set) diesel to 1000' in ~J tbg & annulus KB=42' Pool 6 Spud 2/O8/96 Cement 9-5/8" x 16" 335 sx Arctic Set 1 450 sx Arctic Set 3 Pluc, ,~,.,t in .XN to secure well 4.1'i 8/96 9-5/8" 53.5 ppf L-80 Surface Casing @ 1827' MD/TVD I 7 x 9-5/8" Annulus - cemented with 34 bbl ASIII lead, 12 bbl ASI tail I I 3-1/2" 9.3 ppf L-80 EUE 8rd MOD tbg 10.6 ppg brine in tubing · 10.1 ppg brine in annulus Otis 'X' LN @ 7,046' MD (2.813" ID) Camco 1-1/2" MMM GLM w/TG latch 1 jt below 'X' LN @ 7,085' MD Dummied off. Otis 'XN' LN @ 7,131' MD (2.750" ID) EOT @ 7177' MD Cement Plug 7,220- 7,304' MD Sand Plug @ 7866' MD TD 7,896 MD 7,5O8 TVD Baker GBH-22 Locator Seal Ass'by (10' long) @ 7164'MD, Baker FAB-1 Packer (4.00" ID) @ 7165' RKB Tail pipe includes; 1. 80-40 seal bore extension @ 7166' MD 2. 4-3/4" Acme x4-1/2" EUEXO @ 7175' MD 3. 4-1/2" 5' 12.6# L-80 EUE 8rd Mod PJ @ 7176' MD cut-off at 7177' with CT mechanical cutter Perf 7368'-7454' MD, 6987'-7072' TVD TOF 7,510' MD tagged4/16/96 , Perf guns and tailpipe PBTD 7,774 MD, 7478' TVD Updated Colville River Field Bergschrund #2A APl #50-103-20232-01 964' FNL, 1370' FWL S/9 T/111N R5E 1 6" 62.58# Gr. "B" Conductor @ 110' MD 1 6" cemented to surface w/350 sx AS1 Cement 9-5/8" x 16" 335 sx Arctic Set 1 450 sx Arctic Set 3 XN Plug, PX Housing o550 SRO gauges 3-1/8" FMC Gen IV tubing hanger with 3" ISA BPV (BPV/VR plugs set) diesel to 1000' in tbg & annulus ~Proposed Observation) Completion KB=42' Pool 6 Spud 2/O8/96 9-5/8" 53.5 ppf L-80 Surface Casing @ 1827' MD/TVD 7 x 9-5/8" Annulus - cemented with 34 bbl ASlII lead, 12 bbl ASI tail 3-1/2" 9.3 ppf L-80 EUE 8rd MOD tbg 7/32" Electric Line from gauges to surface 10.6 ppg brine in tubing 10.1 ppg brine in annulus Otis 'X' LN @ 7,046' MD (2.813" ID) Camco 1-1/2" MMM GLM w/TG latch 1 jt below 'X' LN @ 7,085' MD Dummied off. EOT @ 7177' MD OFill @ +/-7550' 7" 26 Ib/ft L-80 BTC @ 7866' MD TD 7,896' MD 7,5O8 TVD Otis 'XN' LN @ 7,131' MD (2.750" ID) Baker GBH-22 Locator Seal Ass'by (10' long) @ 7164'MD, Baker FAB-1 Packer (4.00" ID) @ 7165' RKB Tail pipe includes; 1. 80-40 seal bore extension @ 7166' MD 2. 4-3/4" Acme x4-1/2" EUEXO @ 7175' MD 3.4-1/2" 5' 12.6# L-80 EUE 8rd Mod PJ @ 7176' MD cut-off at 7177' with CT mechanical cutter : Perf 7368'-7454' MD, 6987'-7072' TVD PBTD 7,774 MD, 7478' TVD TOF 7,510' MD tagged4/16/96 ! Perf guns and tailpipe Updated 2/22/99 PERMIT DATA 96-033 SWC RPT :~_'- ;---.'~-, I -' o V 96-033 DIR SURV 96-033 7265 96-033 CDN - MD 96-033 CDN - TVD 96-033 CDR - MD 96-033 CDR - TVD f.~GEOQUEST ~RtCDN SEPIA ~¢,~SEPiA ~)~_ 96-033 96-033 96-033 96-033 MECH SWC ~EPZA 3 t 13 f96 '~) )~ - ? END OF WELL RPT ~EPOCH SRFCE WLL TEST ~LIBURTON /4./7,/96-L~/13/96 PRESS BLDUP DATA~;"'~7063-7065 DSK 96-033 PROD PROFILE ~280-7~90 10-b07 OR,~COMPLETION DATE ~//17/¢~, / Page: 1 Date: 0~/30/97 RUN DATE_RECVD 05/13/96 0-5/28/96 06/03/96 06/03/96~ 06/03/96 06/03/96 06/03/96 06/03/96 06/03/96 06/03/96 07/23/96 07/23/96 07/23/96 / Are Was Ar'e Well ~/zff/%/ DAILY WELL OPS dry dii: samp es required? no And received? yes the well cored? ~'-~no Analysis & description r'ece~ red? well tests r'equir'ed? ~no Received? ~_~L~_no ~s in compliance ~ al COMMENTS no no TO: AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 ARCO Alaska, Inc. AflanticRichfieldCompany FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE: May 10, 1996 Transmitted herwith is the followinq data: REPORTS: Alpine 3 "BASIC ROCK PROPERTIES" - Final Report as Displayed by Core Laboratories c~ (~ ~ 0 ~ ~'/Bergschrund 2A "BASIC ROCK PROPERTIES" - Final Report as Displayed by Core Laboratories Nanuk 1 "BASIC ROCK PROPERTIES" - Final Report as Displayed by Core Laboratories Temptation 1 "BASIC ROCK PROPERTIES" - Final Report_ as Displayed by Core Laboratories If you have any questions please call me at (907) 265-6240. RETURN SIGNED COPY TO: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-146~ 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Received by: DATE: M/~Y' 1 ;~ 1996 Alaska Oil & Gas Cons. Commission Approved for transmittal by: -Ma'~a;~, No rt hF'AIMa; kHaOEnCttCottn TO: AOGCC Attn.: Mr. Robert P Crandali 3001 Porcupine Dr Anchorage Alaska 99501 ARCO Alaska, Inc. AflanticRichfieldCompany FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE' April 18, 1996 Transmitted herwith is the followinq data: SQUEEZE PERF & CEMENT RETAINER RECORD - 12-MAR-96 TEMPERATURE LOG - TEMP / PRESS / GR / CCL - MARCH 28, 1996 DIGITAL DATA: Neve 1 v'f 6" Open Reel Tape-LDWG Format-"Open Hole Edit" CDR CDN DSI with paper listing copy ~-'1/3.5 Floppy-Ascii Format-Directional Data ( Meas Depth, Devi, Hazi) REPORTS: ~/Alpine 3 BASIC ROCK PROPERTIES - FINAL REPORT containing 1 3.5 floppy disk with 97076.XLS files If you have any questions please call me at (907) 265-6240. Kelli RETURN SIGNED COPY TO: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Received by: DATE: 19'96 AJaska Oii& G~ Cons. Comm~ion Anchorage ~oved for transmittal by: F.M. Ho~ej/cutt Manager, North Alaska F,,x151oration TO: AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 ARCO Alaska, Inc. · AflanfieRiclffieldCompany DATE: April 18, 1996 FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Transmitted herwith is the followinq data: Enclosed is the following data: LOGS: 1 Sepia Copy Displayed by EPOCH: Bergschrund 2A Formation Log 1" = 50' (2000' to 7896') i'~"t] 1 Biueline Copy Displayed by EPOCH: Bergschrund 2A Formation Log 1" = 50' (2000' to 7896') 1 Sepia Copy Displayed by Schlumberger: Neve 1 CDN FINAL PRINT CEMENT BOND LOG CEMENT EVALUATION COMPENSATED NEUTRON LOG (EPITHERMAL & THERMAL) RUNS I & 2 PACKAGE SETTING RECORD (BAKER FB -1/TCP ASSEMBLY)- 14-MAR-1996 SQUEEZE PERF & CEMENT RETAINER RECORD - 12-MAR-96 TEMPERATURE LOG - TEMP / PRESS / GR / CCL - MARCH 28, 1996 1 Blueline Copy Displayed by Schlumberger: Neve 1 CDN FINAL PRINT ., CEMENT BOND LOG CEMENT EVALUATION COMPENSATED NEUTRON LOG (EPITHERMAL & THERMAL) RUNS I & 2 PACKAGE SETTING RECORD (BAKER FB -1/'rcP ASSEMBLY) - 14-MAR-1996 ~ ARCO Exploration Company r-~ ARCO Oil and Gas Company {} F~ ARCO Alaska, Inc.{} Record Of Shipment Of Confidential Information JDistrict: Alaska From: ARCO Alaska, Inc. AOGCC Attn.- Mr. Robert P Crandall P.O. Box 100360 3001 Porcupine Dr Anchorage, Alaska 99510-0360 Anchorage Alaska 99501 Attn.: Kelli Thibodeau (907)265-6240 (X) Enclosed ( )Under separate cover ( )Via Alpine 3 / Bergschrund 2 · /Bergschrund 2A Well Summary Report as Displayed Well Summary Report as Displayed Well Summary Report as Displayed by ARCO by ARCO by ARCO -~ Nanuk 1 ~ Neve I -~Temptation 1 "'"Temptation lA Sidewall Core Description Run I as Displayed by ARCO Sidewall Core Description Run 2 as Displayed by ARCO Well Summary Report as Displayed by ARCO Sidewall Core Description - Rotary as Displayed by ARCO Core Report as Displayed by ARCO Well Summary Report as Displayed by ARCO Core Chip Description as Displayed by ARCO Core Chip Description as Displayed by ARCO Well Summary Report as Displayed by ARCO Well Summary Report as Displayed by ARCO Note - PleAse verify and acknowledge Signed~ 0J~ receipt, by signin9 and returni Receivech~b~/ (~ Remarks: Please Note that all included information is CONRDENTIAL. n~l a copy of this transmittal. Date 08/16/96 Date R[CEIVED Alaska Oil & Gas Cons. Commission Anchorage TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 2, 1996 Land Department, ATO 1470 David Sutter, Manager ARCO Alaska, Inc. P O Box 100360 Anchorage, Alaska 99510-0360 Re: Site Inspection, Two North Slope Suspended Wells. Dear Mr. Sutter: On July 10, 1996 our representative, John Spaulding, accompanied your Larry Brown on site inspections of two North Slope locations. He recommended continued suspension for the following' Well Name PTD No. Alpine #lB 95-020 Bergschrund #2A 96-033 Continued suspension is hereby approved for the two above listed ARCO North Slope exploratory wells as per 20 AAC 25.110(e). David W. Jc Chairman cc: Blair WondzeI1 siar2ns TO: AK~O Alaska, Inc. AtlanticRichfieldCompany AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 DATE: July 22, 1996 FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Transmitted herwith is the followinq data: REPORTS as Displaye by Halliburton- Surface Well Test February-(contains 3.5" floppy with digital data) q~'--0~-0 Alpine lB ~'~ Bergschrund 2~ *,~,~ Neve 1 if you have any questions comments Please call me at (907) 265-6240 or Email me ian kat @ expL aai. arco. com. RETURN SIGNED COPY TO: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Received by:, DATE: RECEIVED ,JUL 2 3 1996 2of2 Approved for transmittal by: //% ' "; i, I~ ~, ') ~"-: F. M. Honeycutt Mana~or, North Alaska fixplOration .~../ TO' AOGCC Attn.' Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 ARCO Alaska, Inc. AtlanticRichfi¢ldCompany FROM- ARCO Alaska, Inc. Attn.' Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE: June 2, 1996 Transmitted herwith is the followinq data: Enclosed is the following data: LOGS: 1 Sepia Copy Displayed by Schlumberger: Bergschrund 2A ,~'DN FINAL PRINT L..CDN FINAL PRINT TRUE VERTICLE DEPTH (...~CDR FINAL PRINT ~.--~C,,~IR FINAL PRINT TRUE VERTICLE DEPTH ~ECHANICAL SIDEWALL CORING RECORD 13 MARCH 1996 I Sepia Copy Displayed by Schlumberger: Temptation lA CDN FINAL PRINT CDN FINAL PRINT TRUE VERTICLE DEPTH CDR FINAL PRINT CDR FINAL PRINT TRUE VERTICLE DEPTH 1 Blueline Copy Displayed by Schlumberqer: Bergschrund 2A ,..~DN FINAL PRINT C,~ CDN FINAL PRINT TRUE VERTICLE DEPTH ..,,~DR FINAL PRINT ~.,,~DR FINAL PRINT TRUE VERTlCLE DEPTH "'~VIECHANICAL SIDEWALL CORING RECORD 13 MARCH 1996 I Blueline Copy Displayed by Schlumberger: Temptation lA CDN FINAL PRINT CDN FINAL PRINT TRUE VERTICLE DEPTH CDR FINAL PRINT CDR FINAL PRINT TRUE VERTICLE DEPTH TO: AOGCC Attn.: Mr. Robert P Crandail 3001 Porcupine Dr Anchorage Alaska 99501 ARCO Alaska, Inc. AtlanticRichfieldCompany FROM: ARCO Alaska, Inc. Attn.: Ms. Keili A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE: June 2. 1996 Transmitted herwith is the foilowinq data: DIGITAL DATA Displayed by Schlumberger: ~ ~¢'~Open Reel Tape -LDWG For " HILE DRILLING" CDR & CDN C,,/with paper file listing C~.5 Floppy -ASCII Format-Depth-adjusted Directional Survey Temptation lA 6" Open Reel Tape -LDWG Format -"LOGGING WHILE DRILLING" CDR & CDN with paper file listing 3.5 Floppy-ASCII Format-Depth-adjusted Directional Survey END OF WELL REPORTS Displayed By EPOCH WELL LOGGING INC.: Bergschrund 2A Nanuk 1 Neve 1 Temptation 1 Temptation lA If you have any questions please call me at (907) 265-6240. Kelli RETURN SIGNED COPY TO: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Received by: /~.t~ DATE: /¢:¢_.,~~v p~/~f.~rove d fo r t ransmitta, by: , -~ ~. I-/i/0~'eycL~tt Manager, North Alas a~xploration ARCO Alaska Inc. AtlanticRichfieldCompany CONFIDENTIAL DA TA FROM: Sandra D. Lernke, ATO1354 ARCO Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Ak. Oil & Gas Conservation Comm. ATTN: Howard Okland 3001 Porcupine Drive Anchorage, Alaska 99510 RE: A OGCC data request: Colville directional survey data DATE: 05/28/96 Transmitted herewith is the following: Colville Delta Exploratory well directional survey digital data ASCII files: CONFIDENTIAL DA TA *Temptation 1 501032023300 0'-7660' md *TemptationlA 501032023301 0-8950' md or(~ -~33 ._._~----*Bergschrund 2A 501032023201 1797.5'-7894' **Alpine 3 501032023400 an updated version of this survey is forthcoming to AAI from Geoquest - the original survey was in error. additional surveys for 1996 drilling season deviated boreholes will be forthcoming when data is available. (waiting on surveys for Neve I and lA) CC: M. McDermott, Kelli Thibodeau Approved for transmittal by: Receipt: ~ ~~/ Return receipt to: ARCO Alaska, Inc. ATTN: S. Lemke, ATO-1354 700 G. Street Anchorage, AK 99501 r~AY 2-J 1996 Prepared by: Sandm D. Lemke ~asl~a 0il & ~mputer Services STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL J---J GAS J'--J SUSPENDED j'~ ABANDONED r-1 SERVICE J--"J 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 96-33 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20232-01 4 Location of well at surface ~'~??/;';;~';'7~:,~- At Total Depth i~/:-- i: ~~ 11 Field and Pool 530' FSL, 3' FWL, SEC. 4, T11 N, R5E, UM ~:',.,..~. _~_. . ....... WILDCAT 5 Elevation in feet (indicate KB, DF, etc.) I -~''' [."~¢~'~b;Designation and Serial No. RKB 42' ABOVE SLI ADL 372095 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Deplh, if offshore 16 No. of Completions 08-Feb-96 30-Mar-96 4-17-96 Suspended NA feet MSL NA 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set ] 21 Thickness of permafrost 7896' MD, 7508'TVD YES [~ NO BII NA feet MDI =800' NA 22 Type Electric or Other Logs Run TO BE SENT UNDER SEPARATE COVER BY EXPLORATION GEOLOGY 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58# B SURF 110' 20" 350 sx AS I 9.625" 53.5# L-80 SURF 1827' 12.25" 335 SX AS I 8, 550 SX AS III 7" 26.0# L-80 SURF 7866' 8.5" 270 SX Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) 'PACKER SET (MD) NA 3.5" 7165' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) J AMOUNT & KIND OF MATERIAL USED See attached operations summary 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ¢ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. TO BE SENT UNDER SEPARATE COVER BY EXPLORATION GEOLOGY E( EIVCLD Alaska 0il & Gas Con~. Commission Anchorago Form 10-407 Submil in duplicate 29. 30. GEOLOGIC MAF~ERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TO BE SENT BY EXPLORATION GEOLOGY 31. LIST OF A-I-FACHMENTS AS-BUILT SURVEYS, P&A DIAGRAM, AND DIRECTIONAL SURVEYS AND DALLY DRILLING REPORTS 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed Title 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 spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Well Name: APl #: WELL SUMMARY ARCO Bergschrund #2A cf Lc--- 0'5 % 50-103-20232-01 CONFIDENTIAL J~er AOGCC reg. 2~ AAC, 25.537 Surface Location: ASP: x=390,004 y=5,969,823 Lat: 70.326583 Long: 150.892024 S/T/R: 964' FNL, 1370' FWL, sec 9, T11 N, R5E Lease Number: ADL 372095 Rig: Doyon 141 Elevation: G.L. = 13' K.B. = 43' Spud Date: March 25, 1996 Total Depth: 7896' MD (-7465' SS) driller TD Date: Completion Date: Completion Status: Formation @ TD: Casing Record: March 31, 1996 April 5, 1996 Suspended Jurassic Kingak (Nuiqsut) 16" @ 107' MD 9 5/8"@ 1827' MD 7" @ 7823' MD RECEIVED AUG 1 9 1996 Alaska Oil & Gas Cons. commission And~omge Production Tests: Cased hole DST Perfed from 7368'-7454', flowed 1145 BOPD, 650 GOR, 205# FTP, 39.8°API gravity oil, skin +14.4. No stimulation, KH 1270 md-fi, flow efficiency 34% and production index 9.59 BPB/psi. Tops picked on MWD logs. No wireline logs were run. Geological Tops: MD SS Kick-off 1945' - 1902' Top Albian 4139' -3941' Top Albian B 5820' -5468" Top Albian C 6222' -5840' HRZ 6839' -6428' K- 1 7117' -6698' LCU 7214' -6793' Top Jurassic 7366' -6942' Total Depth (driller) 7896' -7464' Bergschrund #2A page 2 Conventional Cores: none Logging Runs: Run #1 (7451'-7373' MD)' Rotary Sidewall Cores (MSCT/GR) Run #2 (7407'-7370' MD): Rotary Sidewall Cores (MSCT/GR) MWD gamma ray/resistivity (CDR): kick-off to TD MWD neutron/density (CDN): 3900' MD to TD Mudlog' kick-off to TD Sidewall Cores: RSWC run#1 (7451'-7373' MD): shot 26, recovered 26 RSWC run#2 (7407'-7370' MD): shot 25, recovered 24 Bergschrund #2A Ac dal Suspension N. 3" 5M Master valve M. 3-1/8" 5M FMC Gen IV tubing hanger with 3" ISA BPV Profile L. 3-1/2" 9.3#, L-80 EUE 8rd Mod tbg to hanger CONFIDENTIAL 9-5/8" casing @ 1827' NOTES: 1. WL blanking plug set in 'XN' Nipple at 7131' MD RKB 2.10.6 lb/gal kill weight brine placed in tubing. 10.1 lb/gal kill weight brine placed in tubing annulus. 3. Non-freezing diesel "caps" placed in top 1000' of tubing and tubing annulus.. 4. 7" x 9-5/8" annulus filled with cement. 5. Back pressure valve installled in tubing hanger 6. VR plug installewd in tubing head annulus valve J. 3-1/2" OTIS 'X' Nipple 2.813" ID Selective Profile @ 7046' MD I. 1 jt 3-1/2" J-55 EUE 8rd MOD tbg H. 3-1/2" x 1-1/2" Camco MMM mandrell (GLM #1) with dummy valve and TG latch. Handling pups installed on mandrel: 6' L-80 on top & 4' J-55 on bottom; Mandrel set @ 7085' MD G. 3-1/2" OTIS 'XN' nipple 2.75" ID/2.75" NOGO profile @ 7131' MD F. 3-1/2" Baker 'GBH-22' Locator seal assembly with 10' seals (4.0" OD) @ 7164' MD E. Baker 'FAB-I' permanent packer 3-1/2" X 7" @ 7165' MD RKB D. Baker Seal Bore Extension, 80-40, @ 7166' MD C. XO 4-3/4" Acme x 4-1/2" EUE @ 7175' MD B. Pup jt 4-1/2" x 5' 12.6# L80 EUE 8rd Mod @ 7176' MD (Cutoff at 7177') 7" 26# L-80 Top of cement plug 7220' (84' cement plug) 84' cement plug above sand plug Sand plug from PBTD up to 7304' (64' above pen's) J-4 Sand Perfs 7368'-7454' MD -. Top of Fish (perf guns & tail pipe 7510') PBTD @ 7774' WLM, TD @ 7896', 7" shoe @ 7866' FJ, 5~9~96 . t No SOA~ ~~ON ~ L~ ~ P~O~AO~ ~AT ~1~ ~T. ~ 70' ~g' ~' F.N.~, ~,DTO' F.~.~ NO~ ~. ~S ~ H~IZONT~ L~A~ ~D ~A~ ~ ~INA~ ~0~ Z~ ¢~ N.~D. ~7. ~ I~ P~ IS ~~ ~ ~ID N~. ~..___ ....~.._ .~ SU~OR'S C~R~. ~ U~ TO ~AC~ ~D SUR~NG IN ~E '~~~~ ~P~~ ~D ~AT ~ DIM~ONS ~ O~ LOUNSBURY ARCO Alaska, Inc "~ ~L~T~Y ~ C~DU~T~ Subsidiary of Atlantic Ri~field Company ~ I~ P~ AS-BUILT C~D R~ NO. I ~A. NG N~ ~so~5 2~1~s CEA-UI~-601D195 ~1 ~ 2 Date: 5/9/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:BERGSCHRUND %2A RIG:DOYON RIG 141 WI: 0% SECURITY:2 WELL ID: AX9336 AFC: AX9336 TYPE' AFC EST/UL:$ 2201M/ 2500M STATE:ALASKA API NUMBER: 50-103-29232-01 AREA/CNTY: NORTH SLOPE WEST FIELD' COLVILLE RIVER UNIT SPUD:02/08/96 START COMP: BLOCK: FINAL: 03/24/96 ( 1) TD: 1827'(1827) SUPV:DCL 03/25/96 (2) TD' 1827'( 0) SUPV-DCL 03/26/96 (3) TD: 1827' ( 0) SUPV:DCL 03/27/96 ( 4) TD: 3973'(2146) SUPV:WJP 03/28/96 (5) TD: 5016'(1043) SUPV:WJP 03/29/96 (6) TD: 5934'(918) SUPV:WJP 03/30/96 (7) TD: 7312'(1378) SUPV'WJP 03/31/96 (8) TD: 7896' (584) SUPV:WJP 04/01/96 ( 9) TD: 7896'( 0) SUPV:WJP MW' 0.0 PV/YP' 0/ 0 APIWL: 0.0 NU BOPE Move camp. NU BOPE. Accept rig 0300 hrs. 3/24/96. MW: 8.5 PV/YP: 1/ 0 APIWL: 0.0 PREP TO DISPLACE W/KCL MUD NU BOPE. Function test BOP. Test BOPE to 250/5000 psi w/ annular to 3000 psi. Tag cement at 1012'. Drill soft cement from 1012' to 1600'. Drill firm cement from 1600' to 1800' MW: 10.0 PV/YP' 17/20 APIWL: 6.0 NU BOPE. Function test BOP. Test BOPE to 250/5000 psi w/ MW: 10.1 PV/YP: 20/27 DRILLING 8.5" HOLE Drill 8.5" hole 2648' to 3973' APIWL: 6.4 MW' 10.0 PV/YP' 15/28 DRILLING 8.5" HOLE Drill 8.5" hole 3973' to 5016' APIWL: 12.6 MW: 10.2 PV/YP: 14/23 APIWL: 10.4 DRILLING 8.5" HOLE Drill 8.5" hole 5016' to 5132'. Unload neutron source f/CDN. Load neutron source into CDN. Drill/slide 8.5" hole 5132' to 5934' MW: 10.1 PV/YP: 25/19 DRILLING 8.5" HOLE Drill 8.5" hole 5934' to 7312' APIWL: 5.4 MW: 10.1 PV/YP: 47/20 APIWL: 4.8 POH FOR LOGS Drill 8 5" hole 7312' to 7896' POH to shoe Tight @ 7409' 5825'-5732' 2274'-1993' Wash and ream 7786' to 7896' POH. ! MW: 10.1 PV/YP' 22/15 APIWL: 5.0 RIH TO CONDITION FOR CASING Log run #1 - MSCT/GR. Log run #2 - MSCT/GR. Test BOPE. RIH w/cleanout assy. Date: 5/9/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 04/02/96 (10) TD: 7896' ( 0) SUPV:WJP 04/03/96 (11) TD' 7896'( 0) SUPV:DCL 04/04/96 (12) TD: 7896' ( 0) SUPV:DCL 04/05/96 (13) TD' 7779'( 0) SUPV:DCL 04/06/96 (14) TD: 7779' ( 0) SUPV:DCL 04/07/96 (15) TD: 7779' ( 0) SUPV:DCL 04/08/96 (16) TD' 7779'( 0) SUPV:DCL 04/09/96 (17) TD: 7779' ( 0) SUPV:DCL 04/10/96 (18) TD: 7779'( 0) SUPV:WJP MW: 10.1 PV/YP: 20/13 APIWL: 5.2 RUNNING 7" CASING Wash from 7740' to 7896' Tight at 7853' C & C hole for casing. Run 7" casing. MW: 10.1 PV/YP: 0/ 0 APIWL: 0.0 RIH W/SCHLUMBERGER GR & JB Finish RIH w/7" csg to top of fill at 7823'. Test lines to 3500 psi. Pump cement. ND BOP. NU BOPE. Freeze protect annulus. MW: 10.2 PV/YP: 0/ 0 APIWL: 0.0 RIH W/3.5" COMPLETION EQUIPMEN RIH w/CBT/CET/GR/CCL. Log from 7770' to 6100' w/GR to surface. Test casing to 3000 psi for 30 min. RIH w/TCP gun and packer assembly. Set pkr at 7163'. RIH w/3.5 completion equipment. MW: 10.2 PV/YP: 0/ 0 APIWL: 0.0 CLEAN RIG FOR MOVE Finish RIH w/3.5" tbg. Test annulus to 4000 psi. OK. ND BOPE. NU tree. Test tree and pack off to 5000 psi. Install BPV. Prepare to move. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Finish cleaning rig. Release rig at 2000 hrs. 4/5/96. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 PREP TO TEST LINES Move rig off location to iD pad. Prepare to flow test. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 FLOW TEST WELL Test lines to choke manifold to 5000 psi. Pre-test safety meeting. Pressure tbg to 3200 psi. Guns fired at 10:30 hrs. Flow test well through HES equipment. MW: 10.2 PV/YP- 0/ 0 FLOW TEST WELL Flow test well through HES equipment. APIWL: 0.0 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 SHUT-IN PRESSURE BUILD-UP Flow well through HES test equipment. Shut in well downhole w/PRST, accumulate shut-in pressure data. Date: 5/9/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 3 04/11/96 (19) TD: 7779' ( 0) SUPV: WJP 04/12/96 (20) TD: 7779'( 0) SUPV:WJP 04/13/96 (21) TD: 7779'( 0) SUPV:WJP 04/14/96 (22) TD: 7779' ( 0) SUPV:WJP 04/15/96 (23) TD: 7779'( 0) SUPV: WJP 04/16/96 (24) TD: 7779' ( 0) SUPV: WJP 04/17/96 (25) TD: 7779' ( 0) SUPV: DCL 04/18/96 (26) TD: 7779' ( 0) SUPV:DCL MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 PREPARING FOR WELL SUSPENSION Finish pressure build-up. Prepare to suspend well. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 R/D TESTING EQUIPMENT Prepare location for well suspension. Start rigging down test equipment. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 LOADING OUT TESTING EQUIPMENT R/D testing equipment. Prepare HES testing equipment for load-out. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 R/U FOR COILED TUBING WORK Pressure test lines to 3000 psi. Pump cement. CIP @ 1045 hrs. Continue loading out testing equipment. MW: 10.2 PV/YP: 0/ 0 APIWL: 0.0 PREP TO RIH W/COILED TUBING Pressure test BOPE to 300/4000 psi. Well dead. RIH w/tbg cutter assy. Tag up on 4.5" x 3.5" XO @ 7186'. Cutter would not pass. Confirm tag-up depth, P/U to 7177', park and cut tubing. Confirm cut, RIH, tag fish @ 7490'. Freeze protect CTU and wellbore, shut down for night. MW: 10.2 PV/YP: 0/ 0 APIWL: 0.0 PREPARE TO RIH TO TAG CMT. RIH, tag fish and lay in first stage of sand slurry. Wait for sand to settle out. Repeat up to fourth stage of sand slurry. Pump cement. CIP @ 2100 hrs. Displace well to seawater. Freeze protect well and equipment. WOC. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 PREPARE RU HALLIBURTON SLICKLI RIH to 500' w/coil tbg. Test equipment to 4000 psi. Tag cement at 7220' (84' cement plug). Displace well w/brine and top 1000' w/diesel. Secure well. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 FINAL REPORT Move out CTU. RIH and set plug in XN nipple at 7131'. Pressure tbg and annulus to 3000 psi. Test 9-5/8" x 7" annulus to 1500 psi. Set BPV. Secure well. End of WellSummary for Well:AX9336 API# 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 501032023201 e e MD INCLINATION AZIMUTH 0.00 0.00 0.00 1797.50 0.15 345.85 1800.00 0.20 344.96 1810.00 0.41 341.55 1820.00 0.64 337.65 1830.00 0.82 334.70 1840.00 1.02 331.31 1850.00 1.22 327.93 1860.00 1.42 324.55 1870.00 1.55 323.61 1880.00 1.64 323.66 1890.00 1.74 323.71 1900.00 1.84 323.76 1910.00 1.93 323.81 1920.00 2.03 323.86 1930.00 2.24 324.06 1940.00 2.64 324.54 1950.00 3.04 325.02 1960.00 3.44 325.49 1970.00 3.84 325.97 1980.00 4.24 326.45 1990.00 4.64 326.88 2000.00 4.92 326.82 2010.00 5.20 326.77 2020.00 5.48 326.72 2030.00 5.76 326.67 2040.00 6.04 326.61 2050.00 6.32 326.56 2060.00 6.64 326.61 2070.00 6.98 326.68 2080.00 7.32 326.76 2090.00 7.66 326.83 2100.00 8.00 326.91 2110.00 8.34 326.98 2120.00 8.55 326.91 2130.00 8.69 326.74 2140.00 8.83 326.57 2150.00 8.97 326.41 2160.00 9.11 326.24 2170.00 9.26 326.08 2180.00 9.41 325.83 2190.00 9.59 325.46 2200.00 9.78 325.09 2210.00 9.96 324.72 2220.00 10.14 324.34 2230.00 10.32 323.97 2240.00 10.50 323.60 2250.00 10.68 323.23 2260.00 10.87 322.86 2270.00 11.05 322.49 2280.00 11.27 322.15 @(;AN~~iE;Ð 1)"3 \qV 0 CJ 1. e e 501032023201 2290.00 11.50 321.81 501032023201 2300.00 11.73 321 .4 7 501032023201 2310.00 11.95 321 . 13 501032023201 2320.00 12.18 320.79 501032023201 2330.00 12.40 320.45 501032023201 2340.00 12.63 320.11 501032023201 2350.00 12.86 319.77 501032023201 2360.00 13.08 319.43 501032023201 2370.00 13.37 319.10 501032023201 2380.00 13.71 318.79 501032023201 2390.00 14.05 318.47 501032023201 2400.00 14.39 318.15 501032023201 2410.00 14.74 317.83 501032023201 2420.00 15.08 317.51 501032023201 2430.00 15.42 317.20 501032023201 2440.00 15.76 316.88 501032023201 2450.00 16.10 316.56 501032023201 2460.00 16.45 316.38 501032023201 2470.00 16.80 316.51 501032023201 2480.00 17.15 316.65 501032023201 2490.00 17.50 316.78 501032023201 2500.00 17.85 316.92 501032023201 2510.00 18.20 317.05 501032023201 2520.00 18.55 317.18 501032023201 2530.00 18.90 317.32 501032023201 2540.00 19.25 317.45 501032023201 2550.00 19.60 317.59 501032023201 2560.00 19.80 317.47 501032023201 2570.00 19.99 317.34 501032023201 2580.00 20.19 317.21 501032023201 2590.00 20.38 317.09 501032023201 2600.00 20.58 316.96 501032023201 2610.00 20.77 316.83 501032023201 2620.00 20.97 316.71 501032023201 2630.00 21.16 316.58 501032023201 2640.00 21.36 316.45 501032023201 2650.00 21.59 316.45 501032023201 2660.00 21.84 316.49 501032023201 2670.00 22.09 316.53 501032023201 2680.00 22.34 316.57 501032023201 2690.00 22.59 316.61 501032023201 2700.00 22.84 316.65 501032023201 2710.00 23.09 316.69 501032023201 2720.00 23.34 316.73 501032023201 2730.00 23.59 316.77 501032023201 2740.00 23.76 316.78 501032023201 2750.00 23.82 316.75 501032023201 2760.00 23.88 316.72 501032023201 2770.00 23.94 316.69 501032023201 2780.00 24.00 316.66 501032023201 2790.00 24.06 316.63 501032023201 2800.00 24.12 316.60 e e 501032023201 2810.00 24.17 316.57 501032023201 2820.00 24.23 316.54 501032023201 2830.00 24.29 316.54 501032023201 2840.00 24.31 316.66 501032023201 2850.00 24.34 316.78 501032023201 2860.00 24.36 316.91 501032023201 2870.00 24.39 317.03 501032023201 2880.00 24.42 317.15 501032023201 2890.00 24.44 317.27 501032023201 2900.00 24.47 317.39 501032023201 2910.00 24.50 317.51 501032023201 2920.00 24.52 317.63 501032023201 2930.00 24.49 317.58 501032023201 2940.00 24.43 317.45 501032023201 2950.00 24.38 317.33 501032023201 2960.00 24.32 317.20 501032023201 2970.00 24.26 317.07 501032023201 2980.00 24.21 316.94 501032023201 2990.00 24.15 316.81 501032023201 3000.00 24.09 316.68 501032023201 3010.00 24.04 316.55 501032023201 3020.00 24.01 316.45 501032023201 3030.00 24.12 316.46 501032023201 3040.00 24.23 316.46 501032023201 3050.00 24.33 316.46 501032023201 3060.00 24.44 316.47 501032023201 3070.00 24.55 316.47 501032023201 3080.00 24.66 316.48 501032023201 3090.00 24.76 316.48 501032023201 3100.00 24.87 316.49 501032023201 3110.00 24.98 316.49 501032023201 3120.00 25.03 316.55 501032023201 3130.00 25.07 316.61 501032023201 3140.00 25.11 316.68 501032023201 3150.00 25.15 316.75 501032023201 3160.00 25.19 316.81 501032023201 3170.00 25.22 316.88 501032023201 3180.00 25.26 316.94 501032023201 3190.00 25.30 317.01 501032023201 3200.00 25.34 317.07 501032023201 3210.00 25.37 317.02 501032023201 3220.00 25.39 316.90 501032023201 3230.00 25.41 316.77 501032023201 3240.00 25.43 316.64 501032023201 3250.00 25.44 316.52 501032023201 3260.00 25.46 316.39 501032023201 3270.00 25.48 316.27 501032023201 3280.00 25.50 316.14 501032023201 3290.00 25.52 316.01 501032023201 3300.00 25.53 315.93 501032023201 3310.00 25.50 316.01 501032023201 3320.00 25.48 316.09 tit e 501032023201 3330.00 25.46 316.17 501032023201 3340.00 25.44 316.25 501032023201 3350.00 25.41 316.33 501032023201 3360.00 25.39 316.41 501032023201 3370.00 25.37 316.49 501032023201 3380.00 25.35 316.57 501032023201 3390.00 25.32 316.65 501032023201 3400.00 25.31 316.63 501032023201 3410.00 25.30 316.59 501032023201 3420.00 25.30 316.54 501032023201 3430.00 25.29 316.49 501032023201 3440.00 25.28 316.45 501032023201 3450.00 25.27 316.40 501032023201 3460.00 25.26 316.36 501032023201 3470.00 25.25 316.31 501032023201 3480.00 25.24 316.26 501032023201 3490.00 25.23 316.31 501032023201 3500.00 25.21 316.40 501032023201 3510.00 25.20 316.49 501032023201 3520.00 25.18 316.58 501032023201 3530.00 25.17 316.67 501032023201 3540.00 25.15 316.76 501032023201 3550.00 25.14 316.85 501032023201 3560.00 25.12 316.94 501032023201 3570.00 25.11 317.03 501032023201 3580.00 25.09 317.11 501032023201 3590.00 25.07 317.18 501032023201 3600.00 25.06 317.25 501032023201 3610.00 25.04 317.31 501032023201 3620.00 25.02 317.38 501032023201 3630.00 25.00 317.45 501032023201 3640.00 24.98 317.52 501032023201 3650.00 24.96 317.58 501032023201 3660.00 24.95 317.65 501032023201 3670.00 24.92 317.73 501032023201 3680.00 24.85 317.84 501032023201 3690.00 24.78 317.95 501032023201 3700.00 24.71 318.06 501032023201 3710.00 24.64 318.18 501032023201 3720.00 24.57 318.29 501032023201 3730.00 24.50 318.40 501032023201 3740.00 24.43 318.51 501032023201 3750.00 24.36 318.63 501032023201 3760.00 24.29 318.74 501032023201 3770.00 24.22 318.90 501032023201 3780.00 24.15 319.08 501032023201 3790.00 24.08 319.26 501032023201 3800.00 24.02 319.44 501032023201 3810.00 23.95 319.62 501032023201 3820.00 23.88 319.80 501032023201 3830.00 23.81 319.98 501032023201 3840.00 23.74 320.16 e e 501032023201 3850.00 23.67 320.34 501032023201 3860.00 23.64 320.44 501032023201 3870.00 23.75 320.30 501032023201 3880.00 23.85 320.15 501032023201 3890.00 23.95 320.01 501032023201 3900.00 24.05 319.86 501032023201 3910.00 24.15 319.71 501032023201 3920.00 24.25 319.57 501032023201 3930.00 24.35 319.42 501032023201 3940.00 24.45 319.28 501032023201 3950.00 24.55 319.13 501032023201 3960.00 24.58 319.17 501032023201 3970.00 24.60 319.22 501032023201 3980.00 24.62 319.28 501032023201 3990.00 24.64 319.33 501032023201 4000.00 24.66 319.38 501032023201 4010.00 24.68 319.44 501032023201 4020.00 24.70 319.49 501032023201 4030.00 24.72 319.54 501032023201 4040.00 24.73 319.59 501032023201 4050.00 24.69 319.56 501032023201 4060.00 24.65 319.54 501032023201 4070.00 24.61 319.51 501032023201 4080.00 24.57 319.49 501032023201 4090.00 24.53 319.46 501032023201 4100.00 24.49 319.44 501032023201 4110.00 24.45 319.42 501032023201 4120.00 24.41 319.39 501032023201 4130.00 24.37 319.37 501032023201 4140.00 24.35 319.35 501032023201 4150.00 24.33 319.35 501032023201 4160.00 24.32 319.34 501032023201 4170.00 24.30 319.33 501032023201 4180.00 24.28 319.32 501032023201 4190.00 24.27 319.32 501032023201 4200.00 24.25 319.31 501032023201 4210.00 24.24 319.30 501032023201 4220.00 24.22 319.29 501032023201 4230.00 24.19 319.26 501032023201 4240.00 24.15 319.18 501032023201 4250.00 24.11 319.10 501032023201 4260.00 24.07 319.01 501032023201 4270.00 24.03 318.93 501032023201 4280.00 23.99 318.85 501032023201 4290.00 23.95 318.77 501032023201 4300.00 23.91 318.69 501032023201 4310.00 23.87 318.61 501032023201 4320.00 23.83 318.53 501032023201 4330.00 23.87 318.44 501032023201 4340.00 23.91 318.34 501032023201 4350.00 23.95 318.25 501032023201 4360.00 24.00 318.15 e e 501032023201 4370.00 24.04 318.06 501032023201 4380.00 24.08 317.96 501032023201 4390.00 24.12 317.87 501032023201 4400.00 24.16 317.78 501032023201 4410.00 24.20 317.68 501032023201 4420.00 24.24 317.64 501032023201 4430.00 24.26 317.65 501032023201 4440.00 24.29 317.65 501032023201 4450.00 24.32 317.66 501032023201 4460.00 24.35 317.66 501032023201 4470.00 24.38 317.67 501032023201 4480.00 24.41 317.67 501032023201 4490.00 24.44 317.68 501032023201 4500.00 24.46 317.69 501032023201 4510.00 24.49 317.69 501032023201 4520.00 24.48 317.62 501032023201 4530.00 24.47 317.55 501032023201 4540.00 24.46 317.48 501032023201 4550.00 24.45 317.41 501032023201 4560.00 24.44 317.34 501032023201 4570.00 24.43 317.27 501032023201 4580.00 24.42 317.20 501032023201 4590.00 24.40 317.13 501032023201 4600.00 24.39 317.06 501032023201 4610.00 24.36 317.08 501032023201 4620.00 24.30 317.13 501032023201 4630.00 24.25 317.19 501032023201 4640.00 24.19 317.24 501032023201 4650.00 24.14 317.30 501032023201 4660.00 24.09 317.35 501032023201 4670.00 24.03 317.41 501032023201 4680.00 23.98 317.46 501032023201 4690.00 23.92 317.52 501032023201 4700.00 23.88 317.56 501032023201 4710.00 23.87 317.58 501032023201 4720.00 23.87 317.59 501032023201 4730.00 23.86 317.61 501032023201 4740.00 23.85 317.62 501032023201 4750.00 23.85 317.64 501032023201 4760.00 23.84 317.65 501032023201 4770.00 23.83 317.67 501032023201 4780.00 23.83 317.68 501032023201 4790.00 23.82 317.70 501032023201 4800.00 23.92 317.50 501032023201 4810.00 24.04 317.28 501032023201 4820.00 24.15 317.06 501032023201 4830.00 24.27 316.83 501032023201 4840.00 24.38 316.61 501032023201 4850.00 24.50 316.39 501032023201 4860.00 24.61 316.17 501032023201 4870.00 24.73 315.94 501032023201 4880.00 24.84 315.72 e e 501032023201 4890.00 24.92 315.56 501032023201 4900.00 24.94 315.49 501032023201 4910.00 24.97 315.42 501032023201 4920.00 24.99 315.34 501032023201 4930.00 25.02 315.27 501032023201 4940.00 25.04 315.20 501032023201 4950.00 25.07 315.13 501032023201 4960.00 25.09 315.06 501032023201 4970.00 25.12 314.98 501032023201 4980.00 25.14 314.91 501032023201 4990.00 25.15 314.68 501032023201 5000.00 25.15 314.44 501032023201 5010.00 25.16 314.20 501032023201 5020.00 25.16 313.96 501032023201 5030.00 25.17 313.73 501032023201 5040.00 25.17 313.49 501032023201 5050.00 25.18 313.25 501032023201 5060.00 25.18 313.01 501032023201 5070.00 25.19 312.78 501032023201 5080.00 25.26 312.73 501032023201 5090.00 25.36 312.75 501032023201 5100.00 25.45 312.77 501032023201 5110.00 25.54 312.78 501032023201 5120.00 25.64 312.80 501032023201 5130.00 25.73 312.82 501032023201 5140.00 25.82 312.84 501032023201 5150.00 25.92 312.85 501032023201 5160.00 26.01 312.87 501032023201 5170.00 26.05 312.92 501032023201 5180.00 26.04 313.01 501032023201 5190.00 26.03 313.09 501032023201 5200.00 26.02 313.18 501032023201 5210.00 26.01 313.26 501032023201 5220.00 26.00 313.35 501032023201 5230.00 25.98 313.44 501032023201 5240.00 25.97 313.52 501032023201 5250.00 25.96 313.61 501032023201 5260.00 25.95 313.69 501032023201 5270.00 25.87 313.62 501032023201 5280.00 25.79 313.55 501032023201 5290.00 25.72 313.48 501032023201 5300.00 25.64 313.42 501032023201 5310.00 25.57 313.35 501032023201 5320.00 25.49 313.28 501032023201 5330.00 25.41 313.21 501032023201 5340.00 25.34 313.15 501032023201 5350.00 25.26 313.08 501032023201 5360.00 25.34 313.39 501032023201 5370.00 25.44 313.76 501032023201 5380.00 25.55 314.13 501032023201 5390.00 25.65 314.50 501032023201 5400.00 25.76 314.87 e e 501032023201 5410.00 25.86 315.23 501032023201 5420.00 25.97 315.60 501032023201 5430.00 26.07 315.97 501032023201 5440.00 26.18 316.34 501032023201 5450.00 26.12 316.41 501032023201 5460.00 26.02 316.39 501032023201 5470.00 25.92 316.37 501032023201 5480.00 25.82 316.35 501032023201 5490.00 25.72 316.33 501032023201 5500.00 25.62 316.31 501032023201 5510.00 25.52 316.29 501032023201 5520.00 25.42 316.26 501032023201 5530.00 25.31 316.24 501032023201 5540.00 25.21 316.24 501032023201 5550.00 25.12 316.26 501032023201 5560.00 25.02 316.29 501032023201 5570.00 24.92 316.31 501032023201 5580.00 24.82 316.33 501032023201 5590.00 24.72 316.36 501032023201 5600.00 24.62 316.38 501032023201 5610.00 24.52 316.41 501032023201 5620.00 24.42 316.43 501032023201 5630.00 24.33 316.46 501032023201 5640.00 24.24 316.52 501032023201 5650.00 24.15 316.59 501032023201 5660.00 24.07 316.65 501032023201 5670.00 23.98 316.71 501032023201 5680.00 23.89 316.78 501032023201 5690.00 23.80 316.84 501032023201 5700.00 23.72 316.90 501032023201 5710.00 23.63 316.97 501032023201 5720.00 23.54 317.03 501032023201 5730.00 23.58 316.97 501032023201 5740.00 23.63 316.88 501032023201 5750.00 23.69 316.80 501032023201 5760.00 23.74 316.72 501032023201 5770.00 23.80 316.63 501032023201 5780.00 23.85 316.55 501032023201 5790.00 23.90 316.46 501032023201 5800.00 23.96 316.38 501032023201 5810.00 24.01 316.30 501032023201 5820.00 23.99 316.21 501032023201 5830.00 23.92 316.13 501032023201 5840.00 23.86 316.05 501032023201 5850.00 23.80 315.96 501032023201 5860.00 23.74 315.88 501032023201 5870.00 23.67 315.80 501032023201 5880.00 23.61 315.71 501032023201 5890.00 23.55 315.63 501032023201 5900.00 23.48 315.55 501032023201 5910.00 23.41 315.49 501032023201 5920.00 23.31 315.46 e e 501032023201 5930.00 23.22 315.44 501032023201 5940.00 23.12 315.41 501032023201 5950.00 23.03 315.39 501032023201 5960.00 22.93 315.36 501032023201 5970.00 22.84 315.34 501032023201 5980.00 22.74 315.31 501032023201 5990.00 22.65 315.29 501032023201 6000.00 22.55 315.30 501032023201 6010.00 22.46 315.41 501032023201 6020.00 22.36 315.51 501032023201 6030.00 22.27 315.62 501032023201 6040.00 22.17 315.72 501032023201 6050.00 22.08 315.83 501032023201 6060.00 21.98 315.93 501032023201 6070.00 21.89 316.04 501032023201 6080.00 21.79 316.14 501032023201 6090.00 21.70 316.25 501032023201 6100.00 21.60 316.29 501032023201 6110.00 21.49 316.33 501032023201 6120.00 21.39 316.37 501032023201 6130.00 21.28 316.41 501032023201 6140.00 21.18 316.44 501032023201 6150.00 21.07 316.48 501032023201 6160.00 20.97 316.52 501032023201 6170.00 20.86 316.56 501032023201 6180.00 20.76 316.59 501032023201 6190.00 20.65 316.63 501032023201 6200.00 20.53 316.68 501032023201 6210.00 20.42 316.72 501032023201 6220.00 20.30 316.77 501032023201 6230.00 20.19 316.81 501032023201 6240.00 20.08 316.85 501032023201 6250.00 19.96 316.90 501032023201 6260.00 19.85 316.94 501032023201 6270.00 19.74 316.98 501032023201 6280.00 19.62 317.01 501032023201 6290.00 19.53 316.93 501032023201 6300.00 19.43 316.84 501032023201 6310.00 19.33 316.76 501032023201 6320.00 19.23 316.68 501032023201 6330.00 19.13 316.60 501032023201 6340.00 19.03 316.52 501032023201 6350.00 18.93 316.44 501032023201 6360.00 18.83 316.36 501032023201 6370.00 18.74 316.28 501032023201 6380.00 18.67 316.37 501032023201 6390.00 18.60 316.46 501032023201 6400.00 18.53 316.55 501032023201 6410.00 18.46 316.63 501032023201 6420.00 18.39 316.72 501032023201 6430.00 18.31 316.81 501032023201 6440.00 18.24 316.90 e e 501032023201 6450.00 18.17 316.98 501032023201 6460.00 18.10 317.07 501032023201 6470.00 18.00 317.01 501032023201 6480.00 17.89 316.90 501032023201 6490.00 17.78 316.80 501032023201 6500.00 17.67 316.69 501032023201 6510.00 17.56 316.59 501032023201 6520.00 17.46 316.48 501032023201 6530.00 17.35 316.38 501032023201 6540.00 17.24 316.27 501032023201 6550.00 17.13 316.16 501032023201 6560.00 17.05 316.12 501032023201 6570.00 17.00 316.11 501032023201 6580.00 16.94 316.11 501032023201 6590.00 16.89 316.10 501032023201 6600.00 16.83 316.10 501032023201 6610.00 16.78 316.09 501032023201 6620.00 16.73 316.09 501032023201 6630.00 16.67 316.08 501032023201 6640.00 16.62 316.07 501032023201 6650.00 16.56 316.08 501032023201 6660.00 16.51 316.14 501032023201 6670.00 16.45 316.20 501032023201 6680.00 16.39 316.26 501032023201 6690.00 16.34 316.32 501032023201 6700.00 16.28 316.38 501032023201 6710.00 16.22 316.44 501032023201 6720.00 16.16 316.50 501032023201 6730.00 16.11 316.56 501032023201 6740.00 16.05 316.62 501032023201 6750.00 16.00 316.63 501032023201 6760.00 15.95 316.58 501032023201 6770.00 15.91 316.53 501032023201 6780.00 15.86 316.48 501032023201 6790.00 15.82 316.44 501032023201 6800.00 15.77 316.39 501032023201 6810.00 15.73 316.34 501032023201 6820.00 15.68 316.29 501032023201 6830.00 15.63 316.25 501032023201 6840.00 15.58 316.22 501032023201 6850.00 15.51 316.24 501032023201 6860.00 15.44 316.26 501032023201 6870.00 15.37 316.28 501032023201 6880.00 15.30 316.30 501032023201 6890.00 15.23 316.32 501032023201 6900.00 15.16 316.34 501032023201 6910.00 15.09 316.36 501032023201 6920.00 15.02 316.39 501032023201 6930.00 14.95 316.41 501032023201 6940.00 14.84 316.33 501032023201 6950.00 14.73 316.23 501032023201 6960.00 14.61 316.14 e e 501032023201 6970.00 14.50 316.04 501032023201 6980.00 14.38 315.95 501032023201 6990.00 14.27 315.85 501032023201 7000.00 14.16 315.76 501032023201 7010.00 14.04 315.66 501032023201 7020.00 13.93 315.56 501032023201 7030.00 13.75 315.86 501032023201 7040.00 13.56 316.23 501032023201 7050.00 13.37 316.60 501032023201 7060.00 13.18 316.97 501032023201 7070.00 12.98 317.34 501032023201 7080.00 12.79 317.71 501032023201 7090.00 12.60 318.08 501032023201 7100.00 12.41 318.45 501032023201 7110.00 12.22 318.82 501032023201 7120.00 12.05 319.12 501032023201 7130.00 11.96 319.22 501032023201 7140.00 11.86 319.33 501032023201 7150.00 11.76 319.44 501032023201 7160.00 11.66 319.54 501032023201 7170.00 11.57 319.65 501032023201 7180.00 11.47 319.75 501032023201 7190.00 11.37 319.86 501032023201 7200.00 11.27 319.97 501032023201 7210.00 11.18 320.07 501032023201 7220.00 11.12 320.21 501032023201 7230.00 11.09 320.35 501032023201 7240.00 11.05 320.50 501032023201 7250.00 11.01 320.64 501032023201 7260.00 10.98 320.79 501032023201 7270.00 10.94 320.93 501032023201 7280.00 10.90 321.08 501032023201 7290.00 10.87 321.22 501032023201 7300.00 10.83 321.37 501032023201 7310.00 10.80 321.50 501032023201 7320.00 10.77 321.55 501032023201 7330.00 10.74 321.61 501032023201 7340.00 10.71 321.66 501032023201 7350.00 10.68 321.72 501032023201 7360.00 10.65 321.77 501032023201 7370.00 10.62 321.83 501032023201 7380.00 10.60 321.88 501032023201 7390.00 10.57 321.94 501032023201 7400.00 10.54 321.99 501032023201 7410.00 10.52 322.01 501032023201 7420.00 10.50 322.02 501032023201 7430.00 10.49 322.03 501032023201 7440.00 10.47 322.05 501032023201 7450.00 10.45 322.06 501032023201 7460.00 10.43 322.08 501032023201 7470.00 10.42 322.09 501032023201 7480.00 10.40 322.11 e e 501032023201 7490.00 10.38 322.12 501032023201 7500.00 10.34 322.12 501032023201 7510.00 10.28 322.10 501032023201 7520.00 10.23 322.08 501032023201 7530.00 10.17 322.06 501032023201 7540.00 10.11 322.04 501032023201 7550.00 10.05 322.03 501032023201 7560.00 9.99 322.01 501032023201 7570.00 9.94 321.99 501032023201 7580.00 9.88 321.97 501032023201 7590.00 9.82 321.95 501032023201 7600.00 9.80 321.99 501032023201 7610.00 9.77 322.03 501032023201 7620.00 9.75 322.07 501032023201 7630.00 9.72 322.11 501032023201 7640.00 9.70 322.14 501032023201 7650.00 9.68 322.18 501032023201 7660.00 9.65 322.22 501032023201 7670.00 9.63 322.26 501032023201 7680.00 9.61 322.30 501032023201 7690.00 9.58 322.40 501032023201 7700.00 9.55 322.53 501032023201 7710.00 9.53 322.65 501032023201 7720.00 9.50 322.78 501032023201 7730.00 9.47 322.90 501032023201 7740.00 9.44 323.02 501032023201 7750.00 9.42 323.15 501032023201 7760.00 9.39 323.27 501032023201 7770.00 9.36 323.40 501032023201 7780.00 9.33 323.72 501032023201 7790.00 9.28 324.26 501032023201 7800.00 9.23 324.80 501032023201 7810.00 9.19 325.29 501032023201 7820.00 9.19 325.29 501032023201 7830.00 9.19 325.29 501032023201 7840.00 9.19 325.29 501032023201 7850.00 9.19 325.29 501032023201 7860.00 9.19 325.29 501032023201 7870.00 9.19 325.29 501032023201 7880.00 9.19 325.29 501032023201 7890.00 9.19 325.29 501032023201 7896.00 9.19 325.29 PA~E NO. COMPANY ARCO ALASKA WELL NAME BERGSCHRUND LOCATION I COLUILLE DELTA LOCATION 2 NSB, AK DATE: 30-MAR-f6 ~AGNETIC DECLINATION 26,74 GRID CONVERGENCE ANGLE 0o00 API NUMBER 501032023201 JOB NUMBER 37855 ~ER~$CHRUHb CIRCULAR ARC ~ETHODw~w***~ Hb TUD IHC CHD CU~IHC CHG ft ft de~ deg 17~7.1 lf26,~ I78~,I 2052.3 2113.7 2176,0 2270.1 2364,7 2457.0 2550,2 2642,7 2736,2 2828.I 2~23,2 3018,I 31II.0 3203,9 3298,1 33?2.0 I.RATE AZH.CHG CU)AZ~.CH~ deg/lOOtt deg deg TUrN.RATE deq/lOOft 1777,05 0,00 0,00 0,00 0.00 0,00 0.00 1862,86 1.33 1,33 2,01 -22,25 -22,25 -33.80 1?26,32 0,6I 1.94 0,~6 0,32 -2I.~3 0.50 I~88,~0 2.52 4,46 4,02 2,98 -18,94 4.76 2051,82 1,77 6,23 2,~0 -0,33 -17.27 -0,52 2II2,69 2,08 8.31 3,39 0,46 -I8,81 2174.22 0,89 ?,19 1,43 -I.03 -1~.84 2266,?0 1.70 10,90 1.8I -3.50 -23,34 2357.38 2,14 I3,04 2.27 -3,22 -26,55 2448,58 3,15 16,1Y 3,42 -2,72 -27,48 2537,25 2623.88 2710,16 2774,12 2880,77 3.26 1,8I 2.33 0,54 0.25 3482.8 3575,7 3668.5 3762,9 3857,6 19,46 3.50 1.24 -28.23 21,26 1,95 -1,I7 -2~,40 23,59 2.49 0.37 -27.03 24.I3 0,58 -0,27 -27.30 24,38 0,26' 1.15 -28,15 2967,31 -0.54 23,84 -0.57 -I,22 -2~,37 3051.83 1.01 24,84 1,09 0.04 -2~.33 3135.72 0'37 25,21 0,40 0,61 -28.72 3220,78 0,I6 25,38 0,17 -1,19 -29.~1 3305.77 -0.21 25,17 -0.22 0,76 -29.15 3387,85 -0,08 25.0f ~-0,0~ -0,41 3471.91 -0,14 24.75 -0,15 0.83 -28,74 3556.05 -0.I7 24.78 -0,17 0,63 -28.1I 3641,86 -0,66 24,12 -0,70 1.07 -27,05 3728,4I -0.65 23,47 -0,69 1.70 -25,34 3950,6 3813.34 0,94 24,41 1,01 -1,36 -26.70 4038,7 38~3.36 0,I8 24,5~ 0,21 0,47 -26,23 4133,0 3777.21 -0,38 24,2i -0,41 -0,23 --26,4~ 4225,8 4063,7~ -0.15 24.06 -0.I6 -0.06 -26,53 4320,2 4147,97 -0.37 ~3,68 -0,40 -0,76 -27.29 4235,73 4322.47 4408,32 4494.55 4579,52 4414,3 4507,3 4603,6 4698,1 4791.0 0.26 -0.10 -0.51 -0.06 24.07 24,34 24.24 23,73 23,67 CLOSURE TOOL FACE D£S ~LSR? ft deq deq/lOOft deq/lOOft**2 4885,? 4t80,3 5072,4 5165,3 ~25~,3 -8.02 0.00 0,00 0.00 -8,I5 24,62 2,0S 3,09 -8,35 0.00 0.~6 1.69 -8.86 5,39 4,03 4,89 0,00 0,00 2,80 0,75 -II,00 1,73 3,3~ O,Y7 -1,65 -12,43 10,72 1,45 3,I2 -3,72 -14,2i 21,71 1.73 0,51 -3,40 -15,I8 19.07 2.38 0,48 -3,17 -~,78 1.14 3,51 1,23 1,34 -14,60 7,32 3,52 0,02 -1,26 -I4,06 13,30 2,00 1,65 0,40 -I3,23 3.64 2.50 0.53 -0,30 -I2,39 11,58 0,60 2,07 1,21 -I5,06 14,71 0,56 0,03 -I.27 0,04 0.66 -1,27 0.81 0,41 -0.87 .-28.18 0.28 0.05 -28,13 -0,I0 -0,66 -28,78 -0.54 0,52 -28,26 -0.07 0.I4 -28,12 4666.01 1.0~ 24.76 1.15 -2.11 -30.23 4751,48 0.23 24,9? 0.2( -0,6~ -30.?1 4834,83 0,05 25,04 0.06 '2,17 '33,10 4~I8.66 0.87 25,91 0.93 0.15 '32,~4 5003.15 '0.11 25.80 '0.I1 0.81 -32.I3 -0,46 0,67 1,13 1,80 -1.46 0.54 -0,25 -0,07 -0,8I -0,74 0,05 -0.70 0,56 0,15 -2.22 -0.72 -2.38 0.16 0,86 -11,22 137,83 0.78 0.23 -I0,23 1,06 1,09 0,33 -9,44 35,33 0,49 0,64 -8,42 73.03 0,57 0,09 '11,8I 62,70 0,41 0.17 -6,26 115,64 0,21 0,22 -5,38 Ill.52 0,41 0,21 -5.01 123,37 0,34 0,07 -5,21 146,62 0,84 0.53 -7,26 i22,49 1,00 0,17 -7,56 31.21 1,17 0,1~ -8.46 47,53 0,30 0.9~ -9.51 166,40 0,42 0.12 -10,43 I68,31 0.16 0.26 -6,33 133.97 0,52 0,38 -11.18 43.16 0,56 0,05 -11,00 6,73 0,28 0.30 -10,6I 110.26 0.31 0,03 -10,I7 157,65 0,59 0.30 -II.09 140.60 0,09 0.53 -?;,07 39.45 1.47 1,46 -7,20 51.73 0.3~ 1,15 -4,38 87.66 1,01 0,68 -0.78 4.63 0.93 0.08 -~,77 138.13 0,3~ 0,57 SURVEY ANALYSIS ~************ CIRCULAR ARC MD TUD INC CNG CUMINC CNG . ft ft deq deq I_RAIE AZM_CHG CUMAZ~.CHG deq/lOOft deq deg TURN RATE CLOSURE TOOL FACE DLS DLSRT . deq/lOOft ft deo dea/lOOft de~/lOOftw~2 5351.4 5086,22 5442.3 5168,ti 5536.3 5252.78 5628.4 5336.41 5721,4 5421,37 . 5813,0 5505.17 5905,6 5589.91 5997,1 5674,I8 609I,I 5761.21 61~4,3 5848,I4 6278,5 5936,51 6369,5 6022,49 6462,0 6II0.27 6554,3 6198,20 6648,8 6288,73 6745.4 6381.43 6837.5 6470.'0I 6931.2 6560.46 7021.5 6647.92 7117.4 6741.30 7212,7 6834.69 7308.3 6928.54 7399,6 7018,20 7495,3 7112,4I 7589.8 7205.42 -0,70 25,10 -0,76 -0,62 -32,75 0,94 26,05 1,04 3,36 -29,39 -0,95 25,10 -I.01 -0,1~ -29,59 -0.9I 24.19 -0.99 0.22 -29,37 -0.80 23.38 -0.86 0.59 -28.78 0,50 -0.59 -0,87 -0.89 -0,98 -I,07 -0,90 -0,65 -i,01 -0,5I -0.55 -0,42 -0.65 -I.04 -1.83 -0.93 -0,35 -0.26 -0,17 -0.55 0.55 -0.77 -29.55 -0.63- -0.79 -30.32 -0.95 -0.23 -30.55 '0.94 0.99 '29.56 -1.05 0.35 -29.21 23,88 23'30 22,43 :21,54 20.56 1a.59 17.94 16.93 16.42 15,87 : : 10,65 10,37 10,22: 9.67 9,45 9.20 9,04 ,t,14 0.41 -0,99 -0,74 -0,70 0,80 -1,09 -0,97 -0,54 -0,05 -0,57 0.58 -0,46 -0,43 . -0.70 0oi9.. -1.I5 -0,86 -1'91 3,54 . _ ~0~97 1.01 -0~36 i,39 -0.29 ~. 0~.50 -0.18 0,14 -0,58 -0,17 -0.67 5.73 159.38 0.81 0.45 3.69 7.91 58.60 1.91 1.21 '0,21 9.06 I75.16 1.02 0.95 0,24 10,13 174.39 0.99 0.03 0.64 2.57 106,97 0,90 0,09 -0.85 11.75 S2.4~ 0,64 0.28 -0.83 13.08 152.58 0.72 0.06 -0,26 14,67 174,12 0,95 0,26 1,05 16,03 i57,68 1,02 0,07 0.38 10.92 163.58 1.06 0.04 -28.80 0.44 17.56 172.89 1.15 O.Ot -29.54 -0.81 18.22 165.32 1.02 0.14 -28.73 0.87 I8.87 158.98 0,75 0.29 -29.70 -1.05 19.5i 164.2~ 1.14 0.42 -29.75 -0.06 16.9I 172.96 0.54 0.63 -29,17 0,60 21,14 163.89 0,5? 0.05 -29.61 -0.47 21.80 164.50 0.47 0.13 -29.41 0,21 22,5I 175,6~ 0,70 0,24 -30,27 -0,95 23,27 168,76 1,17 0,52 -26.73 3.70 20.39 17~.67 2.08 0.95 -25.72 1.05 23.00 168.25 1.00 1.14 -24.33 1.45 22.10 143.35 0.46 0.57 -23.83 0,55 20,98 I60.13 0.31 0.16 -23.69 0.14 19.73 173.60 0.18 0.14 -23.87 -0.18 23.55 158.19 0.58 0.43 '7682.5 7296.78 -0.22 -0.23 0.36 -23.51 0.39 17.41 164.1~ 0.24 0.37 7775.1 7388.I5 -0.25 -0.27 I.I5 -22.36 1.25 16.09 143.17 0.34 0.10 7809.0 7421.60 -0.16 -0.48 1.83 -20.53 5.39 15.48 119.7I 0.99 1.92 PROJECTED SURVEY TO TOTAL DEPTH 7896,3 7507,72 0,00 9,04 0,00 0,00 -20,53 0,00 13.70 0.00 0,00 1,13 .~CO Alaska, lnc: q~-- 0~'~ cO~!.~!, Sidewall Core Description "~':'-';-;L,;~,;'~J J J,~L Page of Operator and Well Name per AOGCC ~eg, 20 A/lC 25,531 ARCO Bergschrund #2A (RSWC Run #1) J 4 Location Date Shot 26 Recovered 26 Depth Rec, Description Oil Odor Oil Fluor Cut Cut Show ft. in. Stain % Intensit Color color fluor color sum Y 7408.8 .9 lighttannish brown; quartz-rich very mod 80% strng yellow sandstone; very-fine grained (vfL); well light strng sorted; glauconite 1%; rare pyrite; brown moderately well indurated; subangular to subrounded grains; visible porosity 7406.2 1.4 lighttannish brown; quartz-rich very mod 75% strng yellow sandstone; very-fine grained (vfL); well light strng sorted; glauconite 1-3%; trace black brown chert; trace purite; moderately well indurated; subangular to subrounded ~.~'~ grains; visible porosity , / 7403.1 1.5 light tannish brown; quartz-rich very mod 90% mod yellow '~ ~ sandstone; very-fine grained (vfU); light strng,¢~ occasional fine -med black chert; well brown sorted; glauconite 1-3%; moderately well indurated; subangular to subrounded grains; visible porosity 7400.0 1.4 light tannish brown; quartz-rich very mod 80% mod yetlo.'..~.~ sandstone; very-fine grained (vfL-U); light ",'/ ' "'~:~i~ well sorted; glauconite 1-3%; trace brown .... ' ._ ~ black chert; moderately well indurated; .... subangular to subrounded grains; visible porosity 7397.0 1.4 light tannish brown; quartz-rich very mod 80% strng yellow sandstone; very-fine grained (vfL); well light sorted; glauconite 1-2%; trace black brown chert; moderately well indurated; subangular to subrounded grains; some visible porosity 7394.1 1.4 light tannish brown, slight color very mod 90% strng yellow mottling; quartz-rich sandstone; very- light FiECE VEl; fine grained (vfL-U); well sorted; brown glauconite 1-3%; moderately well AU G 1 9 '1996 indurated; subangular to subrounded grains; some visible porosity Al{l~ka 0ii & Gas C0115, 7390.9 1.5 light tannish brown; quartz-rich very mod 80% strng yellow Afldl~ge sandstone; very-fine grained (vfL); light occasional fine grained (quartz); well brown sorted; glauconite 2-3%; moderately well indurated; subangular to subrounded grains; slight color mottling; some visible porosity 7385.1 1.4 light tannish brown; quartz-rich very mod 90% strng yellow sandstone; very.fine grained (vfL); well light strng + sorted; glauconite 1-2%; trace black brown chip chert; moderately well indurated; subangular to subrounded grains; ....... .' _ :1_ ! ....... .',L.. /'382.2 1.4 light tannish brown; quartz-rich very mod 80% strng yellow sandstone; very-fine grained (vfL);well light strng sorted; trace glauconite; moderately brown well indurated; subangular to subrounded grains; some visible porosity 7379 1.5 light tannish brown; quartz-rich very mod 80% strng yellow sandstone; very-fine to fine grained light strng (vfU - fL);well sorted;glauconite 1%; brown moderately well indurated; subangular to subrounded grains; some visible porosity 7375.8 1.5 light tannish brown; quartz-rich very mod 70% strng yellow sandstone; very-fine grained (vfL- light strng U);well sorted;glauconite 1%; trace brown black chert; moderately well indurated; subangular to subrounded grains; some visible porosity 7372.9 1.5 light tannish brown; quartz-rich very mod 75% strng yellow sandstone; very-fine grained (vfL- light strng U));well sorted;glauconite1%; brown moderately well indurated; subangular to subrounded grains; some visible porosity Remarks Described by Greg Wilson AR3B-2389-B ,,~CO Alaska, Inc; ' Sidewall Core Description Operator and Well Name Page of ARCO Bergschrund #2A (RSWC Run #1) I 4 Location Dat e3/31/96 Shot 26 Recovered 26 Depth Rec. Description Oil Odor Oil Fluor Cut Cut Show ft. in. Stain % IntensitColor color fluor color sum Y 7451.0 0.8 light tannish brown; quartz-rich very mod 80% strng yellow sandstone; very-fine grained (vfL), well light strng sorted; glauconite 2-3%; well brown indurated; subrounded grains; visible porosity 7448.0 0.95 light tannish brown; sandstone; very- very mod 80% strng yellow fine grained (vfL); rare medium grained light strng (mL) (quartz and chert), well sorted; brown quartz-rich; glauconite 2-3%; well indurated; subangular grains; visible porosity 7444.7 0.9 light tannish brown; quartz-rich very mod 75% strng yellow sandstone; very-fine grained (vfL); rare light strng medium grained (mL) (quartz and brown chert); well sorted; glauconite 3%; moderately well indurated; subangular to subrounded grains; visible porosity 7442.0 1.0 light tannish brown; quartz-rich very strng 95% strng yellow sandstone; very-fine grained (vfL); light occasional fine grained (quartz); well brown sorted; glauconite 1%; moderately well indurated; subangular to subrounded grains; visible porosity 7439.0 1.1 light tannish brown; quartz-rich very mod 60% strng yellow sandstone; very-fine grained (vfL); light strng occasional fine grained (quartz); well brown sorted; glauconite 1-2%; moderately well indurated; subangular to subrounded grains; some visible porosity 7438.8 1.5 light tannish brown, slight color very mod 60% strng yellow mottling; quartz-rich sandstone; very- light strng fine grained (vfL); occasional fine brown grained (quartz); well sorted; glauconite 1%; moderately well indurated; subangular to subrounded grains; some visible porosity 7436.0 1.8 light tannish brown; quartz-rich very mod 70% strng yellow sandstone; very-fine grained (vfL); light occasional fine grained (quartz); well brown sorted; glauconite 2-3%; moderately well indurated; subangular to subrounded grains; slight color mottling; some visible porosity /'432.7 1.7 light tannish brown; quartz-rich very mod 95% strng yellow sandstone; very-fine grained (vfL); well light strng sorted; trace glauconite; moderately brown well indurated; subangular to subrounded grains; remnant laminations; slight color mottling, possibly due to burrows; some visible porosity 7427.0 1.8 light tannish brown; quartz-rich very mod 70% strng yellow sandstone; very-fine grained (vfL); light strng occasional fine grains (darkchert);well brown sorted; trace glauconite; moderately well indurated; subangular to subrounded grains; faint laminations; slight color mottling, possibly due to burrows; some visible porosity 7424.1 1.8 light tannish brown; quartz-rich very mod 60% strng yellow sandstone; very-fine grained (vfL);well light strng sorted; glauconite 3-4%; moderately brown well indurated; subangular to subrounded grains; slight color mottling, possibly due to burrows; some visible porosity 7421.0 1.8 light tannish brown; quartz-rich very mod 70% strng yellow sandstone; very-fine grained (vfL);well light strng sorted;glauconite 3-4%; moderately brown well indurated; subangular to subrounded grains; slight color mottling, possibly due to burrows; faint laminations; some visible porosity 7417.9 1.8 light tannish brown; quartz-rich very mod 95% strng yellow sandstone; very-fine grained (vfL);well light strng sorted;glauconite 3-4%; moderately brown well indurated; subangular to subrounded grains; slight color mottling, possibly due to burrows; some visible porosity 7415.1 1.55 light tannish brown; quartz-rich very mod 75% strng yellow sandstone; very-fine grained (vfL);well light strng sorted;occasional fine grained (fU) brown quartz; glauconite 3-4%; trace black chert; moderately well indurated; subangular to subrounded grains; some visible porosity 7412.2 1.5 ight tannish brown; quartz-rich very mod 90% strng yellow sandstone; very-fine grained (vfL);well light strng sorted; glauconite 3-4%; trace black brown chert; moderately well indurated; subangular to subrounded grains; some visible porosity Described by Greg Wilson/Ken Helmold AR3B-2389-B .,~CO Alaska, Inc.' Operator and Well Name ARCO Bergschrund #2A (RSWC Run 2) Location CONFIDENTIAL Sidewall Core Description Page of 14 Date 3/31/96 Shot 25 Recovered 24 Depth Rec. Description Oil Odor Oil Fluor Cut Cut Show ft. in. Stain % IntensitColor color fluor color sum Y 7407.0 1.5 light tannish brown; quartz-rich very mod 90% strng yellow sandstone; very-fine grained (vfL); well light strng sorted; glauconite 1-3%; trace black brown chert; moderately well indurated; subangular to subrounded grains; some visible porosity; possibly faint laminations 7403.9 1.5 lighttannish brown; quartz-rich very mod 90% strng yellow sandstone; very-fine grained (vfL); well light strng sorted; glauconite 1-3%; trace black brown chert (most vf, rarely mL-U); moderately well indurated; subangular to subrounded grains; some visible porosity; faint laminations 7401.9 1.5 light tannish brown; quartz-rich very mod 80% strng yellow sandstone; very-fine grained (vfL); well light strng sorted; glauconite 1-3%; trace black brown chert (vfL-U); moderately well indurated; subangular to subrounded grains; some visible porosity; possibly faint laminations 7387.9 1.5 light tannish brown; quartz-rich very mod 80% strng yellow sandstone; very-fine grained (vfL); well light strng sorted; glauconite 1-3%; trace black brown chert (vfL-U, rarely mL); moderately well indurated; subangular to subrounded grains; some visible porosity; possibly faint laminations 7384.0 1.5 light tannish brown; quartz-rich very mod 70% strng yellow RECE! sandstone; very-fine grained (vfL); well light strng sorted; glauconite 1-3%; trace black brown chert (vfL-U, rarely mL-U); moderately 1 9 ;996. well indurated; subangular to subrounded grains; some visible porosity; possibly faint laminations · , 7380.8 1.5 lighttannish brown; quartz-rich very mod 70% strng yellow sandstone; very-fine grained (vfL); well light sorted; glauconite 1-3%; trace black brown chert (vfL-U); moderately well indurated; subangular to subrounded grains; some visible porosity; possibly faint laminations; 2mm ring of carbonaceous material? (no fluorescence of soft, black ring material) ,,, /380.0 1.5 light tannish brown; quartz-rich very mod 70% strng yellow sandstone; very-fine grained (vfL); well light sorted; glauconite 1-3%; trace black brown chert (vfL-U); moderately well indurated; subangular to subrounded grains; some visible porosity; possibly faint laminations 7377.0 1.4 light tannish brown; quartz-rich very mod 75% strng yellow sandstone; very-fine grained (vfL); well light strng sorted; glauconite 1-3%; trace black brown chert (vfL-U, rarely fU); moderately well indurated; subangular to subrounded grains; some visible porosity; possibly faint laminations 7373.9 1.3 light tannish brown; quartz-rich very mod 70% strng yellow sandstone; very-fine grained (vfL); well light strng sorted; glauconite 1-3%; trace black brown chert (vfL-U); moderately well indurated; subangular to subrounded grains; some visible porosity; possibly faint laminations; several very coarse (vcU) calcite crystals, mineral fluorescence 7372.0 1.45 light tannish brown; quartz-rich very mod 60% strng yellow sandstone; very-fine grained (vfL); well light strng sorted; glauconite 1-3%; trace black brown chert (vfL-U); moderately well indurated; subangular to subrounded grains; some visible porosity 7370.0 no No Recovery reco very Remarks Described by Greg Wilson AR3B-2389-B ARCO Alaska, Inc." ~ Sidewall Core Description Operator and Well Name Page of ARCO Bergschrund #2A (RSWC Run #2) I 4 Location Date Shot 25 Recovered 24 Depth Rec. Description Oil Odor Oil Fluor Cut Cut Show ft. in, Stain % Intensit Color color fluor color sum Y 7452.2 1.4 light tannish brown; quartz-rich very mod 80% strng yellow sandstone; very-fine grained (vfL-U); light well sorted; glauconite 1%; trace black brown chert; moderately well indurated; subangular to subrounded grains; some visible porosity 7448.9 1.1 light tannish brown; quartz-rich very mod 90% strng yellow sandstone; very-fine grained (vfL); well light sorted; glauconite 1%; trace black brown chert; moderately well indurated; subangular to subrounded grains; some visible porosity, faint laminations 7446.0 1.4 light tannish brown; quartz-rich very mod 75% strng yellow sandstone; very-fine grained (vfL-U); light strng well sorted; glauconite 1%; moderately brown well indurated; subangular to subrounded grains; visible porosity; faint laminations? 7443.0 1.6 light tannish brown; quartz-rich very strng 90% strng yellow sandstone; very-fine grained (vfL); well light sorted; glauconite 1%; moderately well brown indurated; subangular to subrounded grains; some visible porosity 7440.0 1.5 light tannish brown; quartz-rich very mod 80% strng yellow sandstone; very-fine grained (vfL); well light strng sorted; glauconite 1-2%; trace black brown chert; moderately well indurated; subangular to subrounded grains; some visible porosity 7436.9 1.5 light tannish brown; quartz-rich very mod 80% strng yellow sandstone; very-fine grained (vfL); well light strng sorted; glauconite 1%; moderately well brown indurated; subangular to subrounded grains; some visible porosity 7433.9 1.5 lighttannish brown; quartz-rich very mod 80% strng yellow sandstone; very-fine grained (vfL); rare light medium grained chert (mL); well brown sorted; glauconite 1-3%; moderately well indurated; subangular to subrounded grains; some visible porosity 7430.0 1.0 light tannish brown; quartz-rich very mod 80% strng yellow sandstone; very-fine grained (vfL); well light strng sorted; glauconite 1-2%; moderately brown well indurated; subangular to subrounded grains; remnant laminations?; some visible porosity /'426.0 1.5 light tannish brown; quartz-rich very mod 90% strng yellow sandstone; very-fine grained (vfL); well light strng sorted; glauconite 2-3%; rare black brown chert; moderately well indurated; subangular to subrounded grains; some visible porosity 7425.0 1.5 light tannish brown; quartz-rich very mod 80% bright yellow sandstone; very-fine grained (vfL);well light strng sorted; glauconite 1-2%; moderately brown well indurated; subangular to subrounded grains; faint laminations; some visible porosity 7419.1 1.5 light tannish brown; quartz-rich very strng 80% strng yellow sandstone; very-fine grained (vfU); light rare fine (fU) black chert; well brown sorted;glauconite 3-4%; moderately well indurated; subangular to subrounded grains; slight color mottling, possibly due to burrows; some visible porosity 7417.0 1.4 lighttannish brown; quartz-rich very mod 95% strng yellow frags sandstone; very-fine to fine grained light strng (vfU - fL);well sorted;glauconite 2-3%; brown moderately well indurated; subangular to subrounded grains; some visible porosity 7414.0 1.5 lighttannish brown; quartz-rich very mod 80% strng yellow sandstone; very-fine grained (vfL);well light strng sorted; glauconite 1-2%; trace black brown chert; moderately well indurated; subangular to subrounded grains; some visible porosity 7410.2 1.4 ighttannish brown; quartz-rich very mod 90% strng yellow sandstone; very-fine grained (vfL);well light strng sorted; glauconite 1-3%; trace black brown chert (vfL-U); moderately well indurated; subangular to subrounded grains; some visible porosity Remarks Described by Greg Wilson AR3B-2389-B CORE LABORATORIES BA~CROCK PROPERTIES ARC~~~, INC. BERGSCHRUND NO. 2A WELL FINAL REPORT Performed for: ARCO ALASKA, INC. 700 G Street, Rm: ATO1450 Anchorage, Alaska 99501 April 24, 1996 Performed by: Core Laboratories, Inc. Rock Properties Laboratory Dallas Advanced Technology Center Carrollton, Texas 75006 File: DAL-96098 The analyses, opinions or interpretations contained in this report are based upon obseB/ations and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed repre- sent the best judgment of Core Laboratories. Core Labors odes, however assumes no responsibility and makes no warranty or representations, express or implied, es to the productivity, proper operate. OhS, or prolitableness of any oil. gas, coal or other mineral, property, well or sand in connection with which such report is used or relied UDOn for any reason whatsoever. This report shall not be reproduced except in its entirety, without the written approval of Core Laboratories. · PETROLEUM SERVICES April 24, 1996 Ms. Rene Hannon ARCO Alaska, Inc. 700 G Street Rm: ATO1450 Anchorage, Alaska Subject: CMS-300TM Permeability and Porosity of Core Samples Bergschrund No. 2a Well File: DAL-96098 Dear Ms. Hannon, Please find enclosed the results of basic rock properties testing performed on fifty 15/16 inch diameter rotary core plug samples delivered to our laboratory for analysis. A description of laboratory procedures is included with the testing results. Preliminary data was provided by fax on April 11, 1996. The plug samples were returned to the client on April 24, 1996. We appreciate the opportunity to have been of service to ARCO Alaska, Inc. If you have any questions or if we may be of further assistance, please call us at (214) 466-2673. Sincerely, Daniel J. S~tt Rock Properties Laboratory Dallas Advanced Technology Center Core Laboratories, Inc. 1875 Monetary Lane, Carrollton, Texas 75006-7012, (214) 466-2673, Telex 163166, CORDAL UT, Fax (214) 323-3930 ARCO Alaska, Inc. File: DAL-96098 PROJECT PARTICIPANTS Basic Properties Data Evaluation Report Preparation JQ~ A. Kieschnick Daniel J. Scott Final Review Melanie F. Dunn Core Laboratories ARCO Alaska, Inc. File: DAL-96098 BASIC ROCK PROPERTIES Analytical Procedures Sample Preparation and Analysis , Fifty 15/16 inch diameter rotary samples were received for testing. Each sample was removed from its shipping bottle and dry trimmed to form a right cylinder plug. Forty-nine plugs were assigned sample numbers and checked for fluorescence, then weighed to 0.01 grams. Sample 27 contained only chips and was not analyzed further after describing. Each of the plug samples was loaded into a pre-boiled Dean-Stark apparatus for distillation to determine residual fluid saturations. The Dean-Stark glassware were sealed with Teflon tape to prevent leakage and capped with desiccant to prevent the introduction of condensed atmospheric water. Water volume in each Dean-Stark receiving tube was monitored during the toluene refluxing until stabilization. A wire was used to swab off any water droplets from the neck of the condenser. A record of time and water volumes was kept for each sample. Extraction time for each sample was approximately 30 hours. After Dean-Stark distillation the samples were placed in a vacuum oven at a temperature of 140°F for twenty-four hours. After the samples cooled, weights were determined. The length and diameter of each sample were measured with digital calipers. Grain volumes were measured in a matrix cup at ambient conditions by the AutoPorosimeterTM using Boyle's law, with helium as the gaseous medium. Grain density was calculated for each sample using the dry sample weight and grain volume data. During these procedures, exposure to the atmosphere was minimized to preclude absorption of moisture. Permeability and porosity were measured using the CMS-300TM at 800 psi confining stress. A standard system leak test of the CMS-300TM was performed before testing to ensure correct equipment operation. A calibrated, known volume check cylinder and a known permeability check plug were run with each carousel suite of samples. The Klinkenberg (slip corrected) permeability for each plug sample was determined as a function of pressure decay (helium blow-down). A reference cell of known volume charged the sample with helium. A downstream valve vented the sample to atmosphere, and the change in pressure with time was monitored. The multiple flow regime data allowed the determination of Klinkenberg permeability of the sample, a calculated air permeability (Kair), along with parameters helium slip factor (b) and the Forcheimer inertial resistance factor beta (~). Porosity for each plug sample was calculated using Boyle's law by the CMS-300zM with grain volume and pore volume by: Porosity, percent = Vp · 100 Vp + Vg Where: Vp = Pore volume at net confining pressure (cc) Vg = Grain volume (cc) Seven plugs were too short to be measured in the CMS-300. The sample porosity was calculated from their bulk volume and grain volume data. The permeability was measured using the steady-state permeameter (Autopermeameter'rM). Core Laboratories CMS-300 QUALITY CONTROL DATA Net Confining Stress: 800 psi QC Sample Porosity, fraction umber measured I actual RPD 25-5 99.9 1.000 0.1 QC Sample Permeability to Air, millidarcys Number measured I actual RPD 328B 7.21 7.25 0.6 RPD (relative percent difference) = absolute value ((actual value-measured value)/actual value * 100) Acceptance criteria for porosity = +/- 0.5 porosity units Acceptance criteria for permeability in this range = +/- 5% 25-5 pore volume = 3.204 Core Laboratories tO00.O, ~00.0 t0.0 0.t 0.0! 0.00~ 0.0 Penmeab & 1 1 ty vs. Porosity · ~ ~ Correlotton Coif.- 0.926 J ~0.0 .0 20.0 Boyle's Law Pooosity' % 800 psi Berggchrund No. 2A Flo~:o~y Cc)~es (7372.0-745~).2) - LEGEND - Colville Delta CORE ANALYSIS RESULTS(CMS-300 Hydrostatic Confinement) ARCO Alaska, Inc. File: DAL-96098 Bergschrund No.2a Well 11-April-1996 Colville Delta Exploration ,, Rotary Net Overburden Pressure: 800 psi Dean Stark Rotary Plug Permeability Grain Saturation Core Depth, Klinkenberg, I to Air, Porosity, Density, Oil I Water, Number feet millidarcys.I millidarcys percent gm/cc percent PVI percent PV Description I 7372.0 12.8 14.7 20.4 2.67 8.6 41.9 Sst 2 7372.9 13.8 15.7 20.8 2.66 20.3 53.4 Sst 3 7373.9 27.8. 30.9 22.4 2.65 19.0 31.0 Sst 4 7375.8 21.4 24.0 22.3 2.65 16.4 43.2 Sst 5 7377.0 6.99 8.30 19.9 2.67 21.7 43.1 Sst 6 7379.0 16.8 19.0 21.3 2.66 20.8 44.1 Sst 7 7380.0 10.1 11.7 20.9 2.65 23.2 41.1 Sst 8 7380.8 13.8 15.8 20.7 2.65 22.3 39.8 Sst 9 7382.2 18.6 21.0 21.6 2.65 37.1 32.3 Sst 10 7384.0 7.65 8.98 20.2 2.65 23.3 41.7 Sst 11 7385.1 * 9.41 19.5 2.66 28.0 44.2 Sst 12 7387.9 7.84 9.25 20.4 2.66 25.3 43.9 Sst 13 7390.9 17.2 19.4 21.8 2.65 18.3 44.9 Sst 14 7394.1 31.3 34.5 22.8 2.65 16.9 50.1 Sst 15 . 7397.0 4.93 5.91 19.2 2.65 15.1 46.9 Sst 16 7400.0 21.5 24.0 21.9 2.65 25.5 38.2 Sst 17 7401.9 10.3 11.8 20.0 2.65 25.4 38.9 Sst 18 7403.1 * 12.2 19.9 2.66 20.1 46.8 Sst 19 7403.9 7.33 8.63 19.5 2.65 26.2 41.8 Sst 20 7406.2 7.12 8.35 19.1 2.65 22.2 41.1 Sst 21 7407.0 7.35 8.57 19.2 2.65 29.6 38.2 Sst 22 7408.8 5.66 6.71 18.7 2.65 19.7 44.0 Sst 23 7410.2 24.0 26.7 22.3 2.66 18.6 42.4 Sst 24 7412.2 11.5 13.2 20.3 2.65 19.8 37.9 Sst 25 7414.0 4.38 5.33 19.1 2.66 24.0 42.6 Sst 26 7415.1 19.8 22.2 21.7 2.66 26.3 39.1 27 7417.0 gry-brn vf f gr slty glauc even brt gld fluor gry vf f gr slty arg glauc even gld fluor It gry-bm vf f gr slty arg glauc even brt fluor gry vf f gr slty glauc mott gld fluor gry vf f gr slty glauc mott yel fluor gry-brn vf f gr slty arg glauc mott dull gld fluor gry-bm vf f gr slty arg glauc mott dull gld fluor It brn-gry vf f gr slty arg glauc mott gld fluor gry-brn vf f gr arg slty glauc mott gld fluor gry-brn vf f gr arg slty glauc mott girl fluor gry-bm vf f gr v slty arg glauc mott gld fluor bm-gry vf f gr si arg si slty glauc mott gld fluor gry-brn vf f gr slty si arg glauc even dull gld fluor gry vf f gr slty si arg glauc even dull gld fluor gry-brn vf f gr slty sh lam glauc mott dull gld fluor gry-brn vf f gr glauc slty sh lam even dull gld fluor gry-bm vf f gr glauc slty arg even dull gld fluor gry-brn vf f gr slty arg glauc even dull gld fluor gry-brn vf f gr slty sh lam glauc mott gld fluor gry-brn vf f gr slty sh lam glauc dull mott gld fluor gry-brn vf f gr slty arg glauc even dull gld fluor gry-brn vf f gr slty sh lam glauc even dull gld fluor gry-brn vf f gr sh lam glauc even gld fluor gry-brn vf f gr slty sh lam glauc mott gld fluor gry-brn vf f gr slty sh lam glauc even gld fluor Sst gry-brn vf f gr glauc even gld fluor Rock Chips -- No Analysis Core Laboratories CORE ANALYSIS RESULTS(CMS-300 Hydrostatic Confinement) ARCO Alaska, Inc. Bergschrund No.2a Well Colville Delta Exploration File: DAL-96098 11 -April- 1996 Rotary Net Overburden Pressure: 800 psi Dean Stark Rotary Plug Permeability Grain Saturation Core Depth, Klinkenberg, I to Air, Porosity, Density, Oil I Water, Number feet millidarcysI millidarcys percent gm/cc percent PVI percent PV Description 28 7417.9 16.4 18.5 20.3 2.66 25.7 39.7 Sst 29 7419.1 20.7 23.1 21.4 2.66 26.9 38.5 Sst 30 7421.0 27.4. 30.3 22.6 2.65 28.0 36.8 Sst 31 7424.1 5.69 6.80 19.7 2.65 21.8 36.0 Sst 32 7425.0 11.5 13.2 19.9 2.65 3.3 52.1 Sst 33 7426.0 4.18 5.10 18.2 2.65 37.4 29.2 Sst 34 7427.0 31.6 35.0 22.1 2.66 29.6 37.1 Sst 35 7430.0 8.51 10.0 20.5 2.65 24.9 41.8 Sst 36 7432.7 4.14 5.08 18.9 2.65 30.2 36.2 Sst 37 7433.9 5.62 6.77 20.5 2.65 26.0 38.6 Sst 38 7436.0 5.19 6.24 19.0 2.65 24.5 39.9 Sst 39 7436.9 13.2 15.1 20.7 2.65 24.5 43.0 Sst 40 7438.8 5.18 6.21 18.7 2.65 26.5 41.4 Sst 41 7439.0 7.01 8.24 19.7 2.66 22.9 42.9 Sst 42 7440.0 6.00 7.15 19.4 2.66 39.3 31.4 Sst 43 7442.0 * 8.22 20.5 2.65 22.8 27.9 Sst 44 7443.0 7.49 8.84 20.1 2.66 22.1 49.5 Sst 45 7444.7 * 9.67 19.6 2.65 16.5 48.8 Sst 46 7446.0 12.8 14.5 20.0 2.66 14.3 36.8 Sst 47 7448.0 * 10.9 19.4 2.65 15.8 44.6 Sst 48 7448.9 * 12.1 21.2 2.65 17.4 44.2 Sst 49 7451.0 * 8.09 19.4 2.66 15.4 64.3 Sst 50 7452.2 20.8 23.3 20.7 2.66 18.1 47.1 Sst * Permeability measured with the steady-state instrument. brn-dk gry vf f gr slty glauc even gld fluor brn-gry vf f gr slty glauc even gld fluor brn-gry vf f gr v slty glauc mort gld fluor brn-gry vf gr v slty glauc even dull yel gld fluor gry vf f gr v slty sh lam glauc even dull gld fluor gry-brn vf f gr si slty si arg glauc even dull gld fluor gry-brn vf f gr si slty glauc even gld fluor brn-gry vf f gr slty sh lam glauc gld strk fluor brn-gry vf gr v slty sh lam glauc even dull gld fluor brn-gry vf f gr v slty si arg glauc even dull gld fluor gry vf f gr v slty si arg glauc spt dull gld fluor gry-brn vf f gr v slty si arg glauc mort dull gld fluor brn-gry vf gr v slty si arg glauc dull mort gld fluor brn-gry vf f gr v slty si arg glauc dull gld fluor brn-gry vf f gr slty si arg glauc dull mort gld fluor brn-gry vf gr v slty si arg glauc dull mort gld fluor brn-gry vf f gr slty sh lam glauc spt yel-gld fluor brn-gry vf f gr v slty si arg glauc mott gld fluor brn-gry vf gr v slty arg glauc dull gld fluor gry-brn vf f gr v slty glauc mort gld fluor gry-brn vf f gr v slty arg glauc mort yel fluor gry-brn vf f gr slty si arg glauc mort yel fluor brn-gry vf f gr si slty si arg glauc mott yel fluor Core Laboratories CONFIDENTIAL per AOGCC reg. 20 AAC 25.537 ARCO ALASKA INC. Bergschrund No. 2A Section 9-Il 1N-R5E UM Wildcat Colville Delta Nodh Slope, Alaska Epoch Well Logging, Inc. ~A ~ E OF ~ON~EN~$ 1. Well Resume 2. Daily Chronology 3. Daily Activillf Summary Mud Record 5. Bit Record 6. Deviation Survey Record l. Morning Repods 8. Drilling Curve 9. Rig Acivity 10. Formation Log - MD 11. Formation Log - TVD 12. Drilling Dynamics Log 13. MWD Combo Log WELL RES Uk4E OPERATOR: WELL NAME: LOCATION: FIELD: COORDINATES: ELEVATIONS: COUNTY: STATE: APl INDEX: SPUD DATE: TOTAL DEPTH: COMPLETION DATE (T.D.): CONTRACTOR: RIG RIG TYPE: MUD PUMPS: COMPANY GEOLOGISTS: COMPANY ENGINEERS: TOOLPUSHERS: MUD COMPANY: MUD TYPES: HOLE SIZES: CASING DATA: MUDL~ING SERVICES: TYPE UNIT: UNIT LOGGING GEOLOC~iSTS: SAMPLE TEC:HNICIANS: ELECTRIC: LOC~S BY: LOG INTERVALS: DST INTERVALS: CORED INTERVALS: CORING COMPANY: WELL STATUS: ARCO ALASKA INC. BE~HRUND NO. 2A SEC. 9 T11N RSE, UM COLVILLE DELTA 964' FNL, 1370' FWL 42.0' AMSL NORTH SLOPE BOROUGH ALASKA 50-103-20232-O1 MARCH 24, 1996 7896' MARCH 30, 1996 DOYON DRILLING COMPANY NO. 141 SCR DIESEL-ELECTRIC (2) NATIONAL Al 700 (6'X 12") RENEE HANNAN, GREG WILSON BILL PENROSE ! DONNIE LUTRICK CHUCK S. CHE'VE / DARRELL GREEN BAROID DRILLING FLUIDS, INC. SPUD TO 1846' J LSND TO 7896' TD 2D" TO 107", 12 1/4" TO 1846', 8 1/2" TO 7896' 16" AT lOT, 9 5/8" AT 182T EPOCH WELL LOGGING, INC. (FID)GAS DETECI'~ON DML/RIGWATCH/RIGTRAK JOHN MORRIS, LEES F. BROWNE DAVE ROSCOE, BRAD GREEN ,SCHLUMBERGER NO DOPE NONE NONE NONE NO DOPE. TIGHT HOLE DAILY CHRONOLOGY BERO$CHRUND NO. 3-25-96: 3-26-96: 3-27-96: 3-28-96: 3-29-96: 3-30-96: 3-31-96: Nipple up BOPE. Make up BHA and RIH. Tag cement at 1012'. Circulate diesel out. Drill soft cement to 1600'. Drill hard cement from 1600' to 1757', Drill cement to 1800'. Circulate and reciprocate pipe. Pump 40 barrel spacer and displace with 10 ppg mud. POOH. Change out Ioadcell from tie down. Pick up BHA and RIH. Drill from 1800' to 1948'. Time drill for kick off from 1948' to 1979'. Directional drill from 1979' to 2570'. Drill from 2570' to 2726'. Make a 10 stand wiper trip with 30 to 50 Mbs overpull between 2050' and 1850'. Drill to 3690' and make a 11 stand wiper trip with 50 klbs overpull between 3170' and 3080' and between 2860' and 2800'. Wash from 3640' to 3690'. Drill ahead from 3690' to 3898'. Drill from 3898' to 4036'. POOH and change BHA. RIH and drill from 4036' to 5006', Circulate hole clean and make a wiper trip.. Drill from 5006' to 5162'. POOH to change bit and CDR tool. RIH and drill from 5162' to 5809'. Drill from 5809' to 6118'.. Make a wiper trip to 5050'. Drill ahead to 7111' and make a 11 stand wiper trip to 6040'. Drill from 7111' to 7239'. Drill ahead from 7239' to 7896'. Circulate bottoms up and wipe hole to shoe. Circulate and condition mud. Lost 60 barrels of mud in the upper part of the pay zone due to bit or stabilizers packing-off. POOH and rig up to run E-logs. DALLY ACTIVITY SUMMARY: RE-ENTRY TO T.D .............................................................................................................. ,~'~,rmI~, ,~l~[las~;a.., I1~,~=,. i ................................... ii ............................................................. ! ~ .......................................................... ............................................................................... ~ .................... ~ ........................ l' ......................................... I .................. ~ .................................. ~ ............... ~ ................ TOTAL I I~dRCHI,, '~ ~IB ~ C I ~ Other 14.5 10.5 ~ 4.0 . ~ ~ ~ ~ [ .............. .~9_~_~._~97..~.~ .................. ~68 2,.0'~ 2~.0 , 2~.0 ~2~.0 2~.0 2~.0 ~2~.0 ~ ', DAILY MUD REPORTS !, ,I I ~[ I ! ~. I t ~ ',~i, jFl~,[~;() ^IL.~CkS;I~;,A., IIINC.,j 'Mud Data Provided By: Well' I!J E IR Gi ~ C I~-I R I,J111~1 ID, ,J~ ~;~A BAROI D DATE DEPTH MW VIS PV YP GELS FL FC SOL SD MBT pH ~kLK. MU£ALK. FIL. el- Ca+ 3/25/96 1827 8.5 29 1 0 0/0 0 2 0.0 0 0.0 12.5 0 2.6/2.7 500 600.0 3/26/96 2543 10.0 45 17 20 5/7 6.0 2 7.1 TR 7.5 10.0 0 .2/.75 15800 80.0 3/27/96 3858 10.1 47 20 27 5/19 6.4 2 8.1 TR 12.5 9.0 0 .1/.55 15800 240,0 3/28/96 4960 10.0 48 15 28 19/33 12.6 2 8.2 1/8 12.5 8.5 0 .0/.4 14500 200.0 3/29/96 5790 10.2 43 14 23 6/23 10.4 2 11.1 1/8 13.7 8.8 0 .0/.4 17000 240.0 3/30/96 7112 10.1 46 25 19 5/16 5.4 2 11.0~.25 17.5 9.0 0 .0/.34 19000 80.0 3/31/96 7896 10.1 47 20 t6 4/7 4.8 2 11.8 .25 17.5 8.5 0 .0/.46 22000 40.0 BIT RECORD BIT # SIZE MAKEAND SERIAL JETS DEPTH DEPTH FEET ON BTIV AVG WOB BIT RPM PUMP PRES MUD MUD TYPE NUMBER IN OUT HOURS ROP Iow-hi,Ih-oval Iow-hi~lh-av~l Iow-hi,Ih-oval WT VIS DULL-GRADE .~. 1 R R 8.5 HYCA SX70B2F+GV 17754 6X10 CLEAN OUT CMT 10.0 45 NOT GRADED 2 8.5 HTC ATJP-05 B86XR 3X13 1800 4036 2236 22.4 99.8 1-28-15 49-546-321 1457-2836-2259 10.0 48 1-1-WT-A-E-I-NO-HR 3 8.5 HTC G417G 1900315 6X10 4036 5162 1126 10.2 110.3 1-45-16 213-329-296 2622-3694-3257 10.2 43 1-1 -WT-A-X-I-NO- P R 4RE 8.5 HYCA SX70B2F+GV 17754 6X10 5162 7896 2734 22.3 122.6 1-35-14 190-482-314 2016-3780-3144 10.1 47 2-1-WT-A-X-I-LT,BT=ER-T D ,,, Epoch Well Logging, Inc. · · · . e ARCO ALASKA INC. BER~SC.HRUND NO. 2,1c SURVEY RECORD .-. ....- ...- ""^ ......... ._ _ _. n,_.~u"", ..,.""". ~ MEASURED INCLINATION AZIMUTH VERTICAL LATITUDE DEPARTURE DEPTH DEPTH N/S, +1- EIW, +1- (FEETi (DEGREE) (DEGREE) (FEET) (FEET) (FEET) 1903.00 0.38 0.49 1902.25 9.4 2.14 1997.30 1.01 189.66 1997.25 9.4 2.14 2089.48 3.81 183.94 2089.34 5.54 1.79 2182.99 5.93 182.62 2182.51 -2.39 0.35 2274.77 8.38 182.61 2273.57 -13.90 0.51 2367.43 11.14 181.57 2364.86 -29.67 0.28 2460.12 13.1 175.04 2455.48 -49.18 0.92 2551.99 15.29 168.48 2544.54 -51.44 4.24 2644.62 17.21 166.08 2633.46 -96.61 10.00 2736.14 19.39 164.54 2730.34 -124.40 17.30 2831.13 22.47 164.62 2809.05 -157.13 26.26 2922.77 25.28 163.21 2892.85 -192.77 36.61 3013.31 28.32 163.56 2973.65 231.88 48.17 3107.06 30.60 163.32 3055.28 -276.07 61.32 3200.30 33.14 162.91 3134.46 -323.18 75.62 3292.27 36.93 163.15 3209.74 -373.66 91.03 3388.25 39.40 162.61 3283.63 -429.16 108.13 3480.25 40.16 162.62 3355.87 -486.57 126.10 3573.17 40.05 164.21 3426.94 -543.92 143.19 3760.56 38.86 166.62 3571.64 659.14 173.19 3855.27 38.17 167.66 3645.74 -716.63 156.32 3947.49 37.09 170.82 -771.92 196.85 10.04 4040.85 39.19 170.32 3792.23 -628.32 206.30 4131.85 39.66 172.67 3862.50 -885.95 214.83 4226.92 39.82 173.11 3935.61 -946.28 222.20 4317.05 40.92 169.12 4004.29 -1003.95 231.09 4410.14 43.14 166.84 4073.44 -1064.89 244.09 4605.32 42.74 165.10 4216.38 -1193.78 276.48 4690.44 42.63 168.15 4278.94 -1250.03 289.31 * The directional survey printed in this report is not for Bergschrund # 2A. This is the Bergschrund # 2 survey. ii i i i iiii i i i i i i i i ARCO ALASKA INC. SURV :Y RECORD BERGSCHRUND NO. MEASURED INCLINATION AZIMUTH VERTICAL LATITUDE DEPARTURE DEPTH DEPTH N/S, +/- ENV, +/- (F,,EET) (.DEGREE) (DEGREE) (FEET) (FEET) (FEET) 1903.00 0.38 0.49 1902.25 9.4 2.14 1997.30 1.01 189.66 1997.25 9.4 2.14 2089.48 3.81 183.94 2089.34 5.54 1.79 2182.99 5.93 182.62 2182.51 -2.39 0.35 2274.77 8.38 182.61 2273.57 -13.90 0.51 2367.43 11.14 181.57 2364186 -29.67 0.28 2460.12 13.1 175.04 2455.48 -49.18 0.92 ,, 2551.99 15.29 168.48 2544.54 -51.44 4.24 2644.62 17.21 166.08 2633.46 -96.61 10.00 2736.14 19.39 164.54 2730.34 -124.40 17.30 2831.1 3 22.47 164.62 2809.05 -157.13 26.26 2922.77 25.28 163.21 2892.85 -192.77 36.61 3013.31 28.32 163.56 2973.65 231.88 48.17 , , , 3107.06 30.60 163.32 3055.28 -276.07 61.32 3200.:30 33.14 162.91 3134.46 -323.18 75.62 3292.27 36.93 163.15 3209.74 -373.66 91.03 3388.25 39.40 162.61 3283.63 -429.16 108.13 3480.25 40.16 162.62 3355.87 -486.57 126.10 3573.17 40.05 164.21 3426.94 -543.92 143.19 3760.56 38.86 166.62 3571.64 659.14 173.19 ,,, 3855.27 38.17 167.66 3645.74 -716.63 156.32 3947.49 37.09 170.82 -771.92 196.85 10.04 4040.85 39.19 170.32 3792.23 -628.32 206.30 4131.85 39.66 172.67 3862.50 -885.95 214.83 4226.92 39.82 173.11 3935.61 -946.28 222.20 4317.05 40.92 169.12 4004.29 -1003.95 231.09 4410.14 43.14 166.84 4073.44 -1064.89 244.09 4605.32 42.74 165.10 4216.38 -1193.78 276.48 4690.44 42.63 168.15 4278.94 -1250.03 289.31 i ii i i ARCO ALASKA INC. SURVEY RECORD BERGSCHRUND NO. 2A MEASURED INCLINATION AZIMUTH VERTICAL LATITUDE DEPARTURE DEPTH DEPTH N/S, +/- Eh/V, +/- (FEET) (DEGREE) (DE .G,.REE). . (FEET) .. (FEET) (FEEI'~ 4782.16 42.80 166.81 4346.34 -1319.52 303.86 4875.60 42.74 165.85 4414.95 -1372.20 318.85 4968.85 40.95 165.02 4484.41 -1432.44 334.49 ...... 5063.55 40.42 165.04 4556.19 -1492.03 :350.43 5156.81 39.18 168.00 4627.85 '1550.06 364.37 5254.:37 38.62 167.94 4703.8:3 -1609.91 377.12 ,,_ 5343.68 38.38 169.81 4773.78 -1664.41 387.84 5436.61 38.37 170.42 4846.55 -1721.18 397.73 5531.98 38.29 170.98 4921.44 -1779.61 407.30 5625.93 38.98 173.22 4994.85 -1837.65 415.87 5718.05 38.63 172.41 5067.36 -1895.34 423.68 · 5812.00 '38.09 172.41 5140.71 -1952.29 431.31 · , 5906.41 38.61 170.39 5214.42 -2010.44 440.04 6000.02 39.43 169.32 5287.15 -2068.45 450.42 6094.38 40.85 168.51 5359.29 -2128.14 462.12 6188.26 41.55 167.32 5429.92 -2188.61 475.07 6283.16 41.14 167.11 5502.04 488.95 -626.25 6376.17 40.74 166.10 5571.42 -2309.04 503.07 6470.72 40.47 166.41 5643.20 -2368.81 517.69 6561.55 40.02 165.63 5712.53 -2425.76 531.86 6653.68 39.39 165.82 5783.40 -2482.80 546.37 ,, ,, , 6749.29 39.28 165.60 5857.35 -2541.54 561.34 6843.47 39.01 164.84 5930.39 -2599.00 576.50 6936.85 39.02 165.19 6004.51 -2667.02 592.02 7121.04 39.37 164.48 6145.97 -2787.65 622.68 7214.90 39.13 163.58 6218.69 -2824.74 639.02 7307.00 38.93 164.06 6290~ 20 -2880.45 655.19 7401.05 38.22 163.97 6363.72 -2936.53 672.31 ARCO LASKA INC. SURVEY RECORD BERGSCHRUND NO. 2A MEASURED INCLINATION AZIMUTH VERTICAL LATITUDE DEPARTURE DEPTH DEPTH N/S, +/- ENV, +/- (FE, ET) ,,,(DE,,,GR, E,E) (DEGREE) , (FEET), (,F, EET~, (FEET) , 7496.03 38.11 163.54 6438.42 -2992.60 689.71 7590.17 37.77 163.49 6512.64 -3048.09 706.13 7683.81 36.49 162.85 6587.31 -3102.18 722.49 7778.75 35.08 162.77 6664.33 -3155.19 738.89 7872.33 33.95 162.58 6741.45 -3205.81 754.64 7967.12 33.28 162.70 6820.40 -3255.90 770.25 8060.53 32.38 161.97 6898.89 -3304.14 785.60 ,, 8154.57 32.03 162.29 6978.48 -3351.83 800.98 8427.28 32.31 161.90 7056.95 -3398181 816.16 8342153 32.48 162.81 7137.38 -3447.44 831.63 8436.84 32.77 161.64 7216.60 -3495.89 847.07 , 8486.73 32.74 161.13 7258.76 -3521.49 855.64 8580.00 32.74 161.13 7337.21 -3569.22 871.95 E: )CH WELL LOGGING, L ,C. MORNING REPORT ARCO ALASKA INC. BERGSCHRUND #2A Date: 3-25-96 05:00 Depth: 1757' (TD) YESTERDAY: 1012' Last Casing: 9 5/8" at 1826' 24 Hour Progress: 745' BIT INFORMATION: No. Size Type S/N Jets Interval 1RR 8.5" HYCA SX70 17754 6X10 1012'-1757' DRILLING PARAMETERS: HIGH LOW Rate of Penetration at ' at Torque at ' at Weight on Bit at ' at Rotary RPM at ' at Pump Pressure at ' at Ftg Hours Condition 745' 5.9 IN HOLE (CEMENT) AVERAGE ' ft/hr ' amp ' Klbs ' rpm ' psi DRILLING MUD REPORT: Report Depth: 1827' MW 8.5 VIS 29 PV 1 YP 0 GELS 0/0 FL 0 FC 2 SOL 0 OIL 0 SD 0 MBT 0 pH 12.5 Cl- 500 Ca+ 600 GAS SUMMARY: HIGH LOW AVERAGE Total Ditch Gas (units) at ' at ' units Total Cuttings Gas (units) at ' at ' units Methane (C-1) (ppm) at ' at ' ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4's) at at ppm P e nta n e (C-5's) at at p p m Background Gas: 5 units Trip Gas: units at ' Connection Gas: units Wiper Gas: units at ' LITHOLOGY:.No new hole. ACTIVITY SUMMARY: Nipple up BOPs, maku up BHA, mn in hole, tag cement at 1012', circulate diesel out, drill soft cement to 1600', drill hard cement to current TD. ESTIMATED PoRE PRESSURE: 9.5 ppg Epoch Personnel on site: 4 SERVICES PROVIDED: DML MUDLOGGING Arco Reps: Bill Penrose/Donnie Lutrick Report By: John Morris -)CH WELL LOGGING, ,C. MORNING REPORT ARCO ALASKA INC. BERGSHCRUND #2A Date: 3-26-96 05:00 Depth: 2570' (-I'D) YESTERDAY: 1757' Last Casing: 9 5/8" at 1826' 24 Hour Progress: 813' BIT INFORMATION: No. Size Type SIN Jets Interval 2 8.5" HTC P05 B86XR 3X15 1800'-2570' Ftg Hours Condition 770' 9.9 IN HOLE DRILLING PARAMETERS: HIGH Rate of Penetration 488 at 2066' 28 Torque 90 at 2043' 0 Weight on Bit 28 at 2202' 3 Rotary RPM 546 at 2062' 268 Pump Pressure 2191 at 2373' 1817 LOW AVERAGE at 2177' 135 ft/hr at 2406' 68 amp at 2096' 16 Klbs at 2266' 323 rpm at 2108' 2001 psi DRILLING MUD REPORT: Report Depth: 2543' MW 10 VIS 45 PV 17 YP 20 GELS SOL 7.1 OIL 0 SD tr MBT 7.5 pH GAS SUMMARY: HIGH Total Ditch Gas (units) 488 at Total Cuttings Gas (units) 5 at Methane (C-1) (ppm) 85512 at Ethane (C-2) 2793 at Propane (C-3) 1711 at Butane (C-4's) 778 at Pentane(C-5's) 93 at LOW 2352' 11 2415' 1 2352' 2140 2353' 0 2653' 0 2353' 0 2353' 0 Background Gas: 35 units Connection Gas: 0-215 units 5/7 FL 6 FC 2 10 CI- 15800 Ca+ 80 AVERAGE at 2255' 41 units at 2360' 1.5 units at 2255' 7793 ppm at 2339' 133 ppm at 2339' 57 ppm at 2339' 28 ppm at 2415' 2 ppm Trip Gas: 3 units at 1800' Wiper Gas: units at ' LITHOLOGY:.40% shale, 50% claystone, 10% tuff ACTIVITY SUMMARY:Drill cement to 1800', circulate and reciprocate pipe, pump 40 bbl spacer, displace with 10 ppg mud, pull out of hole. Change out loadcell from tie down, pick up BHA, run in hole, drill from 1800' to 1948'. Time drill for kick offfrom 1948' to 1979'. Directional drill to current T.D. ESTIMATED PORE PRESSURE: 9.5 ppg REMARKS: Connection gases appear to be coming from 2350' to 2450'. Epoch Personnel on site: 4 SERVICES PROVIDED: DlVlL MUDLOGGING Arco Reps: Bill Penrose/Donnie Lutrick Report By: John Moms E_ 3CH WELL LOGGING, MORNING REPORT ARCO ALASKA INC. BERGSHCRUND #2A Date: 3-27-96 05:00 Depth: 3898' (TD) YESTERDAY: 2570' Last Casing: 9 5/8" at 1826' 24 Hour ProgreSs: 1328 ' BIT INFORMATION: No. Size Type SIN Jets Interval 2 8.5" HTC P05 B86XR 3X15 1800'-3898' Ftg Hours Condition 2098' 21.0 IN HOLE DRILLING PARAMETERS: HiGH Rate of Penetration 293 at 3322' 19 Torque 133 at 3710' 0 Weight on Bit 26 at 2829' 2 Rotary RPM 442 at 3226' 85 Pump Pressure 2595 at 3800' 62 LOW at 2636' at 3122' at 3290' at 3691' at 3691' AVERAGE 147 fi/hr 89 amp 15 Klbs 350 rpm 2276 psi DRILLING MUD REPORT: Report Depth: 3858' MW 10.1 VIS 47 PV 20 YP 27 GELS SOL 8.1 OIL 0 SD tr MBT 12.5 pH 5/19 FL 9 CI- GAS SUMMARY: HiGH LOW Total Ditch Gas (units) 405 at 3067' 15 at 2991' Total Cuttings Gas (units) 28 at 2780' 1 at 2660' Methane (C-1) (ppm) 76641 at 3067' 2680 at 2991' Ethane (C-2) 2651 at 2426' 113 at 2991' Propane (C-3) 897 at 3102' 29 at 2563' Butane (C-4's) 588 at 3123' 0 at 3454' Pentane(C-5's) 172 at 3091' 0 at 3800' Background Gas: 50 units Tdp Gas: Connection Gas: 20-315 units Wiper Gas: 6.4 FC 15800 Ca+ 2 240 AVERAGE 62 units 9 units 10598 ppm 513 ppm 172 ppm 67 ppm 2 ppm units at 467 units at 620 units at 2726' 3690' LITHOLOGY:.60% CLAYSTONE, 20% SHALE, 10% SILTSTONE, 10% TUFF ACTIVITY SUMMARY: Drill to 2726', wipe hole 10 stands, 30 to 50 klbs overpull between 2050' and 1850'. Drill to 3690', wipe hole l 1 stands, 50 klbs overpull between 3170' and 3080' and between 2860' and 2800'. Wash 3640' to 3690'. Drill 3690' to current T.D. ESTIMATED PORE PRESSURE: 9.7 ppg Epoch Personnel on site: 4 SERVICES PROVIDED: DML MUDL(3GGING Arco Reps: Bill Penrose/Donnie Lutrick Report By: John Morris L_ OCH WELL LOGGING, MORNING REPORT ARCO ALASKA INC. BERGSHCRUND #2A Date: 3-28-96 05:00 Depth: 5006' ('I'D) YESTERDAY: 3898' Last Casing: 9 5/8" at 1826' 24 Hour Progress: 1108' BIT INFORMATION: No. Size Type S/N 2 8.5" HTC P05 B86XR 3 8.5" .HTC G417G .1900315 DRILLING PARAMETERS: HIGH Rate of Penetration 387 at Torque 151 at Weight on Bit 30 at Rotary RPM 506 at Pump Pressure 3694 at Jets Interval 3X15 1800'-4036' 6X10 4036'-5006' 4286' 15 4905' 0 4908' 2 3991' 213 4670' 2073 Ftg Hours Condition 2236' 25 1-1-W'I'-A E-I-NO-HR 970' 6.5 IN HOLE LOW AVERAGE at 3896' 199 ft/hr at 4871' 109 amp at 4071' 14 Klbs at 4861' 307 rpm at 4352' 3148 psi DRH~LING MUD REPORT: Report Depth: 4960' MW 10.0 ViS 48 PV 15 YP 28 GELS SOL 8.2 OIL 0 SD 1/8 MBT 12.5 pH GAS SUMMARY: HIGH Total Ditch Gas (units) 495 at Total Cuttings Gas (units) 60 at Methane (C-1) (ppm) 82303 at Ethane (C-2) 3938 at Propane (C-3) 2477 at Butane (C-4's) 1606 at Pentane(C-5's) 556 at LOW 4159' 23 4220' 1 4159' 3366 4189' 201 4248' 65 4248' 0 4253' 0 Background Gas: 50 units Connection Gas: 30 - 250 units 19/33 FL 12.6 FC 2 8.5 CI- 14500 Ca+ 200 AVERAGE at 4414' 140 units at 4935' 21 units at 4414' 22062 ppm at 4899' 1305 ppm at 4899' 653 ppm at 4935' 418 ppm at 4935' 150 ppm Trip Gas: 1265 units at 4036' Wiper Gas: units at ' LITHOLOGY:.70% Claystone, 20% Shale, 10% Siltstone ACTIVITY SUMMARY:Drill to 4036', pull out of hole, change BHA, run in hole, drill to 5006', circulate hole clean, wipe hole. ESTIMATED PORE PRESSURE: 9.7 ppg Epoch Personnel on site: 4 SERVICES PROVIDED: DML MUDLOGGING Arco Reps: Bill Penrose/Donnie Lutrick Report By: John Moms E_ '3CH WELL LOGGING, f"JC. MORNING REPORT ARCO ALASKA INC. Date: 3-29-96 05:00 Depth: 5809' ('I'D) YESTERDAY: 5006' BIT INFORMATION: No. Size Type S/N Jets 3 8,5" .HTC G417G .1900315 6X10 4RR 8.5" .HYCA SX70 .17754 6X10 DRILLING PARAMETERS: HIGH Rate of Penetration 459 at 5691' Torque 202 at 5698' Weight on Bit 45 at 5034' Rotary RPM 353 at 5240' Pump Pressure 3632 at 5361' DRILLING MUD REPORT: Report Depth: MW 10.2 ViS 43 PV 14 YP SOL 11.1 OIL 0 SD 1/8 MBT GAS SUMMARY: HIGH Total Ditch Gas (units) 160 at Total Cuttings Gas (units) 19 at Methane (C-1) (ppm) 27649 at Ethane (C-2) 1400 at Propane (C-3) 589 at Butane (C-4's) 218 at Pentane(C-5's) 107 at BERGSHCRUND #2A Background Gas: 60 units Connection Gas: 0-130 units Last Casing: 9 5/8" at 1826' 24 Hour Progress: 803' Interval Ftg Hours 4036'-5162' 1126' 10.2 5162'-5806' 644' 4.6 LOW 16 at 5384' 0 at 5413' 2 at 5444' 91 at 5163' 94 at 5163' Condition NA IN HOLE AVERAGE 163 ft/hr 140 amp 14 Klbs 324 rpm 3323 psi 5790' 23 GELS 6/23 FL 10.4 FC 2 13.7 pH 8.8 CI- 17000 Ca+ 240 LOW AVERAGE 5464' 17 at 5474' 64 units 5360' 1 at 5530' 9 units 5464' 2918 at 5474' 10941 ppm 5464' 164 at 5474' 624 ppm 5163' 59 at 5474' 231 ppm 5688' 0 at 5388' 60 ppm 5464' 0 at 5710' 2 ppm Trip Gas: 1040 units at 5162' Wiper Gas: units at ' LITHOLOGY:.60% claystone, 20% shale, 10% siltstone, 10% sandstone ACTI¥1TY SUMMARY:Drill 5006' to 5162', pull out of hole, change bit and CDR tool, run in hole, drill 5162' to current T.D. ESTIMATED PORE PRESSURE: 9.7 ppg REMARKS: SERVICES PROVIDED: DML MUDLOGGING Epoch Personnel on site: 4 Arco Reps: Bill Penrose/Donnie Lutrick Report By: John Morris .)CH WELL LOGG1NG, ,._ MORNING REPORT ARCO ALASKA INC. Date: 3-30-96 05:00 Depth: 7239' ('TD) YESTERDAY: 5809' BIT INFORMATION: No. Size Type SIN 4RR 8.5" .HYCA SX70 .17754 Jets 6X10 DRILLING PARAMETERS: HIGH Rate of Penetration 474 at Torque 232 at Weight on Bit 27 at Rotary RPM 482 at Pump Pressure 3780 at 5845' 6092' 6281' 5798' 5846' DRILLING MUD REPORT: MW 10.1 VIS 46 PV SOL 11 OIL 0 SD Report Depth: 25 YP .25 MBT GAS SUMMARY: HIGH Total Ditch Gas (units) 284 at Total Cuttings Gas (units) 160 at Methane (C-1) (ppm) 45114 at Ethane (C-2) 2801 at Propane (C-3) 2561 at Butane (C-4's) 1684 at Pentane(C-5's) 374 at Interval 5162'-7239' BERGSHCRUND #2A Last Casing: 9 5/8" at 1826' 24 Hour Progress: 1430' Ftg Hours Condition 2077' 14.8 IN HOLE LOW 13 at 5799' 0 at 6411' 1 at 5753' 190 at 6407' 2319 at 6149' AVERAGE 205 fi/hr 168 amp 15 Klbs 313 rpm 3162 psi 7112' 19 GELS 5/16 FL 5.4 FC 17.5 pH 9.0 Cl- 19000 Ca+ 2 80 LOW AVERAGE 5776' 16 at 6342' 66 units 6590' 1 at 7020' 15 units 5776' 2504 at 6631' 10102 ppm 6581' 174 at 6342' 768 ppm 6581' 66 at 6342' 399 ppm 6610' 0 at 6405' 208 ppm 6581' 0 at 7020' 19 ppm Background Gas: 50 units Trip Gas: units at ' Connection Gas: 0-55 units Wiper Gas: 320 units at 7111' LITHOLOGY:. 100% SHALE ACTIVITY SUMMARY: Drill to 6118', wipe hole to 5050', drill to 7111', wipe hole 11 stands, drill to current T.D. ESTIMATED PORE PRESSURE: 9.7 ppg REMARKS: Epoch Personnel on site: 4 SERVICES PROVIDED: DML MUDLOGGING Arco Reps: Bill Penrose/Donnie Lutrick Report By: John Moms El: WELL LOGGING, MORNING REPORT ARCO ALASKA INC. BERGSHCRUND #2A Date: 3-31-96 05:00 Depth: 7896' (TD) YESTERDAY: 7239' Last Casing: 9 5/8" at 1826' 24 Hour Progress: 657 BIT INFORMATION: No. Size Type SIN Jets Interval 4RR 8.5" .HYCA SX70 .17754 6X10 5162'-7896' Ftg Hours Condition 2734' 22.3 IN HOLE DRH~LING PARAMETERS: HIGH Rate of Penetration 466 at 7368' 25 Torque 211 at 7369' 128 Weight on Bit 26 at 7180' 1 Rotary RPM 351 at 7579' 256 Pump Pressure 3618 at 7370' 2016 LOW at 7527' at 7110' at 7525' at 7525' at 7522' AVERAGE 139 ft/hr 179 amp 15 Klbs 304 rpm 2961 psi DRILLING MUD REPORT: Report Depth: 7896' MW 10.1 ViS 47 PV 20 YP 16 GELS 4/7 SOL 11.8 OIL 0 SD .25 MBT 17.5 pH 8.5 GAS SUMMARY: HIGH Total Ditch Gas (units) 1165 at Total Cuttings Gas (units) 330 at Methane (C-1) (ppm) 123608 at Ethane (C-2) 13518 at Propane (C-3) 17733 at Butane (C-4's) 9644 at Pentane(C-5's) 3650 at LOW 7383' 10 at 7450' 0 at 7383' 1458 at 7383' 112 at 7383' 62 at 7383' 0 at 7387' 0 at Background Gas: 40 units Connection Gas: 0 units FL 4,8 FC 2 CI- 22000 Ca+ 40 AVERAGE 7795' 88 units 7834' 33 units 7795' 10654 ppm 7795' 1025 ppm 7795' 996 ppm 7855' 580 ppm 7890' 194 ppm Tdp Gas: units at ' Wiper Gas: 850 units at 7896' LITHOLOGY:.80% shale, 20% siltstone ACTIVITY SUMMARY: Drill to 7111', circulate bottoms up, wipe hole to 6040', drill to 7896', wipe hole to shoe, circulate and condition mud. Lost 60 bbls of mud in the upper part of'the pay zone due to bit or stabilizers packing-off. ESTIMATED PORE PRESSURE: 9.7 ppg REMARKS: SERVICES PROVIDED: DML MUDLOCK}ING Epoch Personnel on site: 4 Arco Reps: Bill Penrose/Donnie Lutrick Report By: John Moms ARCO ALASKA INC. BERGSCHRUND NO. 2A DRILLING TIME SCHEDULE DEPTH VS TIME DEPTH (THOUSANDS) 0 TOP CEMENT PLUG AT 1012' , -2_4 ...................................................................... LUG AT 1948 8 1/2" HOLE -6 RAN E-LOGS AT TOTAL DEPTH -8t ' ' '' ' ''' --= ..... / ~ TOTAL DEPTH: 789G' ~ .~^c.~D ~D o. ~-~ :o~ [ 1 0 0 1 2 3 4 5 6 7 8 9 10 11 12 3-25-96 to 3-31-96 DAYS EPOCH WELL LOGGING INC. ARCO ALAS~ BERGSCHRUND FOOTAGE BBB INC~ 1,600 1,400 1,200 1,000 8OO 600 4O0 2OO 0 0 2 4 6 8 10 EPOCH WELL LOGGING INC~ [BOP Testing/Rig. Up CircuCate 7% TriplBHA 26% Otb er 9% [] Drill/Core [] Trip/BHA !ID Circulate Drill/Core i[] BOP Testing/Rig-Up ~3% [] Other CONFIDENTIAL per AOGCC mC. 20 AAC 25,537 ARCO ALASKA INC. Bergschrund No. 2A Section 9-T11N-RSE UM Wildcat Coiviile Delta Norfh Slope, Alaska ., JUN O5 199G ~,a 0il & Gas Cons. Commission , ...A,.qch0rage Epoch Well Logging, Inc. ARCO ALASKA, INC. Bergschrund No. 2A Surface Well Test April 7 - April 13, 1996 RECEIVED JUL 2 3 199~ Wi ~ Gas CoDs, ~,'fimi~io~ .~.cborage I B U RTO N Halliburton Energy Services Phone Number: Facsimile Number: 6900 Arctic Blvd. Anchorage, Alaska 99518 (907) 344-2929 (907) 344-6746 Attention: Daniel Wuthrich James Mills Robert Richey HALLIBURTON HALLIBURTON ENERGY SERVICES Anchorage, Alaska CUSTOMER: WELL NUMBER: FIELD: AREA: TEST DATE: TEST NUMBER: ARCO Alaska, INC. Bergschrund No. 2A Coleville River Delta Prudhoe Bay, Alaska April 7 - April 13, 1996 Surface Test 1 HALLIBURTON report copies have been sent to the following companies and/or individuals: # COPIES RECIPIENT ARCO Alaska, INC. Attn: Tim Scarbrough T#040796 ARCO ALASKA, INC. Bergschrund No. 2a Surface Well Test April 7 - April 13, 1996 Initial Flow HALLIBURTON HALLIBURTON ENERGY SERVICES REPORT TICKET NO: MEMORY GAUGE TICKET NO: DATE: HALLIBURTON CAMP: TESTER: WITNESS: DRILLING CONTRACTOR: LEGAL LOCATION: OPERATOR: LEASE NAME: WELL NO: TESTED INTERVAL: 040796 07-Apr-96 Kenai Steve Myers Tim Scarbrough Wellhead Land ARCO Alaska, INC. Coleville River Bergschrund No. 2A 7368'- 7454' FIELD AREA: COUNTY/LSD: STATE/PROVINCE: COUNTRY: Coleville River Delta North Slope Alaska U.S.A NOTICE: THIS REPORT IS BASED ON SOUND ENGINEERING PRACTICES, BUT BECAUSE OF VARIABLE WELL CONDITIONS AND OTHER INFORMATION WHICH MUST BE RELIED UPON HALLIBURTON MAKES NO WARRANTY, EXPRESS OR INPLIED AS TO THE ACCURACY OF THE DATA OR OF ANY CALCULATIONS OR OPINIONS EXPRESSED HEREIN. YOU AGREE THAT HALLIBURTON SHALL NOT BE LIABLE FOR ANY LOSS OR DAMAGE, WHETHER DUE TO NEGLIGENCE OR OTHERWISE ARISING OUT OF OR IN CONNECTION WITH SUCH DATA, CALCULATIONS OR OPINIONS. TABLE OF CONTENTS SECTION 1' SECTION 2: SECTION 3: TEST SUMMARY & INFORMATION Sequence of Events Well Test Results Summary Well Test Separator Summary Well Test Summary Plots Pressure / Temperature History Plot Storage Tank Data Fluid Transfer Data Fluid Summary 1.1 2.1 3.1 4.1 5.1 6.1 7.1 8.1 MEMORY GAUGE DATA Gauge History Plot Gauge Data Listing 1.1 2.1 ASCII FILE DATA Halliburton Energy Services Sequence of Events Company: ARCO Alaska, INC. Well: Bergschrund Well No. 2A Test Number: Initial Test Company Rep: Tim Scarbrough Gas Meter Run ID: 5.761 Barton Recorder Range: 1500# X 100" WC HES Rep: Steve Myers Tubing Vol. bbl/ft: 0.01 Date/Time Delta Tubing Tubing Casing Choke Time Pressure Temperature Pressure Size COMMENTS (hrs) (psig) (Deg. F.) (psig) (64ths) 07-Apr 8:00 0.000 Pressure Test Flowline To 5000 psi - Insulate Lines. 07-Apr 10:27 2.450 Pressure Up Tubing To Fire Guns. 07-Apr 10:30 2.500 3250 Open Well To Tank To Bleed Down Tubing. 07-Apr 10:32 2.533 0 Shut In Well - Wait For Guns To Fire. 07-Apr 10:36 2.600 Guns Fired. 07-Apr 10:45 2.750 650 24 Adj. Open Well To Tank No. 5 on 24/64 Adj. Choke. I. S. = 1' 4". 07-Apr 11:00 3.000 11 20 0 24 Adj. Clean Up Flow. Diesel Returns Reported as Water. 07-Apr 11:30 3.500 10 20 0 24 Adj. 07-Apr 12:00 4.000 10 27 0 24 Adj. 07-Apr 12:30 4.500 10 28 0 24 Adj. 07-Apr 13:00 5.000 16 29 0 24 Adj. 07-Apr 13:30 5.500 43 29 0 24 Adj. 07-Apr 14:00 6.000 319 31 0 24 Adj. Traces of Water @ Surface. 07-Apr 14:15 6.250 370 0 24 Adj. Traces of Gas ~ Surface. 07-Apr 14:30 6.500 422 32 0 24 Adj. Oil @ Surface. ,,, 07-Apr 15:00 7.000 446 32 0 24 Adj. Divert Flow Through Separator. Switch to Tank No. 1. I. S. = 0" 07-Apr 15:30 7.500 320 33 0 24 Adj. Change Choke to 28/64 ths. BS&W = 3%.Open to Tank No.2. I.S. = 0". 07-Apr 16:00 8.000 289 32 25 28 Adj. BS&W = 7%. Start Alternating Between Tank No. 1 & 2. 07-Apr 16:30 8.500 244 32 100 28 Adj. BS&W = 6% 07-Apr 17:00 9.000 282 32 125 28 Adj. BS&W = 20% - Emulsion Present. 07-Apr 17:30 9.500 290 32 150 28 Adj. BS&W = 10% 07-Apr 16:00 10.000 304 33 200 28 Adj. BS&W = 10% 07-Apr 18:30 10.5OO 310 34 200 28 Adj. BS&W = 10% page no: 1.1 Berl b / Job Log Halliburton Energy Services Sequence of Events Company: ARCO Alaska, INC. Well: Bergschrund Well No, 2A Test Number: Initial Test Company Rep: Tim Scarbrough Gas Meter Run ID: 5.761 Barton Recorder Range: 1500# X 100" WC HES Rep: Steve Myers Tubing Vol. bbl/ft: 0.01 Date/Time Delta Tubing Tubing Casing Choke Time Pressure Temperature Pressure Size COMMENTS (hrs) (psig) (Deg. F.) (psig) (64ths) 07-Apr 19:00 11.000 310 34 250 28 Adj. iBS&W = 5% 07-Apr 19:30 11.500 310 34 300 28 Adj. BS&W = 5% 07-Apr 20:00 12.000 320 33 320 28 Adj. BS&W = 3% 07-Apr 20:30 12.500 320 33 320 28 Adj. BS&W = 3% 07-Apr 21:00 13.000 320 33 400 28 Adj. BS&W = 1% 07-Apr 21:30 13.500 330 33 400 28 Adj. BS&W = 1.5% 07-Apr 22:00 14.000 320 33 400 20 Adj. Decrease Choke to 20/64 ths. Adj. BS&W = 1% 07-Apr 22:30 14.500 470 34 400 20 Adj. BS&W = 1% Change To 0.625" Orifice Plate. 07-Apr 23:00 15.000 540 34 400 12 Pos. Decrease Choke to 12/64 ths. Pos. BS&W = 0.1% 07-Apr 23:30 15.500 620 32 350 12 Pos. BS&W = 0.5% 08-Apr 0:00 16.000 630 30 350 20 Adj. Increase Choke to 20/64 ths. Adj. BS&W: 0.5% 08-Apr 0:30 16.500 470 30 310 28 Adj. Change Choke to 28/64 Adj. Change to 1.0" Orifice Plate. BS&W = 0.5% 08-Apr 1:00 17.000 420 32 310 28 Adj. BS&W = 0.5% 08-Apr 1:30 17.500 400 32 390 32 Adj. Increase Choke to 32/64 ths. Adj. BS&W = 0.5% 08-Apr 2:00 18.000 330 34 410 32 Adj. BS&W = 0.5% 08-Apr 2:30 18.500 320 34 450 32 Adj. BS&W = 0.5% 08-Apr 3:00 19.000 300 35 500 36 Adj. Increase Choke to 36/64 ths. Adj. BS&W = 0.2% 08-Apr 3:30 19.500 300 36 550 36 Adj. BS&W = 0.2% 08-Apr 4:00 20.000 280 36 580 40 Adj. Increase Choke to 40/64 ths. Adj. BS&W = 0.2% 08-Apr 4:30 20.500 270 36 600 40 Adj. BS&W = 0.2% 08-Apr 5:00 21.000 270 36 610 40 Adj. BS&W = 0.2% 08-Apr 5:30 21.500 270 36 620 48 Adj. Increase Choke to 48/64 ths. Adj. BS&W = 0.2% 08-Apr 6:00 22.000 250 34 680 48 Adj. BS&W = 0.5% page no'. 1.2 Berl b / Job Log Halliburton Energy Services Sequence of Events Company: ARCO Alaska, INC. Well: Bergschrund Well No. 2A Test Number: Initial Test Company Rep: Tim Scarbrough Gas Meter Run ID: 5.761 Barton Recorder Range: 15008 X 100" WC HES Rep: Steve Myers Tubing Vol. bbl/ft: 0.01 Date/Time Delta Tubing Tubing Casing Choke Time Pressure Temperature Pressure Size COMMENTS (hrs) (psig) (Deg. F.) (psig) (64ths) 08-Apr 6:30 22.500 260 36 700 48 Adj. Change Choke to 64/64 ths. Adj. Switch To Tank No. 3 I.S. = 0". 08-Apr 7:00 23.000 250 34 750 64 Adj. BS&W = 0.5% Alternate Tanks 3 & 4. 08-Apr 7:30 23.500 230 34 775 64 Adj. BS&W = 0.5% 08-Apr 8:00 24.000 240 39 800 64 Adj. BS&W = 0.5% 08-Apr 8:30 24.500 240 37 815 64 Adj. 08-Apr 9:00 25000 230 34 815 64 Adj. 08-Apr 9:30 25.500 225 36 815 64 Adj. Reduce Backpressure on Vessel. Change to 1.250" Orifice Plate. 08-Apr 10:00 26.000 215 40 815 64 Adj. Trace of Solids. 08--Apr 10:30 26.500 210 40 820 64 Adj. Trace of Solids. 08-Apr 11:00 27.000 210 36 820 64 Adj. Trace of Solids. 08-Apr 11:30 27.500 200 36 820 64 Adj. Trace of Solids. 08-Apr 12:00 28.000 210 35 840 64 Adj. Trace of Solids. 08oApr 12:30 28.500 210 36 840 64Adj. Trace of Solids. 08-Apr 13:00 29.000 205 36 840 64 Adj. Trace of Solids. 08-Apr 13:30 29.500 210 36 350 64 Adj. Trace of Solids. Bleed Down Casing Pressure. 08-Apr 14:00 30.000 205 34 400 64 Adj. Trace of Solids. 08-Apr 14:30 30.500 200 34 450 64 Adj. Trace of Solids. 08--Apr 15:00 31.000 205 34 475 64 Adj. Trace of Solids. Schlumberger RIH w/EL. 08-Apr 15:30 31.500 210 42 500 64 Adj. Trace of Solids. Bleed Down Casing Pressure to Zero 08-Apr 16:00 32.000 215 35 0 64 Adj. Trace of Solids. 08-Apr 16:30 32.500 210 36 0 64 Adj. Trace of Solids. 08-Apr 17:00 33.000 210 36 0 64 Adj. Trace of Solids. OS-Apr 17:30 33.500 205 36 0 64 Adj. Trace of Solids. page no: 1.3 Berl b / Job Log Halliburton Energy Services Sequence of Events Company: ARCO Alaska, INC. Well: Bergschrund Well No. 2A Test Number: Initial Test Company Rep: Tim Scarbrough Gas Meter Run ID: 5.761 Barton Recorder Range: 1500# X 100" WC HES Rep: Steve Myers Tubing Vol. bbl/ft: 0.01 Date/Time Delta Tubing Tubing Casing Choke Time Pressure Temperature Pressure Size COMMENTS (hrs) (psig) (Deg. F.) (psig) (64ths) 08-Apr 18:00 34.000 220 34 0 64 Adj. Trace of Solids. 08-Apr 18:30 34.500 220 44 0 64Adj. BS&W = 0.1% 08-Apr 19:00 35,000 220 42 0 64Adj. BS&W = 0.1% 08-Apr 19:30 35,500 220 42 0 64Adj. BS&W = 0.1% 08-Apr 20:00 36.000 212 42 0 64Adj. BS&W=0.1%. Switch to Tank No. 2. I.S.= 1.5". 08-Apr 20:30 36.500 205 42 0 64 Adj. 3S&W = 0.1%. Alternate Tanks 1 & 2. 08-Apr 21:00 37.000 215 42 0 64 Adj. BS&W = 0.2% 08-Apr 21:30 37.500 200 40 0 64 Adj. BS&W = 0.1% 08-Apr 22:00 38.000 200 39 0 64 Adj. BS&W = 0.5% 08-Apr 22:30 38.500 220 39 25 64 Adj. BS&W = 0.1% 08-Apr 23:00 39.000 220 38 50 64 Adj. ~S&W = 0.1% 08-Apr 23:30 39.500 220 38 60 64 Adj. BS&W = 0.1% 09-Apr 0:00 40.000 200 38 60 64Adj. BS&W = 0.1% 09-Apr 0:30 40.500 185 38 60 64Adj. BS&W = 0.1% 09-Apr 1:00 41.000 195 39 60 64Adj. BS&W = 0.1% 09-Apr 1:30 41.500 190 39 60 64Adj. ~S&W = 0.1% 09-Apr 2:00 42.000 180 38 60 64Adj. BS&W = 0.1% 09-Apr 2:30 42.500 185 40 70 64 Adj. BS&W = 0.25% 09-Apr 3:00 43.000 180 39 70 64 Adj. 3S&W = 0.2% 09-Apr 3:30 43.500 190 39 60 64 Adj. BS&W = 0.2% 09-Apr 4:00 44.000 190 39 60 64Adj. ~S&W = 0.1% 09-Apr 4:30 44.500 185 39 60 64 Adj. BS&W = 0.1% 09-Apr 5:00 45.000 175 39 60 64 Adj. BS&W = 0.1% page no: 1.4 Berl b / Job Log Halliburton Energy Services Sequence of Events Company: ARCO Alaska, INC. Well: Bergschrund Well No. 2A Test Number: Initial Test Company Rep: Tim Scarbrough Gas Meter Run ID: 5.761 Barton Recorder Range: 1500# X 100" WC HES Rep: Steve Myers Tubing Vol. bbllft: 0.01 Date/Time Delta Tubing Tubing Casing Choke Time Pressure Temperature Pressure Size COMMENTS (hrs) (psig) (Deg. F.) (psig) (64ths) 09-Apr 5:30 45.500 185 39 60 64Adj. BS&W = 0.1% 09-Apr 6:00 46.000 195 39 60 64Adj. BS&W = 0.1% 09-Apr 6:30 46.500 190 39 60 64 Adj. Trace of Solids. 09-Apr 7:00 47.000 205 39 70 64 Adj. Trace of Solids. 09-Apr 7:30 47.500 205 40 70 64 Adj. Trace of Solids. Switch to Tank No. 3, I. S.: 2' 1". 09-Apr 8:00 48.000 210 40 70 64 Adj. Trace of Solids. Alternate Tanks 3 & 4. 09-Apr 8:30 46.500 215 40 70 64 Adj. Trace of Solids, 09-Apr 9:00 49.000 215 40 70 64 Adj. Trace of Solids. 09-Apr 9:30 49.500 215 40 70 64 Adj. Trace of Solids. 09-Apr 10:00 50.000 215 40 70 64 Adj. Trace of Solids. 09-Apr 10:30 50.500 215 40 80 64 Adj. Trace of Solids. 09-Apr 11:00 51.000 215 40 80 64 Adj. Trace of Solids. 09-Apr 11:30 51.500 202 44 50 64 Adj. Trace of Solids. 09-Apr 12:00 52.000 205 44 50 64 Adj. [Trace of Solids. 09-Apr 12:30 52.500 205 44 50 64Adj. Trace of Solids. 09-Apr 13:00 53.000 205 44 50 64 Adj. Trace of Solids. 09-Apr 13:30 53.500 201 44 50 64 Adj. Trace of Solids. 09-Apr 13:45 53.750 201 44 50 64 Adj. S/I Well Downhole. Take Oil Samples @ Separator. 09-Apr 14:00 54.000 Monitor Surface Equipment - No Data Recorded. 10-Apr 0:00 64.000 Continue To Monitor Surface Equipment - No Data Recorded. 10-Apr 6:30 70.500 POOH with Shut In Tool. No Data Recorded. 10-Apr 8:00 72.000 Continue To Monitor Surface Equipment - No Data Recorded. 10-Apr 18:00 82000 Continue To Monitor Surface Equip. - No Data Recorded. ~-, page no: 1.5 Berl b / Job Log Halliburton Energy Services Sequence of Events Company: ARCO Alaska, INC. Well: Bergschrund Well No. 2A Test Number: Initial Test Company Rep: Tim Scarbrough Gas Meter Run ID: 5.761 Barton Recorder Range: 1500# X 100" WC HES Rep: Steve Myers Tubing Vol. bbllft: 0.01 Date/Time Delta Tubing Tubing Casing Choke Time Pressure Temperature Pressure Size COMMENTS (hrs) (psig) (Deg. F.) (psig) (64ths) 11-Apr 0:00 88.000 Continue To Monitor Surface Equipment - No Data Recorded. 11-Apr 7:00 95.000 Hold Safety Meeting. - No Data Recorded. 11-Apr 11:00 99.000 End Of Test. Begin Rigging Down Surface Test Equipment 11 -Apr 21:00 109.000 Secure Rig Down For Night. 12-Apr 7:00 119.000 Hold Safety Meeting 12-Apr 8:00 120.000 Continue To Rig Down Surface Test Equiprnent. 12-Apr 21:00 133.000 Secure Rig Down For Night. 13-Apr 7:00 143.000 Hold Safety Meeting 13-Apr 8:00 144.000 Continue To Rig Down Surface Test Equipment 13-Apr 18:00 154.000 Equipment and Crew Released From Location. page no: 1.6 Berl b / Job Log Customer: ARCO Alaska, INC, Well: Bergschrund Well No. 2A Stage: Initial Test Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 5.761 Barton Recorder Range: 1500~ X 100" WC H.E.S. Rep: Steve Myers Storage Tank Coeff: 1.6667 Wellhead Data Cumulative Volumes and Rates Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas i~ Press Temp Press Size BS&W Cumm, Rate Cumm. Rate Cumin Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) , 7-Apr 08:00 Pressure Test Flowline To 5000 psi - Insulate Lines. 7-Apr 1.0:27 Pressure Up Tubing To Fire Guns. 7-Apr 10:30 3250.0 Open Well To Tank To Bleed Down Tubing. 7-Apr '.' 10:32 0,0 Shut In Well - Wait For Guns To Fire. 7-Apr 10:36 Guns Fired, 7-Apr 10:45 650.0 0.0 24 Adj. Open, Well To Tank No. 5 on 24/64 Adj. Choke. I. S. = 1' 4". 7-Apr 11:00 11.0 20.0 0.0 24 Adj. 100.0 0,00 0,00 3.33 319,68 0.00 ~lean Up Flow. Diesel Returns Reported as Water. 7-Apr 11:30 10.0 20.0 0.0 24 Adj. 1000 0.00 0.00 1000 320.16 0.00 7-Apr' 12:00 10.0 27.0 0.0 24 Adj. 100,0 0.00 0.00 13.33 159.84 0,00 ~ 7-Apr 12:30 10.0 28.0 0.0 24 Adj. 100.0 0.00 0.00 20.83 360.00 0.00 7-Apr 13:00 16.0 29.0 0.0 24 Adj. 100.0 0.00 0.00 27.50 320.16 0.00 7-Apr 13:30 43.0 29.0 0.0 24 Adj. 100.0 0.00 0.00 40.83 639.84 0.00 7-Apr. 14:00 319.0 31.0 0.0 24 Adj. 100.0 0.00 0.00 60.83 960.00 0.00 Traces of Water (~ Surface. 7-Apr 14:15 370.0 0.0 24 Adj. 100.0 0.00 0,00 61.67 80.16 0.00 Traces of Gas @ Surface. 7-Apr 14:30 422.0 320 0.0 24 Adj, 0,1 0,83 80.12 61.67 0.04 0.00 Oil @ Surface. ~ , _ 7-Apr 15:00 446.0 32.0 0.0 24 Adj, 0.0 11.66 519.84 61.67 0,00 0,00 Divert Flow Through Separator. Switch to Tank No. 1. I. S. = (7' 7-Apr 15:30 320.0 33,0 0.0 24 Adj. 3.0 17.32 271.68 61.84 8.40 9,99 479.43 1.765 Change Choke to 28/64 ths. BS&W = 3%.Open to Tank No.2. I,S. = 0". 7-Apr 16:00 289.0 32.0 25.0 28 Adj. 7.0 22.91 268.29 62.25 19.61 16.85 329.39 1.228 BS&W = 7%. Start Alternating Between Tank No. I & 2. Page 2.1 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Bergschrund Well No. 2A Stage: Initial Test Company Rep: Tim Scarbrough Gas Meter Run ID: 5.761 Barton Recorder Range: 1500~ X 100" WC H.E.S. Rep: Steve Myers Storage Tank Coeff: 1.6667 " II Wellhead DataI]ll Cumulative Volumes and Rates , , , .... ,,, , , Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumin Rate GOR Comments .... (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 7-Apr 16:30 244.0 32.0 100.0 28 Adj, 6.0 36.63 658.53 63.10 40.81 24.55 369.50 0.561 BS&W = 6% 7-Apr 17:00 282.0 32.0 125.0 28 Adj. 20.0 48.99 593.28 66.10 144.00 31.69 342.82 0.578 BS&W = 20% - Emulsion Present. 7-Apr 17:30 290.0 32.0 150.0 28 Adj. 10.0 65.22 778.68 67.85 84.00 39.09 355.32 0.456 BS&W = 10% 7-Apr 18:00 304.0 33.0 200.0 28 Adj. 10.0 79.89 704.37 69.43 75.98 46.76 368.25 0.523 BS&W = 10% 7-Apr' 18:30 310.0 34.0 200.0 28 Adj. 10.0 94.06 680.13 70.97 74.02 55.50 419.49 0.617 BS&W = 10% 7-Apr 19:00 310.0 34.0 250.0 28 Adj. 5.0 108.33 684.79 71.70 34.99 64.24 419.49 0.613 BS&W = 5% .... 7-Apr' 19:30 310.0 34.0 300.0 28 Adj. 5.0 124.89 795.20 72.56 40.99 73.22 430.76 0.542 BS&W = 5% ..... 7-Apr 20:00 320.0 33.0 320.0 28 Adj. 3.0 141.13 779.30 73.04 23.40 82.32 436.71 0.560 BS&W = 3% 7-Apr 20:30 320.0 33.0 320.0 28 Adj. 3.0 157.64 792.45 73.54 24.00 91.54 442.59 0.559 BS&W = 3% 7-Apr 21:00 320.0 33.0 400.0 28 Adj. 1.0 173.36 754.74 73.70 7.40 101.04 456.39 0.605 BS&W = 1% 7-Apr 21:30 330.0 33.0 400.0 28 Adj. 1.5 189.70 784.43 73.94 11.70 110.58 457.83 0.584 BS&W = 1.5% 7-Apr 22:00 320.0 33.0 400.0 20 Adj. 1.0 206.27 795.37 74.11 7.80 119.99 451.72 0.568 Decrease Choke to 20/64 ths. Adj. BS&W = 1% - 7-Apr 22:30 470.0 34.0 400.0 20 Adj. 1.0 217.65 545.83 74.22 5.40 123.99 191~64 0.351 BS&W = 1% Change To 0.625" Orifice Plate. 7-Apr 23:00 540.0 34.0 400.0 12 Pos. 0.1 223.64 287.95 74.22 0.28 128.16 200.56 0.697 Decrease Choke to 12/64 ths. Pos. BS&W = 0.1% 7-Apr 23:30 620.0 32.0 350.0 12 Pos. 0.5 224.49 40.47 74.23 0.20 131.48 159.20 3.933 BS&W = 0.5% 8-Apr 00:00 630.0 30.0 350.0 20 Adj. 0.5 229.61 245.96 74.25 1.20 134.53 146.39 0.595 Increase Choke to 20/64 tbs. Adj. BS&W = 0.5% 8-Apr 00:30 470.0 30.0 310.0 28 Adj. 0.5 250.36 995.74 74.35 4.90 144.62 484.04 0.486 Change Choke to 28/64 Adj. Change to 1.0" Orifice Plate BS&W = 0.5% __ 8-Apr 01:00 420.0 32.0 310.0 28 Adj. 0.5 268.29 860.87 74.44 4.20 154.94 495.68 0.576 BS&W = 0.5% Page 2.2 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Bergschrund Well No, 2A Stage: Initial Test Company Rep: Tim Scarbrough Gas Meter Run ID: 5.761 Barton Recorder Range: 1500~ X 100" WC H.E.S. Rep: Steve Myers Storage Tank Coeff: 1.6667 Wellhead Data . Cumulative Volumes and Rates , , ,, Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumin Rate Cumm. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (0 F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 8-Apr 01:30 400,0 32.0 390.0 32 Adj. 0.5 283.96 751.92 74.52 3,70 164.55 460,99 0.613 Increase Choke to 32/64 ths. Adj, BS&W = 0.5% 8-Apr 02:00 330.0 34.0 410,0 32 Adj. 0.5 304.02 963.20 74.62 4,70 175.55 528.32 0.549 BS&W = 0.5% 8-Apr 02:30 320.0 34,0 450.0 32 Adj, 0.5 321.80 853.35 74.70 4.20 185.44 474.58 0,556 BS&W = 0.5% 8-Apr 03:00 300.0 35.0 500.0 36 Adj. 0.2 338.94 822.52 74,74 1.60 197,66 586.52 0.713 Increase Choke to 36/64 ths. Adj. BS&W = 0.2% 8-Apr 03:30 300.0 36.0 550.0 36 Adj. 0.2 358.47 937.60 74.78 1.84 208.75 532.19 0.568 BS&W = 0.2% 8-Apr 04:00 280.0 36.0 580.0 40 Adj. 0.2 378.60 966.10 74.82 1.88 219.20 501,72 0.519 Increase Choke to 40/64 ths. Adj. 0S&W = 0.2% 8-Apr 04:30 270.0 36.0 600.0 40 Adj. 0.2 398.13 937.60 74.85 1.84 228.54 448.59 0,478 BS&W = 0.2% 8-Apr 05:00 270.0 36.0 610.0 40 Adj. 0.2 417.84 945.87 74.89 1.84 239.41 521.48 0.551 BS&W -- 0.2% 8-Apr 05:30 270.0 36.0 620.0 48 Adj. 0.2 439.06 1018.79 74.93 2.00 250.67 540.53 0.531 Increase Choketo 48164ths. Adj. BS&W = 0.2% ,L 8-Apr 06:00 250.0 34.0 680.0 48 Adj. 0.5 459.56 983.86 75.03 4.80 262.50 567.93 0.577 BS&W = 0.5% 8-Apr 06:30 260.0 36.0 700.0 48 Adj. 1.0 478.94 930.09 75.23 9.20 274.61 581.16 0.625 Change Choke to 64/64 tbs. Adj.Switch To Tank No 3 I.S. = 0". 8-Apr '07:00 250.0 34.0 750.0 64 Adj. 0.5 500.28 1024.69 75.33 5.00 287.20 604.51 0.590 BS&W = 0.5% Alternate Tanks 3 & 4. 8-Apr 07:30 230.0 34.0 775.0 64 Adj. 0.5 519.76 934,79 75.43 4.60 299.10 571.03 0.611 BS&W = 0.5% 8-Apr 08:00 240.0 39.0 800.0 64 Adj. 0.5 540.25 983.86 75.53 4.80 311.17 579,32 0.589 BS&W = 0.5% 8-Apr '08:30 240.0 37.0 815.0 64 Adj. 0.5 560.57 975.26 75.63 4.80 323.33 583.72 0.599 8-Apr 09:00 230.0 34.0 815.0 64 Adj. 0.3 586.26 1232.91 75.69 3.00 335,40 579.32 0.470 8-Apr 09:30 225.0 36.0 815.0 64 Adj. 0.0 604.97 898.32 75.69 0.00 347.28 570.43 0.635 Reduce Backpressure on Vessel. Change to 1.250" Orifice Plate. 8-Apr 10:00 215.0 40.0 815.0 64 Adj. 0.0 627.29 1071.36 75.69 0.00 361.21 668.63 0.624 Trace of Solids. Page 2.3 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Bergschrund Well No. 2A Stage: Initial Test Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 5.761 Barton Recorder Range: 1500~ X 100" WC H.E.S. Rep: Steve Myers Storage Tank Coeff: 1.6667 " Wellhead Data I[ Cumulative Volumes and Rates , ,,,,,, Date/Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm, Rate Cumin. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) . , 8-Apr 10:30 210.0 40.0 820.0 64 Adj. 0.0 651.97 1184.52 75.69 0.00 375.82 701.29 0.592 Trace of Solids. , 8-Apr 11:00 210,0 36.0 820.0 64 Adj, 0.0 675.15 1112.40 75.69 0.00 390.42 700.59 0.630 Trace of Solids. 8-Apr 11:30 200.0 36.0 820.0 64 Adj. 0.0 697.27 1062.00 75.69 0.00 405,04 702.00 0.661 Trace of Solids. 8-Apr 12:00 210.0 35.0 840.0 64 Adj. 0.3 721.23 1149.97 75.76 3.36 419.38 687.99 0.598 Trace of Solids. 8-Apr, 12:30 210.0 36.0 840.0 64 Adj. 0.2 743.31 1059.88 75.80 2.08 433.75 690.07 0.651 Trace of Solids. 8-Apr 13:00 205.0 36.0 840.0 64 Adj. 0.0 758.76 741.60 75.80 0.00 448.11 689.37 0.930 Trace of Solids. ,,i 8-Apr 13:30 210.0 36.0 350.0 64 Adj. 0.0 784.28 1225.20 75.80 0.00 462.49 690.07 0.563 Trace of Solids. Bleed Down Casing Pressure, 8-Apr 14:00 205.0 34,0 400.0 64 Adj. 0.0 806.60 1071.36 75.80 0.00 477.10 701.19 0.654 Trace of Solids. 8-Apr 14:30 200.0 34.0 450.0 64 Adj. 0.0 827.87 1020.84 75.80 0.00 491,71 701.19 0.687 Trace of Solids. · 8-Apr 15:00 205.0 34.0 475.0 64 Adj. 0.0 851.90 1153.44 75.80 0.00 506.32 701.19 0.608 Trace of Solids, Schlumberger RIH w/EL. '" 8-Apr 15:30 210.0 42.0 500.0 64 Adj. 0.0 877.43 1225.20 75.80 0.00 520.92 701.19 0.572 Trace of Solids. Bleed Down Casing Pressure to Zero 8-Apr 16:00 215.0 35.0 0.0 64 Adj. 0.0 901.46 1153.44 75.80 0.00 535.26 687.99 0.596 Trace of Solids. 8-Apr. 16:30 210.0 36.0 0.0 64 Adj. 0.0 927.84 1266.37 75.80 0.00 549.86 701.19 0.554 Trace of Solids. 8-Apr 17:00 210.0 36.0 0.0 64 Adj. 0.0 951.87 1153.44 75.80 0.00 564.46 700.49 0.607 Trace of Solids. 8-Apr 17:30 205.0 36.0 0.0 64 Adj. 0.1 969.72 856.78 75.82 0.84 579.05 700.49 0.818 Trace of Solids. 8-Apr 18:00 220.0 34.0 0.0 64 Adj. 0.1 992.87 1111.29 75.84 1.08 593.63 699.77 0.630 Trace of Solids. 8-Apr 18:30 220.0 44.0 0.0 64 Adj. 0.1 1020.07 1305.74 75.87 1.28 607.98 688.68 0.527 BS&W = 0.1% 8-Apr,19:00 220.0 42.0 0,0 64 Adj. 0.1 1044.08 1152.28 75.89 1.12 622.81 712.18 0.618 BS&W = 0.1% Page 2.4 Final_Reports I Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Bergschrund Well No. 2A Stage: Initial Test Company Rep: Tim Scarbrough Gas Meter Run ID: 5.761 Barton Recorder Range: 1500~ X 100" WC H.E.S. Rep: Steve Myers Storage Tank Coeff: 1.6667 II Wellhead Data ,,,. Cumulative Volumes and Rates Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumin Rate Cumm. Rate Cumin. Rate GOR Comments (dd-mmm hh:mm) (psig) (° F) (psig) (64tbs) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) , 8-Apr 19:30 220.0 42.0 0.0 64 Adj. 0,1 1070.43 1264.61 75.92 1.24 637.77 717.77 0,568 BS&W = 0.1% 8-Apr' 20:00 212,0 42.0 0.0 64 Adj. 0.1 1094,01 1132,03 75.94 1.10 652.11 688.62 0,608 BS&W = 0.1%. Switch to Tank No. 2. I. S. = 1.5". 8-Apr 20:30 205.0 42.0 0.0 64 Adj. 0.1 1118.66 1183.34 75.96 1.16 666.45 688,03 0,581 BS&W = 0.1%. Alternate Tanks I & 2. 8-Apr 21:00 215,0 42.0 0.0 64 Adj. 0.2 1146.08 1315.93 76.02 2,56 680,83 690.48 0.525 BS&W = 0,2% 8-APr 21:30 200,0 40.0 0,0 64 Adj. 0,1 1169.87 1142,21 76.04 1.12 695.26 692.56 0.606 BS&W = 0.1% ,, , 8-Apr '22:00 200.0 39.0 0,0 64 Adj. 0.5 1199.77 1434,95 76.19 7.00 708.96 657.30 0.458 BS&W = 0.5% 8-A, pr 22:30 220.0 39.0 25.0 64 Adj. 0,1 1224.42 1183.34 76.21 1.16 724.49 745.47 0,630 BS&W = 0.1% ,,, 8-Apr 23:00 220.0 38.0 50.0 64 Adj. 0.1 1239.86 740,86 76.23 0.72 739.65 727.94 0.983 BS&W = 0.1% 8-Apr 23:30 220.0 38.0 60.0 64 Adj. 0.1 1261.53 1040.38 76.25 1.02 754.78 726,22 0.698 BS&W = 0,1% 9-Apr 00:00 200,0 38.0 60.0 64 Adj. 0.1 1286,40 1193.77 76.27 1.16 769.67 714.78 0.599 BS&W = 0.1% 9-Apr 00:30 185,0 38.0 60.0 64 Adj. 0.1 1308.92 1081,01 76.29 1.06 784.46 709.92 0,657 BS&W = 0,1% 9-Apr 01:00 195.0 39.0 60.0 64 Adj. 0,1 1330.36 1028.81 76.31 1.00 800.44 767.05 0.746 BS&W = 0.1% 9-Apr 01:30 190.0 39,0 60.0 64 Adj. 0,1 1347.78 836.22 76.33 0.82 815.37 716.41 0.857 BS&W = 0.1% 9-Apr 02:00 180.0 38.0 60.0 64 Adj. 0.1 1372.00 1162.78 76.36 1.14 830.53 727.96 0.626 BS&W = 0.1% 9-Apr. 02:30 185.0 40.0 70.0 64 Adj. 0,3 1402.98 1487.10 76.43 3.65 845.48 717.20 0.482 BS&W = 0.25% 9-Apr 03:00 180.0 39,0 70.0 64 Adj. 0.2 1435.96 1582.86 76.50 3.08 860.88 739.33 0,467 BS&W = 0.2% 9-Apr 03:30 190.0 39.0 60.0 64 Adj. 0.2 1461.43 1222.75 76.55 2.40 876.66 757.59 0.620 BS&W = 0.2% 9-Apr 04:00 190,0 39.0 60.0 64 Adj. 0.1 1475.03 652.62 76.56 0,64 892.04 738.39 1.131 BS&W = 0.1% Page 2.5 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Bergschrund Well No. 2A Stage: Initial Test Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 5.761 Barton Recorder Range: 1500~ X 100" WC H.E.S. Rep: Steve Myers Storage Tank Coeff: 1.6667 Wellhead Data II .......... c'um"u'lative' V°lumes and RatesII ' Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas ) Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbts) (bbl/d) (mscf) (mscf/d) (mscf/bbl) , 9-Apr 04:30 185.0 39.0 60.0 64 Adj. 0,1 1489,05 673.19 76.57 0,66 907.46 740,07 1.099 BS&W = 0.1% 9-Apr 05:00 175.0 39.0 60.0 64 Adj. 0.1 1513.06 1152.28 76.60 1.12 922.80 736.01 0.639 BS&W = 0.1% 9-Apr 05:30 185.0 39.0 60.0 64 Adj. 0.1 1544.93 1529.97 76.63 1.50 938,77 766.65 0.501 BS&W = 0.1% ,9-Apr 06:00 195.0 39.0 60.0 64 Adj. 0.1 1568.73 1142.21 76,65 1.12 954.27 744.25 0.652 BS&W = 0.1% ,, 9-Apr 06:30 190.0 39.0 60.0 64 Adj. 0.1 1594,23 1223.97 76.68 1.20 969.78 744.25 0.608 ]-race of Solids. 9-Apr 07:00 205.0 39.0 70.0 64 Adj. 0,1 1616.53 1070.29 76.70 1.04 985.25 742.77 0.694 Trace of Solids. 9-Apr '07:30 205.0 40.0 70.0 64 Adj. 0.1 1640.32 1142.21 76.72 1.12 1000.77 744.98 0.652 ITrace of Solids. Switch to Tank No. 3. I. S. = 2' 1'. 9-Apr 08:00 210,0 40.0 70.0 64 Adj. 0.1 1663.47 1111.29 76.74 1.08 1016.31 745.86 0.671 ITrace of Solids. Alternate Tanks 3 & 4. 9-Apr 08:30 215.0 40.0 70.0 64 Adj. 0.1 1687.27 1142.21 76.77 1.12 1031.61 734.39 0.643 Trace of Solids. 9-Apr 09:00 215.0 40.0 70.0 64 Adj. 0.1 1711.28 1152.28 76.79 1.12 1047.39 757.17 0,657 Trace of Solids. 9-Apr 09:30 215,0 40.0 70.0 64 Adj. 0.1 1735.07 1142.21 76.81 1.12 1063.14 756.41 0.662 Trace of Solids. 9-Apr 10:00 215.0 40.0 70.0 64 Adj. 0.1 1759.08 1152.28 76.84 1.12 1078.90 756.41 0.656 Trace of Solids. 9-Apr 10:30 215.0 40.0 80.0 64 Adj, 0.1 1783.30 1162.78 76.86 1.14 1094.66 756.41 0.651 Trace of Solids. 9-Apr 11:00 215.0 40.0 80,0 64Adj. 0.1 1808.17 1193.77- 76,88 1.16 1110.42 756.41 0.634 Trace of Solids. 9-Apr 11:30 202.0 44.0 50.0 64 Adj. 0.1 1832.40 1162.78 76.91 1.14 1126.18 756,41 0.651 Trace of Solids. 9-Apr 12:00 205.0 44.0 50.0 64 Adj. 0.1 1855.55 1111.29 76.93 1.08 1141.94 756.41 0.681 Trace of Solids. 9-Apr 12:30 205.0 44.0 50.0 64 Adj. 0.1 1880.20 1183.34 76,95 1,16 1157.02 724.19 0.612 Trace of Solids. 9-Apr 13:00 205.0 44.0 50.0 64 Adj. 0.1 1905.07 1193.77 76.98 1.16 1172.08 722,74 0,605 Trace of Solids. Page 2.6 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Bergschrund Well No. 2A Stage: Initial Test ,Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 5.761 Barton Recorder Range: 1500~ X 100" WC H.E.S. Rep: Steve Myers Storage Tank Coeff: 1.6667 Wellhead DataII. Cumulative Volumes and Rates II Date/Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas " Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate GOR Comments ' (dd-mmm hh:mm) (psig) (~ F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) , 9-Apr 13:30 201,0 44.0 50.0 64 Adj. 0.0 1928.89 1143.36 76,98 0,00 1187,14 722.74 0.632 Trace of Solids. 9-Apr 13:45 201.0 44,0 50,0 64 Adj. 0,0 1946.76 1715.28 76.98 0,00 1194.67 722,74 0.421 S/I Well Downhole, Take Oil Samples ~ Separator, 9-Apr 14:00 Monitor Surface Equipment - No Data Recorded, 10-Apr 00:00 Continue To Monitor Surface Equipment - No Data Recorded, 10-Apr 06:30 :~OOH with Shut In Tool. No Data Recorded. 10-Apr 08:00 Continue To Monitor Surface Equipment - No Data Recorded. 10-Apr 18:00 Continue To Monitor Surface Equip. - No Data Recorded, 11-Apr 00:00 Continue To Monitor Surface Equipment - No Data Recorded. 11-Apr 07:00 Hold Safety Meeting. - No Data Recorded. 11-Apr 11:00 End Of Test. Begin Rigging Down Surface Test Equipment 11-Apr 21:00 Secure Rig Down For Night. ,,. 12-Apr 07:00 Hold Safety Meeting 12-Apr 08:00 Continue To Rig Down Surface Test Equipment, 12-Apr 21:00 Secure Rig Down For Night. 13-Apr 07:00 Hold Safety Meeting 13-Apr 08:00 Continue To Rig Down Surface Test Equipment 13-Apr 18:00 Equipment and Crew Released From Location. ,. Page 2.7 Final_Reports I Results Summary Customer: ARCO Alaska, INC. , Well: Bergschrund Well No. 2A Test Number: Initial Test CompanY Rep: Tim Scarbrough Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 5,761 Barton Recorder Range: 1500~ X 100" WC H.E.S. Rep: Steve Myers Storage Tank Coeff: 1.6667 , , Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMPi Inc. Rate Inc. Rate Inc. Rate GOR CHLOk~ES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) ((~60F) (inches) (AIR=l) (psig) (inH20) (°F) ("F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d)I (mscf/bbl) (ppm) ,7-Apr 08:00 , ,7-Apr 10:27 '7-Apr 10:30 3250.0 7-Apr 10:32 0.0 7-Apr 10:36 7-Apr 10:45 650.0 24 Adj. 7-Apr 11:00 11.0 24 Adj. 100.0 3.33 0.00 0,00 0.00 3.33 319.68 0.00 7-Apr 11:30 10.0 24Adj, 100.0 6.67 0.00 0.00 0.00 6.67 320.16 0.00 .,. 7-Apr 12:00 10.0 24 Adj. 100.0 3,33 0.00 0.00 0.00 3.33 159.84 0.00 7-Apr 12:30 10.0 24 Adj. 100.0 7.50 0.00 0.00 0.00 7,50 360.00 0.00 7~Apr 13:00 16.0 24 Adj. 100.0 6.67 0.00 0.00 0.00 6.67 320.16 0.00 7-Apr 13:30 43,0 24 Adj. 100.0 13.33 0.00 0.00 0.00 13.33 639.84 0.00 7-Apr 14:00 319.0 24 Adj. 100.0 20.00 0.00 0.00 0.00 20.00 960.00 0.00 7-Apr 14:15 370.0 24 Adj. 100.0 0.84 0.00 0.00 0.00 0.84 80.16 0.00 7-Apr 14:30 422,0 24 Adj. 0.1 0.84 0.83 0.83 80.12 0.00 0.04 0.00 7-Apr 15:00 446.0 24 Adj. O0 10.83 10.83 10.83 519.84 0.00 0.00 0.00 7-Apr 15:30 320.0 24 Adj. 3.0 5.84 5.66 0,785 0.785 170.0 44.0 72.0 5.66 271.68 0.18 8.40 9.99 479.43 1.765 7-Apr 16:00 289.0 28 Adj. 7.0 5,84 5.43 42.90 0.785 0.785 150.0 24.0 78.0 5.59 268.29 0.41 19.61 6.86 329.39 1.228 Page 3.1 Final_Reports/Separator Reading Customer: ARCO Alaska, INC. Well: Bergschrund Well No. 2A Test Number: Initial Test Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 5761 Barton Recorder Range: 1500~ X 100" WC H.E.S. Rep: Steve Myers Storage Tank Coeff: 1.6667 Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR cHLoR,,,C (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (@60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbltd) (mscf) (mscf/d) (mscf/bbl) (ppm) 7-Apr 1'6:30 244.0 28 Adj. 6.0 14.17 13.32 39.40 0.785 0.785 150.0 30.0 750 13.72 658.53 0.85 40.81 7.70 369.50 0.561 7-Apr 17:00 282.0 28 Adj. 20.0 15.00 12.00 39.40 0.785 0.785 160.0 24.0 72.0 12.36 593.28 3.00 144.00 7.14 342.82 0.578 115,000 7~Apr 17:30 290.0 28 Adj. 10.0 17.50 15.75 39.40 0.785 0.785 160.0 26.0 76.0 16.22 778.68 1.75 84.00 7.40 355.32 0.456 7-Apr 18:00 304.0 28 Adj. 10.0 15.83 14.25 37.20 0.785 0.785 170.0 34.0 76.0 14.67 704.37 1.58 75.98 7.67 368.25 0.523 75,000 7-Apr 18:30 310.0 28 Adj. 10.0 15.42 13.88 0.785 0.785 170.0 34.0 76.0 14.17 680.13 1.54 74.02 8.74 419.49 0.617 7-Apr 19:00 310.0 28 Adj. 5.0 14.58 13.85 36.70 0.785 0.785 170.0 34.0 76.0 14.27 684.79 0.73 34.99 8.74 419.49 0.613 45,000 7-Apr 19:30 310.0 28 Adj. 5.0 17.08 16.23 0.785 0.785 170.0 36.0 78.0 16.57 795.20 0.85 40.99 8.97 430.76 0.542 7-Apr 20:00 320.0 28 Adj. 3.0 16.25 15.76 38.60 0.785 0.785 170.0 37.0 78.0 16.24 779.30 0.49 23.40 9.10 436.71 0.560 49,000 7-Apr 20:30 320.0 28 Adj. 3.0 16.67 16.17 0.785 0.785 170.0 38.0 78.0 16.51 792.45 0.50 24.00 9.22 442.59 0.559 7-Apr 21:00 320.0 28 Adj. 1.0 15.42 15.27 39.40 0.785 0.785 170.0 41.0 85.0 15.72 754.74 0.15 7.40 9.51 456.39 0.605 35,0bu 7-Apr 21:30 330.0 28 Adj. 1.5 16.25 16.01 0.785 0.785 170.0 41.0 82.0 16.34 784.43 0.24 11.70 9.54 457.83 0.584 7-Apr 22:00 320.0 20 Adj. 1.0 16.25 16.09 40.00 0.785 0.785 165.0 41.0 80.0 16.57 795.37 0.16 7.80 9.41 451.72 0.568 34.000 7-Apr 22:30 470.0 20 Adj. 1.0 11.25 11.14 0.785 0.785 165.0 48.0. 76.0 11.37 545.83 0.11 5.40 3.99 191.64 0.351 7-Apr 23:00 540.0 12 Pos. 0.1 5.83 5.82 40.20 0.785 0.785 165.0 53.0 80.0 6.00 287.95 0.01 0.28 4.18 200.56 0.697 25.000 7-Apr 23:30 620.0 12 Pos. 0.5 0.83 0.83 0.785 0.785 165.0 34.0 88.0 Q84 40.47 0.00 0.20 3.32 159.20 3.933 8-Apr 00:00 630.0 20 Adj. 0.5 500 4.98 40.20 0.785 0.785 150.0 32.0 92.0 5.12 245.96 0.03 1.20 3.05 146.39 0.595 25,0(X} 8-Apr 00:30 470.0 28 Adj. 0.5 20.42 20.32 0.785 0.785 160.0 50.0 94.0 20.74 995.74 0.10 4.90 10.08 484.04 0.486 8-Apr 01:00 420.0 28 Adj. 0.5 17.50 17.41 38.90 0.785 0.785 160.0 52.0 90.0 17.93 860.87 0.09 4.20 10.33 495.68 0.576 20,000 Page 3.2 Final_Reports I Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Bergschrund Well No. 2A Test Number: Initial Test Company Rep: Tim Scarbrough Gas Meter Run ID: 5.761 Barton Recorder Range: 1500~ X 100" WC H.E.S. Rep: Steve Myers Storage Tank Coeff: 1.6667 Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLOR,~,E. (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (~60F) (inches) (AIR:l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscfld) (mscffbbl) (ppm) , 8-Apr 01'.30 400.0 32 Adj, 0.5 15.42 15.34 0.785 0.785 160.0 45.0 90,0 15.67 751.92 0,08 3.70 9.60 460,99 0.613 8-Apr 02:00 330.0 32 Adj. 0.5 19.58 19.48 40.80 0.785 0,785 170.0 55.0 86.0 20.07 963.20 0.10 4.70 11.01 528.32 0.549 35,000 8-Apr 02:30 320.0 32 Adj. 0.5 17.50 17.41 0.785 0,785 165.0 46,0 88.0 17.78 853.35 0.09 4.20 9.89 474.58 0.556 8-Apr 03:00 300.0 36 Adj. 0.2 16,67 16.64 40.40 0.788 0.788 170.0 68.0 88.0 17,14 822,52 0.03 1.60 12.22 586.52 0.713 37,000 8-Apr 03:30 300.0 36 Adj. 0.2 19,17 19.13 0.788 0.788 170.0 56.0 86.0 19.53 937.60 0.04 1.84 11.09 532.19 0.568 8-Apr 04:00 280.0 40 Adj. 0.2 19,58 19.54 39.80 0.788 0.788 170.0 50.0 88.0 20.13 966.10 0.04 1.88 10.45 501.72 0.519 31,000 8-Apr 04:30 270.0 40 Adj. 0.2 19.17 19.13 0.788 0.788 170.0 40,0 88.0 19.53 937.60 0.04 1.84 9.35 448.59 0.478 8-Apr 05:00 270.0 40 Adj. 0.2 19.17 19.13 40.10 0.788 0.788 170.0 54.0 88.0 19.71 945.87 0.04 1.84 10.86 521.48 0.551 33,000 8-Apr 05:30 270.0 48 Adj. 0.2 20.83 20.79 0.788 0.788 170.0 58.0 88.0 21.22 1018.79 0.04 2.00 11.26 540.53 0.531 8-Apr 06:00 250.0 48 Adj. 0.5 20.00 19.90 40.10 0.788 0.788 170.0 64.0 88.0 20.50 983.86 0.10 4,80 11.83 567.93 0.577 30,0Ou 8-Apr 06:30 260.0 48 Adj. 1.0 19.17 18.98 0.788 0.788 170.0 67.0 88.0 19.38 930.09 0.19 920 12.11 581.16 0.625 8-Apr 07:00 250.0 64 Adj. 0.5 20.83 20.73 40.10 0.784 0.784 175.0 70.0 88.0 21.35 1024.69 0.10 5.00 12.59 604.51 0.590 25,000 8-Apr 07:30 230.0 64Adj. 0,5 19.17 19.07 0.784 0.784 170.0 64.0 85.0 19.47 934.79 0.10 4.60 11.90 571.03 0.611 8-Apr 08:00 240.0 64 Adj. 0.5 20.00 19.90 40.10 0.784 0.784 170.0 66.0 86.0 20.50 983.86 0.10 4.80 12.07 579.32 0.589 25.000 8-Apr 08:30 240.0 64 Adj. 0.5 20.00 19.90 0.784 0.784 170.0 67.0 86.0 20.32 975.26 0.10 4.80 12.16 583.72 0.599 8-Apr 09:00 230.0 64 Adj. 0,3 25.00 24.94 40.10 0.784 0.784 170.0 66.0 86.0 25.69 1232.91 0.06 3.00 12.07 579.32 0.470 25.000 8-Apr 09:30 225.0 64 Adj. Q0 18.33 18.33 0.784 0.784 170.0 64.0 86.0 18.71 898.32 0.00 0.00 11.88 570.43 0.635 8-Apr 10:00 215.0 64 Adj. 0.0 21.67 21.67 39.70 0.818 0.818 100.0 64.0 82.0 22.32 1071.36 0.00 0.00 13.93 668.63 0.624 Page 3,3 Final_Reports I Separator Reading Customer: ARCO Alaska, INC. Well: Bergschrund Well No. 2A Test Number: Initial Test Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 5.761 Barton Recorder Range: 1500~ X 100" WC H.E.S. Rep: Steve Myers Storage Tank Coeff: 1.6667 Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff I Temp 'TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLOR,~ (hh:mm) (psig) (64ths) (%) (bbls) (bbls) ((g~60F) (inches) (AIR=I)I (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 8-Apr 10:30 210.0 64 Adj. 0.0 24.17 24.17 0.818 0.818 110.0 64.0 83.0 24.68 1184.52 0.00 0.00 14.61 701.29 0.592 8-Apr 11:00 210.0 64 Adj. 0.0 22.50 22.50 40.60 0.818 0.818 110.0 64.0 84.0 23.18 1112.40 0.00 0.00 14.60 700.59 0.630 8~Apr 11:30 200.0 64 Adj. 0.0 21.67 21.67 0.818 0.818 110.0 64.0 82.0 22.13 1062.00. 0.00 0.00 14.63 702.00 0.661 8-Apr 12:00 210.0 64 Adj. 0.3 23.33 23.26 40.60 0.820 0.820 110.0 62.0 850 23.96 1149.97 0.07 3.36 14.33 687.99 0.598 25,000 8~Apr 12:30 210.0 64 Adj. 0.2 21.67 21.63 0.820 0.820 110.0 62.0 82.0 22.08 1059.88 0.04 2.08 14.38 690.07 0.651 8-Apr 13:00 205.0 64Adj. 0.0 15.00 15.00 39.40 0.820 0.820 110.0 62.0 83.0 15.45 741.60 0.00 0.00 14.36 689.37 0.930 8-Apr 13:30 210.0 64 Adj. 0.0 25.00 25.00 0.820 0.820 110.0 62.0 82.0 25.53 1225.20 0.00 0.00 14.38 690.07 0.563 8-Apr 14:00 205.0 64 Adj. 0.0 21.67 21.67 39.40 0.820 0.820 110.0 64.0 82.0 22.32 1071.36 0.00 0.00 14.61 701.19 0.654 8-Apr 14:30 200.0 64 Adj. 0.0 20.83 20.83 0.820 0.820 110.0 64.0 82.0 21.27 1020.84 0.00 0.00 14.61 701.19 0.687 8-Apr 15:00 205.0 64 Adj. 0.0 23.33 23.33 40.80 Q820 0.820 110.0 64.0 82.0 24.03 1153.44 0.00 0.00 14.61 701.19 0.608 8-Apr 15:30 210.0 64 Adj. 0.0 25.00 25.00 0.820 0.820 110.0 64.0 82.0 25.53 1225.20 0.00 0.00 14.61 701.19 0.572 8-Apr 16:00 215.0 64 Adj. 0.0 23.33 23.33 40.80 0.820 0.820 110.0 62.0 85.0 24.03 1153.44 0.00 0.00 14.33 687.99 0.596 8-Apr 16:30 210.0 64 Adj. 0.0 25.83 25.84 0.820 0.820 110.0 64.0 82.0 26.38 1266.37 0.00 0.00 14.61 701.19 0.554 8-Apr 17:00 210.0 64 Adj. 0.0 23.33 23.33 40.80 0.820 0.820 110.0 64.0 83.0 24.03 1153.44 0.00 0.00 14.59 700.49 0.607 8-Apr 17:30 205.0 64 Adj. 0.1 17.50 17.48 0.820 0.820 110.0 64.0 84.0 17.85 856.78 0.02 0.84 14.59 700.49 0.818 8-Apr 18:00 220.0 64 Adj 0.1 22.50 22.48 40.80 0.820 0.820 110.0 64.0 84.0 23.15 1111.29 0.02 1.08 14.58 699.77 0.630 8-Apr 18:30 220.0 64 Adj 0.1 26.67 26.64 0.820 0.820 110.0 62.0 84.0 27.20 1305.74 0.03 1.28 14.35 688.68 0.527 8-Apr, 19:00 220.0 64 Adj, 0.1 23.33 23,31 39.00 0,790 0.790 110.0 64.0 84.0 24.01 1152.28 0.02 1.12 14.84 712.18 0.618 Page 3.4 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Bergschrund Well No. 2A Test Number: Initial Test Company Rep: Tim Scarbrough Gas Meter Run ID: 5.761 Barton Recorder Range: 1500~ X 100" WC H.E.S. Rep: Steve Myers Storage Tank Coeff: 1.6667 ,,, IoatemmeIIWellhead, ,DataIIS,e.P, a[atQr Readings ............... Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) ({~60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 8-Apr 19:30 220.0 64 Adj. 0.1 25.83 25.80 0.790 0.790 110.0 65.0 84.0 26.35 ]1264.61 0.03 1.24 14.95 717.77 0.568 8-Apr 20:00 212.0 64 Adj. 0.1 22.92 22.90 39.00 0.790 0.790 105.0 63.0 86.0 23.58 1132.03 0.02 1.10 14.35 688.62 0.608 8-Apr 20:30 205.0 64 Adj. 0.1 24.17 24.15 0.790 0.790 110.0 60.0 86.0 24.65 1183.34 0.02 i.16 14.33 688.03 0.581 8-Apr 21:00 215.0 64 Adj. 0.2 26.67 26.62 39.20 0.812 0.812 110.0 62.0 86.0 27.42 1315.93 0.05 2.56 14.39 690.48 0.525 8-Apr. 21:30 200.0 64Adj. 0.1 23.33 23.31 0.812 0.812 110.0 62.0 83.0 23.80 1142.21 0.02 1.12 14.43 692.56 0.606 8-Apr 22:00 200.0 64 Adj. 0.5 29.17 29.02 39.20 0.812 0.812 110.0 56.0 84.0 29.89 1434.95 0.15 7.00 13.69 657.30 0.458 8-Apr 22:30 220.0 64 Adj. 0.1 24.17 24.15 0.820 0.820 115.0 69.0 86.0 24.65 1183.34! 0.02 1.16 15.53 745.47 0.630 8-Apr 23:00 220.0 64 Adj. 0.1 15.00 14.99 39.60 0.792 0.792 110.0 67.0 84.0 15.43 740.86 0.02 0.72 15.17 727.94 0.983 8-Apr 23:30 220.0 64 Adj. 0.1 21.25 21.23 0.792 0.792 115.0 64.0 86.0 21,67 1040.38 0.02 1.02 15.13 726.22 0.698 .~,. 9-Apr 00;00 200.0 64 Adj. 0.1 24.17 24.15 39.60 0,792 0,792 110.0 65.0 87.0 24.87 1193.77 0.02 1.16 14.89 714.78 0.599 9-Apr 00:30 185.0 64 Adj. 0.1 22.08 22.06 0,792 0.792 110.0 64.0 86.0 22.52 1081.01 0.02 1.06 14.79 709,92 0.657 , 9-Apr 01:00 195.0 64 Adj. 0.1 20.83 2'0.81 39.80 0.788 0.788 115.0 71.0 86.0 21.43 1028.81 0.02 1.00 15.98 767.05 0.746 24,000 9-Apr 01:30 190.0 64 Adj. 0.1 17.08 17.06 0.788 0.788 115.0 62.0 86.0 17.42 836.22 0.02 0.82 14.93 716.41 0.857 9-Apr 02:00 180.0 64 Adj. 0.1 23.75 23.73 0,788 0.788 115.0 64.0 86.0 24.22 1162.78 0.02 1.14 15.17 727.96 0.626 9-Apr 02:30 185.0 64 Adj. 0.3 30.42 30.34 0.788 0,788 110.0 65.0 86.0 30.98 1487.10 0.08 3.65 14.94 717.20 0.482 9-Apr 03:00 180.0 64 Adj. 0.2 32.08 32.02 39.20 0.788 0.788 115.0 66.0 86.0 32.98 1582.86 0.06 3.08 15.40 739.33 0.467 24,000 9-Apr 03:30 190.0 64 Adj. 0.2 25.00 24.95 0.788 0.788 115.0 69.0 84.0 25.47 1222.75 0.05 2.40 15.78 757.59 0.620 9-Apr 04:00 190.0 64 Adj. 0.1 13.33 13.32 0,788 0.788 110.0 69.0 87.0 13.60 652.62 0.01 0.64 15.38 738.39 1.131 Page 3.5 Final_Reports I Separator Reading Customer: ARCO Alaska, INC, Well: Bergschrund Well No. 2A Test Number: Initial 'rest Company,Rep: Tim Scarbrough Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 5.761 Barton Recorder Range: 1500~ X 100" WC H.E.S. Rep: Steve Myers Storage Tank Coeff: 1.6667 Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc, Rate Inc. Rate GOR ,CHLORIL~£S (hl'i:mm) (psig) (64ths) (%) (bbls) (bbls) (@60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscftd) (mscf/bbl) (ppm) 9-Apr 04:30 185.0 64 Adj. 0.1 13.75 13.74 0.788 0.788 115.0 66.0 85.0 14.02 673.19 0.01 0.66 15.42 740.07 1.099 9-Apr 05:00 175.0 64 Adj. 0.1 23.33 23.31 39.20 0.777 0.777 110.0 67.0 82.0 24.01 1152.28 0.02 1.12 15.33 736.01 0.639 , 9-Apr 05:30 185.0 64 Adj. 0.1 31.25 31.22 0.777 0.777 115.0 70.0 86.0 31.87 1529.97 0.03 1.50 15.97 766.65 0.501 9-Apr 06:00 195.0 64 Adj. 0,1 23.33 23.31 0.777 0.777 115.0 66.0 86.0 23.80 ~1142,21 0.02 1.12 15.51 744.25 0.652 9-Apr, 06:30 190.0 64 Adj. 0.1 25.00 24.98 0.777 0.777 115.0 66.0 86.0 25.50 1223.97 0.03 1.20 15.51 744.25 0,608 9-Apr 07:00 205.0 64 Adj. 0.1 21.67 21.65 39.80 0.777 0,777 115.0 66.0 88.0 2230 1070.29 0.02 1.04 15.47 742.77 0.694 9-Apr 07:30 205.0 64 Adj, 0.1 23.33 23.31 0.777 0.777 115.0 66.0 85.0 23.80 1142,21 0.02 1,12 15.52 744.98 0.652 .... 9-Apr 08:00 210.0 64Adj. 0.1 22.50 22.48 39.80 0.780 0.780 115.0 66.0 82.0 23.15 1111.29 0.02 1.08 15.54 745.86 0.671 9-Apr 08:30 215.0 64 Adj. 0.1 23.33 23.31 0.780 0.780 115,0 64,0 82.0 23.80 1142.21 0.02 1.12 15.30 734.39 0.643 9-Apr 09:00 215.0 64Adj. 0.1 23.33 23.31 39.80 0.780 0.780 115.0 68.0 82.0 24.01 ,1152.28 0.02 1.12 15.77 757.17 0.657 9-Apr 09:30 215,0 64 Adj. 0.1 23,33 23.31 0.780 0.780 115.0 66.0 83.0 23.80 1142.21 0.02 1.12 15.76 756.41 0.662 9-Apr 10:00 215.0 64 Adj. 0.1 23.33 23.31 39.80 0.780 0,780 115.0 66.0 83.0 24.01 1152.28 0.02 1.12 15.76 756.41 0.656 9-Apr 10:30 215.0 64 Adj. 0.1 23.75 23.73 0.780 0.780 115.0 66.0 83.0 24.22 1162.78 0.02 1.14 15.76 756.41 0.651 9-Apr 11:00 215.0 64Adj. 0.1 24.17 24.15 39.80 0.780 0.780 115.0 66.0 83.0 24.87 1193.77 0.02 1,16 15.76 756.41 0.634 9-Apr 11:30 202.0 64Adj. 0.1 23.75 23.73 0.780 0.780 115.0 66.0 83.0 24.22 1162.78 0.02 1.14 15.76 756.41 0,651 9-Apr 12:00 205.0 64 Adj. 0.1 22.50 22.48 39.80 0.780 0,780 115.0 66.0 83.0 23.15 1111.29 0.02 1.08 15.76 756.41 0.681 9-Apr 12:30 205.0 64 Adj. 0,1 24.17 24.15 0.780 0.780 115.0 62.0 80.0 24.65 1183.34 0.02 1.16 15.09 724.19 0.612 9-Apr 13:00 205.0 64 Adj. 0.1 24.17 24.15 39.80 0.780 0.780 115.0 62.0 82.0 24.87 1193.77 0.02 1.16 15.06 722.74 0.605 Page 3.6 Final_Reports I Separator Reading Customer: ARCO Alaska, INC. Well: Bergschrund Well No. 2A Test Number: Initial Test Corppany Rep: Tim Scarbrough Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 5.761 Barton Recorder Range: 1500~ X 100" WC H.E.S. Rep: Steve Myers Storage Tank Coeff: 1.6667 Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas ti (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc, Rate Inc. Rate Inc. Rate GOR CHLORiL~:~' (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (~60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 9-Apr 13:30 201.0 64 Adj, 0,0 23.33 23,33 0.780 0,780 115.0 62.0 820 23.82 1143.36 0.00 0.00 1506 722.74 0.632 9-Apr 13:45 201.0 64 Adj. 0,0 17,50 17.50 0,780 0.780 115.0 62.0 82.0 17.87 1715.28 0.00 0.130 7.53 722.74 0.421 9-Apr 14:00 10-Apr 00:00 10-Apr 06:30 10-Apr 08:00 10-Apr 18:00 11'-Apr O0:00 11-Apr 07:00 11 -Apr 11:00 11-Apr 21:00 12-Apr 07:00 12-Apr 08:00 12-Apr 21:00 13-Apr 07:00 13-Apr 08:00 13-Apr 18:00 Page 3 7 Final ..Report~ / Separator Reading Company: ARCO Alaska, INC, Test Number: Initial Flow HallibuAon Energy Services Wellhead Readings vs Time Well: Bergschrund No. 2A Date: 9-Apr-96 lO00 128 900 800 700 ~ :~ 600 ~ ~o 500 rD rD .- ,~ 400 300 200 100 0 6:00 12:00 18:00 0:00 6:00 12:00 I8:00 Time 0:00 6:00 12:00 -4,-Tubing ~-~ Casing -e--Temperature v._~_ Choke Size 112 96 8O 64 ~ © ½ 32 16 0 18:00 Plot Start Time: 7-Apr-96 6:00 Plot End Time: 9-Apr.6 18:00 Berg I b / Current Wellhead Plot Page no: 4.1 Company: ARCO AIaska !NC, Test Numbea': ~ itia/F~ow Rate vs Time Week Bergschmnd No, 2A Date: 9~Apr.-96 2000 800 1500 '~ ~ 1000 500 0 6:00 12:00 18:00 0:00 6:00 12:00 Ti~e t 8:00 .... ~-- Oi~ -~--- Water/Diesel e- Gas O:00 6:00 12:00 700 600 500 ,~i: 400 ~}: 300:7~ 200 100 0 t8:00 P!ol Stat Time: 7,Apr ~ Current Rate P~ot Page no: 42 Piot End Time: ~,Ap --,c,'x~ ! Oempany ARCO Alaska, ~NC. Test, Number ~nifial Ff©w HaBibu~r~O~ E~ergy Services Fluid Cun3s vs Time We~k Ber0schrund No 2A Date: 9 Ap~.,96 2000 2000 !500 3 1ooo 500 0 6:00 12:00 18:00 0:00 6:00 12:00 !8:00 0:00 Tame 6:00 · ,-~-- Oil -~-- Water/Diesel ---~-· Gas I2:00 1500 1ooo 0 18:00 5O0 P/oi; S~d Time: 7-APR4~ 6:00 Berlb / Culre~'~t Total Cum Plo Page no: 43 Pier End Time; g-APR.-~ Company: ARCO Alaska, INC. Well Number: Bergschrund Well No. 2A Test Number: Initial Test Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Myers Company Rep: Tim Scarbrough Tank Coefficient: 1.6667 i i i Date I Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 ,. Inc. Cum Tot Inc, Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum To (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) .)~1) Pre-FI°w Strap 3.00 5.00 3,00 5.00 0.00 0.00 0.00 0.00 1.00 2.00 23.33 , , , 07-Apr 1'0:.45 0,00 0.00 0.00 0.00 1.00 2.00 Q00 , 07-Apr i1'00 0.00 0.00 0.00 0.00 1.00 4,00 3.33 3.33 07-Apr 11:30 0.00 0.00 0.00 0.00 1.00 8.00 6.67 10.00 07-Apr 12':00 0.00 0.00 0.00 0.00 1.00 10.00 3.33 13.33 07-Apr 12:30 0.00 0.00 0.00 0.00 2.00 2.50 7.50 20.83 07-Apr 13:00 0.00 0.00 0.00 0.00 2.00 6.50 6.67 27.50 07-Apr 13:30 0.00 0.00 0.00 0.00 3.00 2.50 13.33 40.83 07-Apr 14:00 0.00 0.00 0.00 0.00 4.00 2.50 20.00 !83 . 07-Apr 14:30 0.00 0.00 0.00 0.00 4.00 3.50 1.67 62.50 07-Apr 15:00 3.00 0.00 0.00 0.00 0.00 4.00 10.00 10.83 73.33 07-Apr 16:00 10.00 11.67 11.67 3.00 0.00 0.00 0.00 0.00 07-Apr 16:30 10.00 0.00 11.67 11.50 14.17 14.17 0.00 0.00 0.00 07-Apr 17:00 1.00 7.00 15.00 26.67 11.50 0.00 14.17 0.00 0.00 0.00 07-Apr 17:30 1.00 7.00 0.00 26.67 1.00 10.00 17.50 31.67 0.00 0.00 0.00 07-Apr 18:00 2.00 4.50 15.83 42.50 1.00 10.00 0.00 31.67 0.00 0.00 0.00 =. 07-Apr 18:30 2.00 4.50 0.00 42.50 2.00 725 15.42 47.08 0.00 0.00 0.00 Page no' 6.1.1 Berl b / Tank Farm 1 thru 5 Halliburton Energy Services company: ARCO Alaska, INC. Well Number: Bergschrund Well No. 2A Test Number: Initial Test Tank Farm Strap Sheet HES Rep: Steve Myers Company Rep: Tim Scarbrough Tank Coefficient: 1.6667 Date / Time. Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 : .... Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc, Cum Tot Inc. Cum To! , (ff.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ff.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ff.) (in.) (bbls) il) 07-Apr 19:O0 3.00 1,25 14.58 57.08 2.00 7.25 0.00 47.08 0.00 0.00 0.00 07-Apr 19:30 3.00 1.25 0.00 57.08 3,00 5.50 17.08 64.17 0.00 0.00 0_00 07-Apr 20:00 3.00 11.00 16.25 73.33 3.00 5.50 0.00 64.17 0.00 0.00 0.00 07-Apr 20:30 3.00 11.00 0.00 73.33 4.00 3.50 16.67 80.83 0.00 0.00 0,00 07-Apr 21'00 4.00 8,25 15.42 88.75 4.00 3.50 0.00 80.83 0.00 0.00 0.00 07-Apr 21'30 400 8.25 0.00 88.75 5.00 1.25 16.25 97.09 0.00 0.00 0.00 [ ,, 07-APr 22:00 5,00 6.00 1625 105.00 5.00 1.25 0.00 97.09 0.00 0,00 0.00 . 07-Apr 22:30 5.00 6.00 0.00 105.00 5.00 8.00 11.25 108.34 0.00 0.00 0.00 07-Apr 23:00 5.00 9.50 5.83 110.84 5.00 8.00 0.00 108.34 0.00 0.00 0.00 07-Apr 23:30 5.00 9.50 0.00 110.84 5.00 8.50 0.83 109.17 0.00 0.00 ~0 L 08-Apr 0:00 6.00 0.50 5.00 115.84 5.00 8.50 0.00 109.17 0.00 0.00 0.00 08-Apr 0:30 6.00 0.50 0.00 115.84 600 8.75 20.42 129,59 0.00 0.00 0.00 08-Apr 1:00 6.00 11.00 17.50 133.34 6.00 8.75 0.00 129.59 0.00 0.00 0.00 08-Apr 1'30 6.00 11.00 0.00 133.34 7.00 6.00 15.42 145.00 0.00 0.00 0.00 08-Apr 2:00 7.00 10.75 19.58 152.92 7.00 6.00 0.00 145.00 0.00 0.00 0.00 08-Apr 2:30 7.00 10.75 0.00 152.92 8.00 4.50 17.50 162.50 0.00 0.00 0.00 08-Apr 3:00 8.00 8.75 16.67 169.59 8.00 4.50 0.00 162.50 0.00 0.00 0.130 08-Apr 3:30 8.00 8.75 0.00 169.59 9.00 4.00 19.17 181.67 0.00 0.00 0.00 Page no: 6.1.2 Berlb / Tank Farm I thru 5 Company: ARCO Alaska, INC. Well Number: Bergschrund Well No. 2A Test Number: Initial Test Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Myers Company Rep: Tim Scarbrough Tank Coefficient: 1.6667 Date / Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot, Inc. Cum Tot (ff.) (in.) (bbls) (bbl) (ff.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft,) (in.) (bbls) 08-APr 4:00 9.00 8.50 19.58 189.17 900 4.00 0.00 181.67 0.00 0.00 0.00 08-Apr 4:30 9.00 8.50 Q00 189.17 10.00 3.50 19,17 200.84 0.00 0.00 0.00 08-Apr 5:00 10,00 8.00 19.17 208,34 10.00 3,50 0.00 200.84 0.00 0.00 0,00 08-Apr 5:30 10.00 8.00 0,00 208,34 11.00 4.00 20.83 221.67 0.00 0.00 0.00 08-Apr 6:00 11.00 8.00 20.00 228.34 11.00 4.00 0.00 221.67 0.00 0.00 0.00 08-Apr 6:30 11.00 8.00 0.00 228.34 12.00 3.50 19.17 240.84 Q00 0.00 0.00 0.00 08-Apr 7:00 0.00 0.00 1.00 0.50 20.83 20.83 0.00 0.00 0.00 08-Apr 7:30 0.00 0.00 1.00 0.50 0.00 20.83 11.50 19.17 19.17 0.00 08-Apr 8:00 0.00 0.00 2.00 0.50 20.00 40.83 11.50 0.00 19.17 0.00 ,, 08-Apr 8:30 0.00 0.00 2.00 0.50 0.00 40.83 1.00 11.50 20,00 39.17 08-Apr 9:00 0.00 0.00 3.00 3.50 25.00 65.83 1.00 11.50 0.00 39.17 0.00 08-Apr 9:30 0.00 0.00 3.00 3.50 0.00 65.83 2.00 10.50 18.33 57.50 0.00 08-Apr 10:00 0.00 0.00 4.00 4.50 21.67 87.50 2.00 10.50 0.00 57.50 0.00 08-Apr 10:30 0.00 0.00 4.00 4.50 0.00 87.50 4.00 1.00 24.17 81.67 0.00 08-Apr 11:00 0.00 0.00 5.00 6.00 22.50 110.00 4.00 1.00 0.00 81.67 0.00 08-Apr 11'30 0.00 0.00 5.00 6.00 0.00 110.00 5.00 2.00 21.67 103.34 0.00 08-Apr 12:00 0.00 0.00 6.00 8.00 23.33 133.34 5.00 2.00 0.00 103.34 0,00 08-Apr 12:30 0.00 0.00 6.00 8.00 0.00 133.34 6.00 3.00 21.67 125.00 0.00 __ Page no' 6.1.3 Berlb / Tank Farm I thru 5 Halliburton Energy Services Company: ARCO Alaska, INC. Well Number: Bergschrund Well No. 2A Test Number: Initial Test Tank Farm Strap Sheet HES Rep: Steve Myers Company Rep: Tim Scarbrough Tank Coefficient: 1,6667 i Date / Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum To! (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) ')1) 08-Apr 13:O0 0.00 0,00 7.00 5.00 15.00 148.34 6.00 3.00 0,00 125.00 0.00 ,, 08-Apr 13:30 0.00 0.00 7.00 5.00 0.00 148.34 7.00 6.00 25.00 150.00 0.00 08-Apr 14:00 0.00 0.00 8.00 6.00 21.67 170.00 7.00 6.00 0.00 150.00 0.00 08-Apr 14:30 0.00 0.00 8.00 6,00 0.00 170,00 8.00 6.50 20,83 170,84 0.00 08-Apr 15:00 0.00 0.00 9.00 8,00 23.33 193.34 8.00 6.50 0.00 170.84 0.00 08-Apr 15:30 0.00 0.00 9.00 8.00 0.00 193.34 9.00 9.50 25.00 195.84 0.00 08-Apr 16:00 0,00 0.00 10.00 10.00 23.33 216.67 9.00 9.50 Q00 195.84 0.00 08-Apr 16:30 0.00 0.00 10.00 10.00 0.00 216.67 11.00 1.00 25.83 221.67 0.00 08-Apr 17:00 0.00 0.00 12.00 0.00 23.33 240.00 11.00 1.00 0.00 221.67 0.00 08-Apr 17:30 0.00 0.00 12.00 Q00 0.00 240.00 11.00 11.50 17.50 239.17 '~0 08-Apr 18:00 0.00 0.00 13.00 1.50 22.50 262.51 11.00 11.50 0,00 239.17 0.00 08-Apr 18:30 0.00 0.00 13.00 1.50 0.00 262.51 13.00 3.50 26.67 265.84 0.00 08-Apr 19:00 0.00 0.00 14.00 3.50 23.33 285.84 13.00 3.50 0.00 265.84 0.00 08-Apr 19:30 Q00 0.00 14.00 3.50 0.00 285.84 14.00 7,00 25.83 291.67 0.00 ., 08-Apr 20:00 0.00 1.50 0.00 15.00 5.25 22.92 308.76 0.00 0.00 08-Apr 20:30 1.00 0.00 1.00 4.00 24.17 24,17 0.00 0.00 0.00 08-Apr 21:00 1.00 5.00 26.67 26.67 1.00 4.00 0.00 24.17 0.00 0.00 0.00 08-Apr 21'30 1.00 5.00 0,00 26.67 2.00 6.00 23.33 47.50 0.00 0.00 0.00 Page no: 6.1.4 Berlb / Tank Farm I thru 5 Company: ARCO Alaska, INC. Well Number: Bergschrund Well No. 2A Test Number: Initial Test Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Myers Company Rep: Tim Scarbrough Tank Coefficient: 1.6667 i Date / Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (ff.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) -~_._. 08-Apr 22:00 2.00 10.50 29.17 55.83 2.00 6.00 0.00 47.50 0.00 0.00 Q00 08-Apr 22:30 2.00 10.50 0.00 55,83 3.00 8.50 24.17 71.67 0.00 0.00 0.00 08-Apr 23:00 3.00 7.50 15.00 70.83 3.00 8.50 0.00 71.67 0.00 0.00 0.00 08-Apr 23:30 3.00 7.50 0.00 70.83 4.00 9.25 21.25 92.92 0.00 0.00 0.00 09-Apr 0:00 4.00 10.00 24.17 95.00 4.00 9.25 0.00 92.92 0.00 0.00 0.00 09-Apr 0:30 4.00 10.00 0.00 95.00 5.00 10.50 22.08 115.00 0.00 0.00 0.00 09-Apr 1:00 5.00 10.50 20.83 115.84 5.00 10.50 0.00 115.00 0.00 0.00 0.00 09-Apr 1:30 5.00 10.50 0.00 115.84 6.00 8.75 17.08 132.09 0.00 0.00 0.00 09-Apr 2:00 7.00 0.75 23.75 139.59 6.00 8.75 0.00 132.09 0.00 0.00 0.00 09-Apr 2:30 7.00 0.75 0.00 139.59 8.00 3.00 30.42 162.50 0.00 0.00 "'~0 09-Apr 3:00 8.00 8.00 32.08 171.67 8.00 3.00 0.00 162.50 0.00 0.00 0.00 09-Apr 3:30 8.00 8.00 0.00 171.67 9.00 6.00 25.00 187.50 0.00 0.00 0.00 09-Apr 4:00 9.00 4.00 13.33 185.00 9.00 6.00 0.00 187,50 0.00 0.00 0.00 09-Apr 4:30 9.00 4.00 0.00 185.00 10.00 2.25 13.75 201.25 0.00 0.00 0.00 09-Apr 5:00 10.00 6.00 23.33 208.34 10.00 2.25 0.00 201.25 0.00 0.00 0.00 , 09-Apr 5:30 10.00 6.00 0.00 208.34 11.00 9.00 31.25 232.50 0.00 0.00 0.00 09-Apr 6:00 11.00 8.00 23.33 231.67 11.00 9.00 0.00 232,50 0.00 0.00 0.00 09-Apr 6:30 11.00 8.00 0.00 231.67 13.00 0.00 25.00 257.51 0.00 0.00 0.00 ,, Page no: 6.1.5 Berlb/Tank Farm I thru 5 Company: ARCO Alaska. INC. Well Number: Bergschrund Well No. 2A Test Number: Initial Test Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Myers Company Rep: Tim Scarbrough Tank Coefficient: 1.6667 Date / Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum To (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) ?1)_ 09-Apr 7:00 12.00 9.00 21.67 253.34 13.00 0.00 0.00 257.51 0.00 0.00 0.00 09-Apr 7:30 0.00 14.00 2.00 23.33 280.84 2.00 1.00 0.00 0.00 0.00 09,Apr 8:00 0.00 0.00 3.00 2.50 22.50 22.50 2.00 8.00 0.00 0.00 09~Apr 8:30 0.00 0.00 3.00 2.50 0.00 22.50 3.00 10.00 23.33 23.33 0.00 09-Apr 9:00 0.00 0.00 4.00 4.50 23.33 45.83 3.00 10.00 0.00 23.33 0.00 09-Apr 9:30 0.00 0.00 4.00 4.50 0.00 45.83 5.00 0.00 23.33 46.67 0.00 09-Apr 10:00 0.00 0.00 5.00 6.50 23.33 69.17 5.00 0.00 0.00 46.67 0.00 09-Apr 10:30 0.00 0.00 5.00 6.50 0.00 69.17 6.00 2.25 23.75 70.42 0.00 09-Apr 11'00 0.00 0.00 6.00 9.00 24.17 93.34 6.00 2.25 0.00 70.42 0.00 09-Apr .11'30 0.00 0.00 6.00 9.00 0.00 93.34 7.00 4.50 23.75 94.17 il0 09-Apr 12:00 0.00 0.00 7.00 10.50 22.50 115.84 7.00 4.50 0.00 94.17 0.00 09-Apr 12:30 0.00 0.00 7.00 10.50 0.00 115.84 8.00 7.00 24.17 118.34 0.00 09-Apr 13:00 0.00 0.00 9.00 1.00 24.17 140.00 8.00 7.00 0.00 118.34 0.00 09-Apr 13:30 0.00 0.00 9.00 1.00 0.00 140.00 9.00 9.00 23.33 141.67 0.00 09-Apr 13:45 0.00 0.00 9.00 11.50 17.50 157.50 0.00 0.00 Post-Flow Strap 2.00 3.33 2.00 3.33 5.00 10.25 117.09 7.00 11.67 8.00 13.33 I Page no: 6.1.6 Berlb / Tank Farm 1 thru 5 Halliburton Energy Services Tank Farm Transfer Summary Company: ARCO Alaska, INC. Well Number: Bergschrund Well No. 2A Test Number: Initial Test HES Rep: Steve Myers Company Rep: Tim Scarbrough Tank Coefficient: 1.6667 Date / Time Truck Tank Starting Strap Ending Strap Vol Cum Number Number Transferred Volumn (dd-mm hh:mm) (ft) (in) (bbls) (ft) (in) (bbls) (bbl) (bbl) 08-Apr 9:50 2005 1 11.00 8.00 233.34 1.00 1.67 231.67 231.67 08-Apr 13:50 143-014 5 4.00 6.50 90.84 8.00 13.33 77.50 309.17 08-Apr 15:54 3005 2 12.00 3.50 245.84 1.50 2.50 243.34 552.51 08-Apr 20:00 2018 4 14.00 7.00 291.67 3.00 3.00 65.00 226.67 779.18 09-Apr 1:00 2018 3 15.00 5.25 308.76 2.00 1.00 41.67 267.09 1046.27 09-Apr 9:00 3005 1 12.00 9.00 255.01 2.00 3.33 251.67 1297.94 09-Apr 13:30 3005 2 14.00 2.00 283.34 2.00 3.33 280.01 1577.95 09-Apr 20:43 3005 4 9.00 9.00 195.00 7.00 11.67 183.34 1761.29 09-Apr 21:40 3005 3 9.00 11.50 199.17 5.00 10.25 117.09 82.08 1843.37 Page 7.1 Berg1 b / Tank Transfer Data Halliburton Energy Services Tank Farm Totals Summary Company: ARCO Alaska, INC. Well Number: Bergschrund Well No. 2A Test Number: Initial Test H.E.S. Rep: Steve Myers Company Rep: Tim Scarbrough Tank Coefficient: 1.6667 Date / Time Tank Pre-Flow Total Flow Total Vacuum Post-Vac Volume3 Number Volume (A) Volume (B) Volume (C) Volume (D) (A+B)-(C*D) (dd-mm-yy hh:mm) (bbl) (bbl) (bbl) (bbl) (bbl) 08-Mar-96 10:00 1 5.00 481.68 483.34 3.33 (0.00) 08-Mar-96 10:00 2 500! 521.68 523.34 3.33 (0.00) 08-Mar-96 10:00 3 0.00 466.26 349.17 117.09 0.00 08-Mar-96 10:00 4 0.00 433.34 410.01 11.67 11.67 08-Mar-96 10:00 5 23.33 73.33 77.50 13.33 5.83 6 0.00 0.00 0.00 0.00 0.00 7 0.00 0.00 0.00 0.00 0.00 8 0.00 0.00 0.00 0.00 0.00 9 0.00 0.00 0.00 0.00 0.00 10 0.00 0.00 0.00 0.00 0.00 Fracl 0.00 0.00 0.00 0.00 0.00 Frac2 0.00 0.00 0.00 0,00 0.00 Frac3 0.00 0.00 0.00 0.00 0.00 i Fluid Splits At Recorded Conditions To Correlate To Tank Volumes. Oil (bbl) 1899.27 Fluid Split Water2 (bbl) 13.98 Diesel~ (bbl) 63.00 Notes: ~' Estimated By Customer. 2 Includes solids and gel fluids.(BS&W) 3 Volume Difference Due To Ueasurments, Expansion or Contraction. Page 8.1 Berl b / Tank Farm Summary STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION SUNDRY APPROVALS 1. Type ot Request; Abandon_ Suspend X V'Operatlon Shutdown _ Re.enter suspended well _ Alter casing _ Repair well Plugging _ Time extension _ Stimulate Change approved program_ Pull tubing _ Variance _ Perforate _ Other _ ;~. Name of Operator ARCO Alaska, tnc,, __ 3. Address Box 100360, Anchorage, AK 9951O 5. Type of Well: Development Exploratory Stratigraphic Service 4. Locstion of well at surface 964' FNL, 1370' FWL, Sec. 9, T11N, RSE, UM At top of productive interval 458' FSL, 58' FWL, Sec 4, TllN, RSE, L~ At effective depth ~R[~[~ At total depth 530'FSL, 3'FWL, Sec. 4, T11N, ~ErUM 12. Present well ~ndEIon summa~ Total Depth: measured 7896' ~eet true vertical 750 8' ~eet L 6. Datum elevation (DF or KB) FtKB 42' Above SL _ 7. unit or Property name N/A $. Well number @F,.RGSCH RU._N_D_ #2A 9. Permit number 96 -33 10. APl number 5o-1 03-20:237..-01 _ 11. Field/Pool Wildcat Effective depth: measured 7 3 6 8 ' feet true vertical 6 9 8 8' feet Casing Length Size Cemented Structural Conductor 8 O' 1 6" 350 SX AS I Surface 1787' 9-5/8" 335 Sx AS III & Intermediate 550 Sx AS I Production 7 8 2 6' 7" 270 Sx Class G Uner Pedoratian depth: measured: 7368'.7454' MD True vertical: 6988'-?074' TV[:) Measured depth True vertical depth 110' 110' 1827' 1827' 7866' 7478' Operator proposes to suspend well for potential future use as a service well per AOGCC regulations. Tubing (size, grade, and measured depth' 3-1/:2' 9.3# LB0 I::UE 8rd Modified, Tubing Tail at 7180' WLM RKB Packers and SSSV (type and measured depth): Baker FAB-1 set @ 7165' WLM RK8 13, Aztachments Description summary of proposal ~ Proposed suspension procedure and planned wellbore 14_ Estimated dale for commencing operation (Suspension Date) ~,Dril 12,199~ 16. If proposal was verbally approved Name of approver Date approved Detailed operation program _ BOP sketch_ status diagram 15. Status of well classification as: 011 ~ Gas _ Suspended _ Service 17. I hereb, y certify that th~ foregoing ? is true and correct to the best of my knowledge. Title Senior Ddllincj _l=n~ineer FOR COMMISSION USE ONLY Mechanical Integrity Tes~ t~x. 10- '7" / Approved by the order of the Com~~ Commissioner F'orm 1~403 dev 06/15/88 ~ IIApPr°~a'l -{(P- No~ ~. SUBMIT IN TRIPUCATE Bergschrund #2A Proposed Suspension Procedure P roc.e_d.u re: . . , . Following off-rig well:testing, and prior to Coiled Tubing Unit (CTU) ardval, pull back pressure valve if previously installed, RIH with slickline and pull prong from 'XN' Nipple below production packer. Monitor well pressures. Pull blanking plug from 'XN' Nipple. After pulling blanking plug, tag plugback depth and correlate back to RKB depths with slickline. Use Tubing End Locator (TEL) on slickline to assist in correlation. POOH with slickline. Mobilize and rig up Coiled Tubing Unit (CTU) for well suspension operation. Notify AOGCO 24 hours in advance of all pressure testing and well suspension operations. AOGCC has option to observe ail plug setting operations. AOGCC Field Inspector Contact Numbers: Pager: 659-3607 Truck: 659-3870 Office: 279-1433 Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. Nipple up CTU to 3-1/2" Otis union above swab valve. Rig up pit system as required to handle returns from well. 5. Nipple up CTU "Quad" BOP Stack with: 6, . , a. Two (2) sets of blind / shear rams One (1) set of pipe rams One (1) set of slip rams Rig up stripper above BOP Stack. Rig up to take returns from annulus as required with choke and route into horizontal tiger tank. Pressure test all surface equipment and lines to 300 psi Iow and 4000 psi high. Be sure to use diesel or other non-freezing fluid for pressure testing. Bullhead seawater into peals to kill well. RIH with 1-3/4" coiled tubing with 2- 1/8" motor and 2-1/2" cutter with blades to cut 4-1/2" tubing. Tag PBTD. Correlate back to slickline PBTD and flag coil 9. Puli up to 7180' cutter depth. Cut 4-1/2" tubing tail at 7180'. POOH. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. RIH with 1-3/4" coil with 2.5" sand/cement nozzle. Tag PBTD. Flag coil at PBTD. Circulate and condition for spotting of sand plug across perforations. Circulate bottoms up. Rig up Dowell and batch mix 20-40 mesh sand plug(s) to spot sand in well from PBTD and upward to cover perforations. Spot plugs in stages as required. Cover all perfs with sand; allow sand to settle out of gel. "Dry" tag top of sand plug to verify placement. Flag coil at top of sand plug. Place top of sand plug 25 feet above top perforation. Pull up with coiled tubing nozzle above sand plug and circulate bottoms up. Pull up to tubing tail and continue to circulate at minimum rate. Batch mix and pump a densified cement plug, mixed at 17.0 ppg, blended with 4.5 ppb nylon fibers, right above sand plug which was previously placed across perfs. Lower nozzle to just above sand plug when cement reaches nozzle. Use coil flag to verify position. Spot 120' long balanced cement plug on top of sand plug. Cement plug is densified and blended with fibers for potential use as a horizontal sidetrack kickoff plug using a CTU at a later date. Follow cement with 1.5# biozan gel for cement clean-out. Pull out of cement plug slowly, and pull up to bottom of tubing. Circulate bottoms up. Wait on cement. Continue to circulate at minimum rate to prevent CTU freezing. RIH and tag up on top of cement plug to verify placement (AOGCC has option to witness tag). Circulate bottoms up using kill weight brine. Increase weight of kill weight bdne to compensate for diesel placed at top of well for freeze protection. Displace all seawater with kill weight brine. POOH with coiled tubing. Freeze protect top 1000 feet of 3-1/2" tubing with diesel on TOH. RIH with slickline and set plug in 'XN' Nipple in tubing tailpipe. Pressure test tubing to 4000 psi against XN plug, cement plug, and sand plug to ensure pen's are isolated below packer. Pressure test annulus to 4000 psi to check for any packer leakage. Shut in well on tubing and on tubing annulus. Monitor guages on both sides. Rig up Dowell on 9-5/8" x 7" annulus. Pressure test lines to 3000 psi. Pump into 9-5/8" x 7" annulus using kill weight brine. Establish injection rate into 7" annulus. Monitor wellhead guages. 22. 23. 24. 25. Batch mix and pump 15.8 ppg Arctic,set I cement into 7" annulus to fill up from 9-.5/8" shoe at 1827' to surface. Do not exceed 2000 psi injection pressure while placing cement. Clear lines and shut down pumps. Break off Dowell and clean up. Shut in 7" annulus. Monitor and secure well. Close valves and install guages on tubing and tubing annulus for monitoring well during suspension period. Install VR plug in tubinghead wing valve. Install back pressure valve in tubing hanger. Clear ice pad location and demob all matedal and equipment for season. F J, 4/11/96 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Fred Jotmson Senior Drilling Engineer Kuparuk Drill Site Developraem ATO 1292 Phone 265-1492 Fax 265-6224 April 11, 1996 Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 (907) 276-7542 (fax) Re: Proposed Well Suspension Procedure Bergschrund #2A APl #50-103-20232-01 Permit No. 96-033 "TIGHT HOLE" Gentlemen' ARCO is currently concluding testing operations on the above referenced well. ARCO plans to suspend this well for potential later use as a service well pursuant to 20 AAC 25.110. As previously submitted weekly status updates have indicated, ARCO believes this well is justified for suspension since the well results and market conditions meet the requirements of 20 AAC 25.110. ARCO can provide additional confidential well data and information regarding this operation to the AOGCC upon request. Pursuant to 20 AAC 25.110 (c), the AOGCC regulations require the well to be plugged as per 20 AAC 25.105. In addition, the Commission requires "the operator to set a bridge plug between 200 and 300 feet below the casing head and cap with 100 linear feet of cement". ARCO requests an exception to these requirements detailed in 20 AAO 25.105, and is proposing a suspension procedure for this well as detailed on the attachment. In short, this procedure calls for the placement of sand plugs across the perforations (see attached well schematic), with a cement plug set above the peris on top of the sand plugs. This cement plug would be positioned below the packer. Ag, CO Alike, lac. is a Subsidiary o£ ^tlaaticRid'a'i:ldCotreanv This concept allows re-entry to the well at a later date utilizing coiled tubing technology to drill out the cement and sand plugs, thus avoiding cementation of the perfs. This plan eliminates the need for re-perforation upon re-entry. This plan also allows the well to be sidetracked later using coiled tubing, using the cement plug above the perfs as the kickoff plug for cutting a window in the 7" production casing. Following the setting of the sand and cement plugs below the packer, kill weight brine would be circulated throughout the well. The weight of the brine would be increased to compensate for the loss in hydrostatic pressure created by the placement of +/- 1000 feet of non-freezing diesel in the tubing and tubing annulus at the surface. Next, a plug would be set and pressure tested in the 'XN' profile in tubing tailpipe above the packer. The tubing annulus would also be pressure tested to verify integrity. Finally, the 9-5/8" x 7" annulus would be cemented using the downsqueeze method with cement being pumped of sufficient volume to fill the entire annulus down to the 9- 5/8" casing shoe. This suspension program allows for several measures of defense against movement of wellbore fluids. The sand plugs across the perfs, plus the tagged cement plug above the sand plug provides primary perf isolation. The packer and plug in the 'XN' profile provides a second measure of defense. And the kill weight brine, compensated for the diesel caps at surface, provides ~ third measure of defense against wellbore fluid movement. Please note that the well can readily be P&A'd later without a rig if necessary to set the necessary surface plug required by AOGCC regulations. Since this supension operation is to commence in the near future, ARCO is asking for a ruling on this request in the next couple of days if possible. We appreciate your consideration of this proposal. You will notice that the well is considered a "TIGHT HOLE", and we would request that your office maintain the information on this well accordingly. If you have any questions or require any additional information on this project, please contact me at 265-1492. Sincerely, Fred Johnson Senior Drilling Engineer Kuparuk Bdll Site Development ARCO Alaska, Inc. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DaVid Johns~//n, Chairman ",~' :' IHRU: Blair Wond~'eli, P. I. Supervisor ~'~ F:ROM: Bo~by F:oster,~~ Petroleum Inspoctor DATE: FILE NO: SUBJECT: April 16, 1996 OP91DPDD.doc Operation Shutdown Plug ARCO - Exploration Bergschuard #2A PTD # 96-0033 Tuesday, April 16, 1.996: i traveled this date to ARCO's Colville River exploration well Bergschuard 2A to witness the tagging of the cement plug set in the 7" casing to suspend operations for the year. ! arrived on location and met with Bill Penrose, ARCO rep., and he informed me that a sand plug had been set from 7,866' to 7,304'. Then a cement plug had been set from 7,304' to 7,223'. Bill called me the previous evening and ask if he could leave the top of the cement approximately 80' above the sand due to the tubing tail being very close. ! called Jack Hartz and discussed this with him and we agreed to it. As the CT unit started in the hole to tag the TOC a hydraulic hose blew and shut the operation down. I departed the location fr another job. ! received a call from Donnie Lutrick, BIl's relief, informing me that the repairs had been completed and the rig was going in the hole to tag the plug. I knew that a rig was moving and ! called Security and they said th eroad was blocked and would be for 7 to 8 hours. I told Donnie to tag the plug and call me with the results. He called back and said tht he tagged the cement with 2,200 lbs. and a pump rate of .5 bbls/min, at 7,220' giving 84' of cement above the sand plug. I gave him permission to preceed with the operation. Summary:_ ! waived the witnessing of the tagging of the cement plug set from 7,304 to 7,220' in preparation for operation shutdown on ARCO's Bergschaurd 2A. Attachment: ARCO Weilbore Schematic ARCO Alaska, Post Ollice 00360 Anchorage, A,.~a 99510-0360 Telephone 90? 276 1215 March 25, 1996 Davict W. Johnston, Chairman Alaska Oil and Gas Conservation Comr~ssion 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Weekly Operations Report ARCO Temptation #1 Permit No. 96-006 ARCO Bergschrund #2A Permit No. 96-033 ARCO Nanuk #1 Perrrdt No. 96-057 Dear Commissioner Johnston, Attached is the weekly operations summary for the ARCO Temptation #1, Bergschrund #2A Sidetrack and Nanuk #1 we~s being drilled in the Co[ville delta a.rea. The Nanuk #1 was drilled to 7630' TI), logged and P&A. The Doyon rig was Then moved back to the Bergschrund ice pad. The Bergschrund #2A is drilling out cement in the surface casing. The Temptation well is drilling surface hole at 1200'. If you have questions or require additional information, please contact Fred Johnson at 265-1 a92. Sincerely, Fred Johnson Drilling Engineer AFi3D-6003 ~3 p.,ECEIVE D Alaska 0il & Gas C~ns. commission FAX 7642_ ....... _ _,.._P' 02/03_ Bergschrund #2A Proposed Suspension N. 3' 5M Masler YaWe M. 3-1/8' SM r-MC Gan IV ruling har~gerwizh 3' ISA EtPV Pm/i;e ~ 3-I/'2' ~3~, L-a0 EU~'Grcl Mo~tZ}gfo hanger CONF[DENTIAL NOTES: I. PhJg will be set in 'XN' NIpple ~t 7131' MO RKO 2. Kill weight brine will be placed in tubing and tubing annulus, plus atmve cement ping below packer, "' 3, Non-freezing diesel "caps" will be place~ In lop 113130' o! .. tubing and tubing annulus. Brine weigM will be increasee lo.- compensate for diesel caps. a. 7" ~ 9-5/8~ annulus will be filled with r, ement. ~ J. 3,1/2' OTIS 'X' Nipple 2.6!3' !O Selective Profi;e @ ?046' MD I. ! jt 3-1/2' J-55 EUE ard MOD H. 3-1/2' x 1-!/2' Cameo MMM mar',0rell (GLM #I) with 48/~4' c~m valve and TG latch. Hand~j ¢>upa installed on mandrel: 6' L-SO on top & 4' J-S5 On I~o~om; Ma~clrel set @ 7C86' MD G. 3,~/2' OTIS 'XN' ~ippie 2,75" 10/2.75' NOGQ vrofile ~ 7131' MD 3-~/2' aal~et 'GBH-2,2' Locator seal assemoh/with 10' seZis (l.0' OO~ @ 7164' MO Baker 'I=A~-I' permane~.! packer 3-1/2~ X ?' ~> 7155' MD RKEt D, ~aker $6al ~ora Extension. 80-40, @ 7166' MD C. XO 4.374" Acme x 4-I/2' EUE @ 7175' MD .:'up it 4-'.. r~' x 5' :2.$# LBO EU/E Sr~ Mo~ @ 7176' MD (Cutoff ~ 71ElO') 7" 26~ L-80 Top of c~emem p.k~o 7.223' . . i20' cement plug above sanci plug Sand plug from PBTD up m a6' above top perf ('/34~3') ~.~. .~'-, Sand Perf$ 7368'-7454' MD Top of Fi~ (perf guns & Tail pipe 7498') PBT9 ~ ;9'74' WLM, TD (.~ 7896', 7' sl~e @ FJ, 4/1 996 4'22P~{ ARCO ALASKA INC No. 8466 ?. 4/b Date- 3/25/96 ARCO ALASEA INCORPORATED WELL SUMPLARY REPORT Page: 1 WELL:BERGSCMRUND #2A RIG:NO RIG WELL ID: AX9336 AFC' AX9336 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: WILDCAT BLOCK: SPUD: START COMP' FINAL: TIGHT HOLE API NUMBER: 50-103-20232-01 03/24/96 (1) TD: 1829'(0) SUPV:DCL 03/25/96 (2) IlD: 1827'( SUPViDCL 0) WA: 0.0 PV/YP: 0/ 0 APIWL: 0.0 NU BOPE Move camp. NU BOPE. Accept rig 0300 hrs. 3/24/96, MW: 8.5 PV/YP: 1/0 APIWL: 0,0 PREP TO DISPLACE W/KCL MUD NU BOPE. Function test BOP. Test BOPE to 250/5000 psi w/ annular to 3000 psi. Tag cement at 1012'. Drill soft cement from 1012' to 1600'. Drill firm cement from 1600' to 1800' RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ~1~ OIL A~¥D GAS CONSERVATION C0~13115SION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 iV~rch 13, 1996 Thomas W. McI~¥, P.-E. Senior Drilling ~eer Kupgn~ Drill Ske Development ATO 1202 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re' Requested annular disposal of cement washdown water from Col¢_tle Delta exploratory wells Dear Mr. McKay: The Commission has received your request for'authorization for disposal of cement washdown water from certain Col¢_lle Delta exploratory wells in the annuli of wells currently being drilled in the Kupamk River Unit. The washdown water would be generated by drilling operations at the following exploratory wells during the 1996 season_' Bergschnmd #2, Bergschrund #2A, Alpine #3, Nanuk #1, Neve #1, Neve #IA, and Temptation #1. Disposal would take place into the annuli of wells being dr/l/ed by Parker Rig #245, for which nnnular disposal h~s already been authorized. We understand that cement washdown water is produced as a result of blending and mixing cement used in drilling wells. It therefore appears that the cement washdown water you propose for annular disposal is a nodmzardous waste associated w/th the act of drilling an oil or gas well for exploratory purposes, within the meaning of AS 31.05.030(e)(2). Ordinarily annular disposal is permitted in well ~nnuli located m the same drill pad as the well generating the waste in question You have explained that the Colville Delta exploratory wells will not have annuli available for disposal operations. The Commission authorizes ARCO Alaska, Inc., to dispose of cement washdown water from the above-listed Colville Delta exploratory wells in the annul/of wells curremly being drilled within the Kuparuk River unit by Parker Rig #245, subject to the existing terms and conditions governing annular disposal in the latter wells. This authorization is for the 1996 drilling season only. Sincerely, J. David Nolten, P~E. Commi~honer /ruckennau Babcock Commissioner ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Thomas W. McKay, P.E. Senior Drilling Engineer Kupaz-uk Dritl Site Development ATO 1202 Phone 265-6890 Fax 265-6224 :~.-"--.- . * .-: . _. __ . ~ ~ ~ .~., .~- ._., ..~ . .. ~. - . . . - _,__~ ~: .~ :.~,.<.~ Februan/28, !996 ;' .:. : Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 (907) 276-7542 (fax) Annular Disposal of Cement Washdown Water Colville Delta Exploratory Wells Re: Gentlemen' ARCO hereby requests a waiver to the AOGCC Regulations (20 AAC 25.080.) covering Annular Disposal of Drilling Waste recently adopted by the Commission on January 31, 1996. This waiver is requested to cover ARCO's Colville Delta exploratory wells currently being drilled during the 1996 winter drilling season. Cement washdown water is an integral part, of any cement job. Cement is used as a means of pressure control in the wells being drilled. Each casing string, sidetrack plug, P&A plug, and other cement plugs mixed for use in drilling wells produce a relatively small amount of cement washccw;, ',va,;er as a result of the cement blending and mixing operation. We are requesting the Commission determine under 20 AAC 25.080. that this washdown water is a waste associated with the act of drilling a well and permitted for annular disposal. Secondly, ARCO requests permission to transport cement washdown water from the Colviile exploratory operations to approved disposal annuli in the Kuparuk River Unit. This waiver is required since cement washdown water is not exempt, and thus cannot be disposed of in Class 2 injection wells in the Kuparuk River Unit. It is also required because the Colville Delta exploratory wells do not have annuli available for annular disposal operations. Normally, the amount of cement washdown water generated for any individual cement job is less than 250 bbls, although it an vary widely depending upon the operation. ARCO Alaska, Inc. is a Subsidiary of AtlandcRichfieldCompany The wells generating cement washdown water needing a waiver this winter include' Bergschrund #2 Bergschrund #2A Alpine #3 Nanuk #1 Neve #i Neve #lA Temptation #1 The destination of ~,'-' waste wou~ k'" the pe,'m;tt~d annuii of the ,,,:ells currently being drilled within the KRU by Parker Rig ~245. The cement washaown water would be pumped into the perm~**=a ann,,lus that Parker Rig 2 .o w~ conna~ted to at that time. Again, the permitted well would be within the Kuparuk River Unit. c,.,,,s~,.,e,at,on ,.,~ this request. If you have any q,,estions or require We appreciate your ~'" ''~ - ~ '-,' , ,,,.,,, any additional information on this matter, please contact me at 265-6890. Sincerely, Thomas W. McKay, P.E':. Senior Drilling Engineer Kuparuk Drill Site Development AROO Alaska, Inc. TONY KHOWLE$, GOVERNOR '"""C" ?CECUP!NE DRWE ANCECP%GE, ALASKA 3G501~3192 9FEi"!E: (S07) 279-143.,3 FAX; (907) 276-7542 Febraazy 29, 1996 W~I/nm S. Isaacscn Dr/lling En=~_neer Kupan~ Dr/Il Ske Development ~CO Aflas, ka,. Inc. P.O. Box 100360 ~,~chomgc, AK 995 I0-0360 Re: request for wa/vet to 20 AAC 25.080(d)(4), :h~nu/ar Disposal of Dr/il/rig WasTe Dear M_r. Isaacson The Commission has receive,4 your request for wzdver ro 20.4~C 25.080(d)(4), wh/ch restr/cm annular disposai of driil/ng waste from dr/JJ/ng opemr/om m we~ on the same pad. The reque~ for waiver is intended for wells ! Q-21 rind LX- !7. ARCO seeks authorization to inje~ dr/illng was'a~s fi-em ~he 4 3/4" hole sect/on ofweLls lQ-21 and LX-t7 into the ann~us ora well az e:~er 3H or ~ parL The . :/4 secaon or,he lQ-21 and 2X- 17 wells w/il be dr/it~ by e/r. Mr Nordic 41 or a ~ii~ mb/ng onk (CTU). Although~ armufi are ava/labie for injemon pu~oses on the iQ and L'~ pM.s, neither Nordic #1 nor the CTU have thc abfiiW ro ~m-ind and inje~ cuttings for annular disoosal purposes. Cnind and injecz capability is svaiiable on Pmrker 245., wkich is driilin=~ on the 3H and'3F 3ZCO has indicated *dmt a Class II disoosai well 'Mil ~o be avaiiable for use dumg the above mentioned dr/]iing oper-~ions. PI~se be adv/sed, tha: in add/non to the czmenz w~.Mown wamr m~r/oned in your ,-ecm~ o~er ,wa~ gene:-~ed ~ dri]Fn= a~vities th~ are aooroved for The Commission hereby grants a waiver m ARCO Ala~ Inc. for we~ lQ-21 and 2X-t7 from the requirements of 20 AAC 25.080(d)(4). b LIIC,JC.-y, C~ Commh~o~ Z. Tuckermaa Bab~ck Commismmm' ARCO Alaska, Inc, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 i215 RECEIVED March 25, 1996 MAR ?- 6 1996 Alaska Oil & Gas Cons. Commission Anchorage David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: ARCO Bergschrund #2A (Sidetrack) Permit No. 96-033 Dear Commissioner Johnston, ARCO Alaska, Inc. is submitting this letter as notification that the bottom hole location of the subject well has been changed slightly from the approved Permit to Drill. The planned bottom hole location has been moved 140' to the northwest so that the target can be penetrated on an existing seismic line. This location change is small and within the normal accuracy of the directional drilling control. This change was discussed with Blair Wondzell. Due to the small location change, Blair did not feel that a 401 revision was required and that a letter notifying AOGCC of the intended change would be sufficient. The revised Bergschrund #2A location is shown below Surface Location: Target Location: TD Location: 1370' FWL, 964' FNL, Sec 9, T1 IN, R5E 20' FWL, 535' FSL, Sec 4, TllN, R5E 88' FEL, 655' FSL, Sec 5, TIIN, R5E Spacing exceptions have been obtained for this target and bottom hole location. If you have questions or require additional information, please contact me at 265-1492 in our Anchorage office. Sincerely, Fred Johnson Diqlling Engineer Kuparuk Drillsite Development AR3B-6003-93 242-2603 OILAND GAS CONSERVATION CO . ION PERMIT TO DRILL 2O AAC 25.OO5 ! la. Type of Work Drill ~ Redrill w 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 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc, KB ht above sea level:40 feet Wildcat 3. Address 6. Property Designation P. O. Box 100360, Anchoracje, AK 99510-0360 ADL-372095/25559 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1370' FWL, 964' FNL, Sec. 9, T11N, R5E, UM N/A ,~tatewide At top of productive interval 8. Well number Number 20' FWL, 535' FSL, Sec. 4, T11N, R5E, UM Ber_aschrund #2A #U63061 0 At total depth 9. Approximate spud date Amount 88' FEL, 655' FSL, Sec. 5, T11N, R5E, UM 3-1-96 $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 20 feet 1 Mile f/ Berc~schrund #2 2560 Lease Acres 7833' RKB MD1 71390' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 2000 feet Maximum hole an~lle 24 de~l Maximum surface 1075 psig At total depth (TVD) 3692 psig 18, Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Lencjth MD TVD MD '['VD linclude stage data/ 2 0" 16" 62.58# B PEB 8 0' 4 0' 4 0' 120' 120' Permafrost Cement 12.25" 9.625" 53.5# L-80 BTC 1760' 40' 40' 1800' 1800' +290 sx AS-Ill, 600 sx AS-1 8.5" 7" 26.0# L-80 BTCMo( 7800' 40' 40' 7833' 7390' +200 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat X 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 foregoing is true and correct to the best of my knowledge Signed jCf.~. ~~,.~ ,,c¢4/¢///~',E/~,4fVC.,/C/Titlle KRU Drillsite Development Supervisor Date ~' - Commission Use Only Permit Number I APl number5 0 - IAppr°val date ISee c°ver letter f°rother requirements Conditions of approval Samples required __Y e s__ N o Mud log required __ Y e s __ N o Hydrogen sulfide measures__ Ye s __ N o Directional survey required __Yes __ N o Required working pressure forBOPE __2M; __ 3M; __ 5M; __ 10M' __ 1 5M Other: by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission ;. Re: The application of ARCO Alaska, Inc. for exception to 20 AAC 25.055 to allow drilling the Bergschrund No. 2A delineation oil well. ARCO Alaska, Inc. by letter dated February 22, 1 996 has requested an exception to the provisions of 20 AAC 25.055(a)(3) for the drilling of a delineation oil well due west of the Kuparuk River Unit and adjacent to the National Petroleum Reserve, Alaska (NPR-A) on the North Slope. The exception would allow ARCO to drill the Bergschrund No. 2A delineation oil well to a bottom-hole location that is closer than 500 feet from a quarter section line. The well will be drilled as a deviated hole with a surface location: 964' from the north line and 1370' from the west line of Section 9, T11N, R5E, Umiat Meridian (UM) and bottomhole location 104' from the south line and 3242' from the west line of Section 3, T11N, R5E, UM. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM March 12, 1996 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 am on March 28, 1996 in conformance with 20 AAC 25.5,$0. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433 after March 12, 1996. If no protest is filed, the Commission will consider the issuance of the order without a hearing. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Diana Fleck at 279-1433 no later than March 21, 1996. _. - /Tuck~;man Bab~-~c~, Commissioner 'Alaska Oil and Gas Conservation Commission Published February 27, 1996 A0-02614038 OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$o GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 16, 1996 Fred Johnson, Ddlling Engineer ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Company Permit # Surf Loc Btmhole Loc Exploratory Bergschrund #2A RD ARCO Alaska Inc 96-O33 1370'FWL, 964'FNL, Sec 09, T11N, R05E, UM 006'FVVL, 550'FSL, Sec 04, T11N, R05E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to re-ddll the above referenced well. The permit to re-ddil does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. An exception to the Hydrogen Suifite requirements 20 AAC 25.065 and an exception to the shale density requirement in 20 AAC 25.033(e,2D) is approved. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed pdor to ddiling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. David W Joh~ton Chairman ~ BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o end Dept of Environmental Conservation - w/o end STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Reddll lb. Type of Well Exploratory X..~__ Stratigraphic Test _ Development Oil _ Re-Entry__ Deepen _ Service _ Development Gas __ Single Zone _ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KB ht above sea level:40 feet Wildcat 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL-372095 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1370' FWL, 964' FNL, Sec. 9, T11N, R5E, UM N/A Statewide At top of productive interval 8. Well number Number 107' FWL, 438' FSL, Sec. 4, T11N, R5E, UM Bergschrund #2A #U630610 At total depth 9. Approximate spud date Amount 6' FWL, 550' FSL, Sec. 4, T11N, R5E, UM 2-20-96 $200,000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 6 feet 1 Mile f/ Bergschrund #2 2560 Lease Acres 7779' RKB MD, 7,390' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 2000 feet Maximum hole angle 22 deg Maximum surface 1075 psig At total depth (TVD) 3692 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~le data) 2 0" 16" 62.58# ~ B PEB 8 0' 3 0' 3 0' 120' 120' Permafrost Cement 12.25" 9.625" 53.5# L-80 BTC 1775' 25' 25' 1800' 1800' _+290 sx AS-Ill, 600 sx AS-1 8.5" 7" 26.0# L-80 BTCMoC 7754' 25' 2 5' 7779' 7390' _~200 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations· Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural . Conductor ;.,-¢:.'-',',,~ ~: i r~ '; Surface ~ % ~--~ ~-¢' ¢,~,- ~ Intermediate Production Perforation depth: measured · true vertical i, 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 foregoing is true and correct to the best of my knowledge Signed,//~/~~~J~ Titlle KRU Drillsite Development Supervisor Date ~ '" Commission Use Only Permi~::~,m_.b~.~,,,.~ IAPl number 5 0 .//d?..~ _,,,2.. 4::~ ..~..' .~..~_.. _ (~/ I Ap~va~.e I See c°ver letter '°r,.~_ . _.4~ ~_~ other requirements Conditions of approval Samples required ,2~_Y e s __ N o Mud log required ~ Y e s __ N o Hydrogen sulfide measures__ Y e s ~ N o Directional survey required ,~Yes __ N o Required working pressure forBOPE __2M; __ 3M · __~ 5M' __ 10M' __ 1 5 M Other: 0rJgJria! Signed By by order of ;_.~/ /, Approved by 13m~iH i/'l~' irthnr-fnrt Commissioner the commission Date~',/! /'~.~/~' Form 10-401 Rev. 7-24-89 Submit ir plicate T/p 1 (-'m~) ADL' 5 :-.73;65x I 1 ~z~.sx 1" NEVE #1 37210~ AAI /7,2.5~. UTP//7.5= : ALK4715 )[ ADL 25558 ,. APC 20.0: 25558 AAI 72.5~,,// _ UTP Bergschrund #2 BHL (COND) .. ALK4717 ADL 25559 UTP 15.1 APC 20= 3-,31 N. K4553 ~DL me RES 3-31-~ 372107 zPC 2o'.'~,,, ; / (COND) i // ADL 25557 - AA~' UTP 16.1x APC 20.0x Bergschrund #2 Surface Location . ~DL-372095 AN 63.9x ~ UTP 16.1xi APC 20~ ALK4557 ADL '. · 372106; .. ;. ADL 3721081 AP~ ADL 372096 ./. '56 AAI BPX 6 UTP 11- , AHC UTP. /i 646 5579 AN 58.75x BPX 33,55x ~, UTP 7.917x 11-11-02 ARCO BERGSCHRUND #2A ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 0 -1000 SURFACE CASING -3000 1800' -2000 -4000 -5000 -6000 -7000 -8000 -9000 -10000 8 9 10 1! 12 13 14 15 16 17 18 ~~,;~j.¢~Q~VALENT MUD WEIGHT (LB/GAL) - ~ 000 SURFACE CASING 1800' -2000 -3000 -4000 ~ -5000 I-- ILl >, -6000 I-- -7000 -8000 -9000 -10000 ARCO BERGSCHRUND #2A ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 8 9 10 11 12 13 14 15 16 17 18 F:~~~'~~D WEIGHT (LB/GAL) JAN I ¢~ 1996 Drilling Hazard Section Bergschrund #2A Surface Hole · None. Well will be sidetracked below the existing 9-5/8" surface casing Production Hole Mud weight should be 9.8-10.0 lb/gal prior to drilling the C-30/K5 interval at 2380'. This interval in offset wells contains gas that is thought to be slightly pressured at 9.6 lb/gal. · Normal drilling precautions should be taken throughout the hole. Bergschrund #2A - General Procedure Application for Permit to Drill January 13, 1996 Bergschrund #2A will be a sidtrack well drilled from below surface casing in the Bergschrund #2 well. The sidetrack will be drilled by the same rig immediately after plugging back the original well. Formation pressures, rig information, mud and cement programs are all the same as shown in the Bergschrund #2 Permit 1) Dress off cement plug with 8-1/2" bit. 2) Test BOP if required. 3) Make up 8-1/2" bit and bottom hole assembly with steerable mud motor and MWD/LWD (GR-Res). Drilll 8-1/2" hole to kickof point at_+2000'. Orient motor and sidetrack out of original hole. Drill 8-1/2" hole to TD as per directional plan. 4) If LWD Icg results are favorable, run and cement 7" casing. 5) Nipple down BOP, nipple up tubing head, nipple up and test lower Xmas Tree. 6) Run cased hole logs if required. 7) Pressure test 7" casing to 3000 psi. 8) Freeze protect 9-5/8" x 7" annulus. 9) Install tubing hanger and back pressure valve. Continue with well test operations or shutdown operations. 10) Clean and abandon location and access road. JAN 1 6 1996 Alasb30it & Gas Cons, Commission Anchorage :'~-~"artical Section Vie~' Colville Bergschrund #2A 1000- 2000- 3000- _r'34000- 5000- 6000- 700O 8O0O -1000 (Vertical Section Angle · 318.0) ...... :. ..... < ...... > ..... .: ...... ! ...... : ...... ~ ...... · ..... < ............ : ...... ! ...... · ..... ~ ........... < ...... ~ ...... : ...... ~ ...... ~ ..... ~ ...... ~ ...... : ...... ! ...... .. ..... ( ...... ) ..... < ...... ~ ...... .. ..... ~ ...... · ..... ~ ...... ...... ~. ..... ; ...... : ..... .:. ........................................... .:. ...... ! ...... : ..... ; ........... .: ...... ~ ...... : ..... ~ ...... ~. ..... : ...... ~ ...... : ...... ! ............ ~ ...... ~ ..... : ...... ~ .......... ~ ...... :. ..... : ...... : ................................................................................................ ~ ................................ ~. ..... ; ...... ; ..... ; ...... ; ...... ... ..... ; ...... ; ..... ; ...... ; ................................. ...... ~ ..... .; ...... ; ..... ,~ ...... · ...... :. ..... ~ ...... ~ ..... .; ...... ! ..... .; ...... ; ...... ; ..... ; ...... ,, ..... ,~ ...... ; ...... :. ..... ; ...... .~ ..... ~ ...... ; ..... .: ...... ~ ..... ... ..... ; ...... ; ..... .: ...... ; ..... ... ..... ; ..................... : ...................................... :. ..... ; ...... ;. ..... .: ...... · ..... .: ...... ; ...... ~ ..... ~ ...... ~ ..... .; ...... ~ ...... ~ ..... ~ ...... ~ ..... ~ ...... ~ ..... .; ...... ~ ..... .·. ..... ; ...... ~ ..... .: ...... ~ ..... ... ..... ; ...... ;. ..... ; ...... ;. ...................................... :. ..... ~ ...... ~ ..... .: ...... . ..... -~ ...... i ...... ~. ..... .~ ...... ,, ..... .: ...... ~ ...... :. ..... ~ ...... .~ ..... < ...... ~ ..... .: ...... ~ ..... ~ ..... ~ ...... ~ ..... .; ...... ~ ..... ~ ..... ~ ...... ;. ..... ~ ...... : ...... · ..... < ...... ) ..... < ............ : ...... 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I 0 1000 2000 3000 4000 5000 Vertical Section (Feet) Plan View Colville Bergschrund #2A (Vertical Section Angle · 318.0) · i ...... ;~ ....... : ........................................................ ~ ........................................ .......... ~ ......... ~. .......... , .......... , .......... ~ .......... , .......................................... ~ ................................................................................................................ ~ .......... ~ ................... ~.~ .....................~ ................................~ ........... ~ ................................................................ ~ ......................................................... ~ .......... ~ ........... ~ .......... ~~.'"~::.:.:~..::.:.~:.:.::~.::.:.:~.:.::7.: ........... ~ .......... ~ ........... ~ .......... ~ .......... ~ ........... ~ .......... ~ .......... ~ .......... ~ ........... .......... ........... ........... :::::::::::::::::::::::::::::::::::::: ........ .................... ...................... .......... .......... ...................... .......... ...................... : -20oo -~oo ~o 2~o ....................................................... ~ .......... ~ .......... ~ .......... ; .......... & ................................................................ ~ ........................................................ ........................................................................................................................................................... ~ ..... ,~ ..... ~ ..... ~.~..~..~..~ ..... ~...~4 ..................... , .......................................................................... *~ ...................................... F~7~"'r'~"~% ...................... East/West (Feet) DPMS Survey Report Bergschrund #2A Field Name: Colville Well Name: Bergschrund #2A Plan Name: Plan 2/8 Elevation: Oft RKB: Oft SHL: Oft & Oft BHL: 7390ft (7779ft MD) @ 1514ft & -1364ft J-4: 7020ft (7379ft MD) @ 1402ft & -1263ft Date Page : 1 : 13/February/96 Interpolated Planned Survey Summary (Vertical Section Angle : 318.0 MD 0 0 100 0 200 0 3O0 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 2736.7 2800.0 2900.0 3000.0 3100.0 3200.0 3300.0 3400.0 3500.0 3600.0 3700.0 3800.0 3900.0 40OO.O 4100.0 Inc 0.00 0.00 0.00 0.00 0.00 0.00 0 00 0 00 0 00 0 00 0 00 0 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 6.00 9.00 12.00 15.00 18.00 21.00 22.10 22.10 22.10 22.10 22.10 22.10 22.10 22.10 22.10 22.10 22.10 22.10 22.10 22.10 22.10 Azm TVD VS N/S 317.99 0.0 0.0 0.0 0.0 317.99 100.0 0.0 0.0 -0.0 317.99 200.0 0.0 0.0 -0.0 317.99 300.0 0.0 0.0 -0.0 317.99 400.0 0.0 0.0 -0.0 317.99 500.0 0.0 0.0 -0.0 317.99 600.0 0.0 0.0 -0.0 317.99 700.0 0.0 0.0 -0.0 317.99 800.0 0.0 0.0 -0.0 317.99 900.0 0.0 0.0 -0.0 317.99 1000.0 0.0 0.0 -0.0 317.99 1100.0 0.0 0.0 -0.0 317.99 1200.0 0.0 0.0 -0.0 317.99 1300.0 0.0 0.0 -0.0 317.99 1400.0 0.0 0.0 -0.0 317.99 1500.0 0.0 0.0 -0.0 317.99 1600.0 0.0 0.0 -0.0 317.99 1700.0 0.0 0.0 -0.0 317.99 1800.0 0.0 0.0 -0.0 317.99 1900.0 0.0 0.0 -0.0 317.99 2000.0 0.0 0.0 0.0 317.99 2100.0 2.6 1.9 -1.8 317.99 2199.6 10.5 7.8 -7.0 317.99 2298.8 23.5 17.5 -15.7 317.99 2397.1 41.7 31.0 -27.9 317.99 2494.3 65.1 48.4 -43.6 317.99 2590.2 93.5 69.4 -62.6 317.99 2684.4 126.9 94.2 -84.9 317.99 2718.6 140.3 104.3 -93.9 317.99 2777.2 164.1 122.0 -109.9 317.99 2869.9 201.8 149.9 -135.0 317.99 2962.5 239.4 177.9 -160.2 317.99 3055.2 277.0 205.8 -185.4 317.99 3147.8 314.6 233.8 -210.6 317.99 3240.5 352.3 261.7 -235.8 317.99 3333.1 389.9 289.7 -261.0 317.99 3425.8 427.5 317.6 -286.1 317.99 3518.4 465.1 345.6 -311.3 317.99 3611.1 502.8 373.5 -336.5 317.99 3703.7 540.4 401.5 -361.7 317.99 3796.4 578.0 429.4 -386.9 317.99 3889.0 615.6 457.4 -412.0 317.99 3981.7 653.3 485.4 -437.2 E/W Build 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Turn Dleg T face 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 0.0 0.0 0.0 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 DPMS Survey Report Bergschrund #2A Page : 2 Date : 13/February/96 Interpolated P lanned Survey Summary MD Inc Azm TVD 4200.0 22.10 317.99 4074.4 4300.0 22.10 317.99 4167.0 4400.0 22.10 317.99 4259.7 4500.0 22.10 317.99 4352.3 4600.0 22.10 317.99 4445.0 4700.0 22.10 317.99 4537.6 4800.0 22.10 317.99 4630.3 4900.0 22.10 317.99 4722.9 5000.0 22.10 317.99 4815.6 5100.0 22.10 317.99 4908.2 5200.0 22.10 317.99 5000.9 5300.0 22.10 317.99 5093.5 5400.0 22.10 317.99 5186.2 5500.0 22.10 317.99 5278.8 5600.0 22.10 317.99 5371.5 5700.0 22.10 317.99 5464.1 5800.0 22.10 317.99 5556.8 5900.0 22.10 317.99 5649.4 6000.0 22.10 317.99 5742.1 6100.0 22.10 317.99 5834.7 6200.0 22.10 317.99 5927.4 6300.0 22.10 317.99 6020.1 6400.0 22.10 317.99 6112.7 6500.0 22.10 317.99 6205.4 6600.0 22.10 317.99 6298.0 6700.0 22.10 317.99 6390.7 6800.0 22.10 317.99 6483.3 6900.0 22.10 317.99 6576.0 7000.0 22.10 317.99 6668.6 7100.0 22.10 317.99 6761.3 7200.0 22.10 317.99 6853.9 7300.0 22.10 317.99 6946.6 7379.2 22.10 317.99 7020.0 7400.0 22.10 317.99 7039.2 7500.0 22.10 317.99 7131.9 7600.0 22.10 317.99 7224.5 7700.0 22.10 317.99 7317.2 7778.6 22.10 317.99 7390.0 (continued VS N/S 690.9 513.3 728.5 541.3 766.1 569.2 803.7 597.2 841.4 625.1 879.0 653.1 916.6 681.0 954.2 709.0 991.9 736.9 1029.5 764.9 1067.1 792.8 1104.7 820.8 1142.4 848.7 1180.0 876.7 1217.6 904.7 1255.2 932.6 1292.8 960.6 1330.5 988.5 1368.1 1016.5 1405.7 1044.4 1443.3 1072.4 1481.0 1100.3 1518.6 1128.3 1556.2 1156.2 1593.8 1184.2 1631.5 1212.1 1669.1 1240.1 1706.7 1268.0 1744.3 1296.0 1782.0 1324.0 1819.6 1351.9 1857.2 1379.9 1887.0 1402.0 1894.8 1407.8 1932.4 1435.8 1970.1 1463.7 2007.7 1491.7 2037.3 1513.6 E/W Build -462.4 0.0 -487.6 -512.8 -538.0 -563.1 -588.3 -613.5 -638.7 -663.9 -689.1 -714.2 -739.4 -764.6 -789.8 -815.0 -840.1 -865.3 -890.5 -915.7 -940.9 -966.1 -991.2 -1016.4 -1041.6 -1066.8 -1092 0 -1117 1 -1142 3 -1167 5 -1192 7 -1217 9 -1243 1 -1263 0 -1268 2 -1293.4 -1318.6 -1343.8 -1363.6 0.0 0.0 0.0 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Turn 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Dleg T face 0.0 0 0 0.0 0 0 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0 0 0 0.0 0 0 0.0 0.0 0.0 0.0 0.0 0 0 0.0 0 0 0.0 0 0 0.0 0 0 0.0 0 0 0.0 0 0 0.0 0 0 0.0 0 0 0.0 0 0 0.0 0 0 0.0 0 0 0.0 0 0 0.0 0 0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 End Of DPMS Survey Report ARCO Alaska, Inc. Post Office Bo× 100350 Anchorage, Alaska 9951 Telephone 907 278 i215 February 13, 1996 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill ARCO Bergschrund #2A (Sidetrack) Dear Commissioner Johnston, ARCO Alaska, Inc. is submitting a revised 401 Application for Permit to Drill an onshore exploratory well, the ARCO Bergschrund #2A (Sidetrack), on State lands near the mouth of the Colville River. The target and TD locations have been changed so that another spacing exception would not be required. The productive interval and TD in this well lie within 500' of a quarter section line. A spacing exception has been approved for a bottom hole location in this 1/4 section. However the well name Bergschrund #4 was used on the spacing exception instead of the conventional Bergschrund #2A sidetrack naming system. The proposed sidetrack will be drilled from the same surface location as the Bergschrund #2 well. This sidetrack will be drilled immediately after plugging back the original Berschrund #2 well. The bottom hole location is approximately one mile northwest of the ARCO Bergschrund #2 well. The same rig, Doyon 141, will be used to drill the sidetrack. Attached to this application letter are Form 401, property ownership map, and directional plan. All other information concerning this well such as rig equipment, formation pressures, mud and cement programs are the same as in the Bergschrund #2. Please replace the old 401 form with the revised one. Estimated spud date for this sidetrack is February 19. ARCO requests that AOGCC review this Application as soon as possible to allow approval in a short time period. Your prompt attention to this matter is appreciated. If you have questions or require additional information, please contact me at 265-1492 in our Anchorage office. Sincerely, Fred Johnson Drilling Engineer Kuparuk Drillsite Development :<ECE!VED FEB 1 :~ l~gG Alaska Oil & Gas Cons, Commission Anchorage AR3B-6003-93 2i2 2603 ARCO Alaska, Inc. , Post Office Box 100360 Anchora§e, Alaska 99510-0360 Telephone 907 2.'76 1215 January 15, 1996 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill ARCO Bergschrund #2A (Sidetrack) Dear Commissioner Johnston, JAN 1 6 Aias~ uN ii Gas Cons, Comr~10a Anffiora~e ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory well, the ARCO Bergschrund #2A (Sidetrack), on State lands near the mouth of the Colville River. ARCO will act as operator for itself, Union Texas Petroleum, and Anadarko Petroleum Corporation in evaluating acreage previously leased by ARCO. The productive interval in this well lies within 500' of a quarter section line. A spacing exception has been applied for. The proposed sidetrack will be drilled from the same surface location as the Bergschrund #2 well. This sidetrack will be drilled immediately after plugging back the original Berschrund #2 well. The bottom hole location is approximately one mile northwest of the ARCO Bergschrund #2 well. The same rig, Doyon 141, will be used to drill the sidetrack. Attached to this application letter are Form 401, property ownership map, anticipated mud weights and formation pressures, directional plan, and drilling proceedure. All other information concerning this well such as rig equipment, formation pressures, mud and cement programs are the same as in the Bergschrund #2 ~'~-~ ,r q~,4'r~.¢/ All waste drilling mud and cuttings generated during the drilling of ,~lp/.e,e-,/dq3 will be hauled to the Kuparuk River Field or Prudhoe Bay Field for temporary storage and eventual processing by ball mill which will grind the cuttings prior to their being injected down an approved disposal well. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. ARCO also requests an exception on 20 AAC 25.033(e,2,D) shale density requirement. The shale density technique does not work well in Alaska due to the variable composition of the shales, and the chemical used in the shale density column is listed as an exceptional health hazard. The Commission is requested to review this application for Permit To Drill as soon as possible to allow approval in a short time period. This is a sidetrack drilling operation from the original wellbore. Drilling operations on the sidetrack will be ready to begin this week. Your prompt attention to this matter is greatly appreciated. ARSB-6003-93 242-2603 Pressure Information Proposed Drilling Fluid Program Pressure Analysis Proposed Drilling Program Fiscally, the following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Weekly Stares Report 2) Completion Report (20 AAC 25.070) Fred Johnson, Drilling Engineer Fred Johnson, Drilling Engineer 265-1492 265-1492 3) Geologic Data and Logs Mark McDermott, Exploration Services 265-6394 (20 AAC 25.071) If you have questions or require additional information, please contact Fred Johnson at 265-1492 or myself at 265-6206 in our Anchorage office. s~~erely, Mike ~ Supervisor Kuparuk Drillsite Development ,JAN I 6 Alaska Oil & Gas Cons. Commission Anchor,s AR3B~6003-93 2d2-2~03 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-31 92 Re: THE APPLICATION OF/~RC0 ) ALASKA, INC. for an (;rder granting an ) exception to spacing requirements of ) Title 20 AAC 25.055 to provide for the ) drilling of seven delineation oil wells in ) the Colville Delta vicinity. ) 'Conservation Order No. 367 ARCO Alaska, Inc. Nanuk No. 1, Neve No. 1, Neve No. lA, Neve No. lB, Temptation No. 1, Alpine No. 3, Bergschrund No. 4, IT APPEARING THAT: January 3, 1996.. I , ARCO Alaska, Inc. submitted applications dated December 7, 1' 995'requesting exceptions to the well spacing provisions of Title 20 AAC 25.055 (3) to allow drilling .the ARCO Neve No. 1, Neve No. lA, Neve No. lB, Nanuk No. 1, Temptation No. 1, Alpine No. ,.3, and Bergschrund No, 4 delineation oil wells to locations within 500 feet of a quarter-section line in the Colville Delta vicinity of the North Slope. · -~ 2. Notice of opportunity for public hearing was published in the Anchorage Daily News on December 15, 1995 pursuant to 20 AAC 25.540. 3. No protests to the applications were received. FINDINGS' 1. The Neve No. 1 delineation oil well as proposed will be drilled as a straight hole at a location 465' from the north line and 2440' from the west line of Section 14, T11N, R4E, Umiat Meridian (UM). 2. The Neve No. lA delineation oil well as proposed will be drilled as a deviated hole with a surface location 465' from the north line and 2440' from the west line of Section 14, T11N, R4E, UM and bottomhole location 2960' from the north line and 530' from the west line of Section 14, T11N, R4E, UM. 3. The Neve No. lB delineation oil well as proposed will be drilled as a deviated hole with a surface location 465' from the north line and 2440' from the west line of Section 14, T11N, R4E, UM and bottomhole location 640' from the south line and 3290' from the west line of Section 11, T11 N, R4E, UM. , The Nanuk No. 1 delineation oil well as proposed will be drilled as a straight hole at a location 2290' from the north line and 1140' from the west line of Section 30, T11N, _ R5E, UM. The Temptation No. 1 delineation oil well as proposed will be drilled as a straight hole at a location 1890' from the south line and 540' from the west line of Section 16, T12N, R4E, UM. o The Alpine No. 3 delineation oil well as proposed will be drilled as a straight hole at a location 2145' from the north line and 2115' from the west line of Section 25, T12N, R4E, UM. Conservation Order No.{~ . "'~,~ January 3, 1996 -. Page 2 : '- '. 7. The Bergschrund No. 4 delineation oil well as proposed will be drilled as a deviated hole with a surface location 960' from the north line and 1620' from the west line of Section 9, T11N, FISE, UM and bottomhole location 535' from the south line and 20' from the west line of Section 4, T11 N, R5E, UM. ? 8. All owners and operators of governmental quarter sections directly and diagonally offsetting the quarter section proposed for each of the subject wells has been duly notified. 9. An exception to the well spacing provisions of Title 20 AAC 25.055 (3) is necessary to allow the drilling of each of the above listed wells. CONCLUSION' Granting a spacing exception to allow drilling of the ARCO Neve No. 1, Neve No. lA, Neve No. lB, Nanuk No. 1, Temptation No. 1, Alpine No. 3 and Bergschrund No. 4 wells will not result in waste nor jeopardize correlative rights. " NOW, THEREFORE, IT IS ORDERED: ARCO Alaska, Inc.'s applications for exception to the well spacing provisions of Title 20 AAC 25.055 (3) for the purpose of drilling the seven wells described above are approved. DONE at Anchorage, Alaska and dated January 3, 1996. Dawd W Johnston, C~nrma~'m ~ Alaska tion Colmission. . J. David Norton, P.E., Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23'd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission Shall grant or refuse the application in whole or in ~art within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, tho 30-day. period for appeal to Superior Court runs from the date on which tho request is deemed denied (i.e., 10th day after the application for rehearing was filed). r- RMIT CHECKLIST F, -LD, POO . . . . COMPANY /~__ ~ INIT CLASS/,////~/ GEOL AREA PROGRAM..' exp~ der [] redrll~ aery ~ wellbore seg [] ADMINI STP~ATION ENGINEERIN.G 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool .............. Y N~ 5. Well located proper distance from drlg unit boundary...Y 6. Well located proper distance from other wells ..... .~ N 7. Sufficient acreage available in drilling unit ..... ~ N 8. If deviated, is wellbore plat included ........ ~3 N 9. Operator only affected par~y .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ~ N 14. Conductor string provided ............... ~ N 7 15. Surface casing protects all known USDWs ........ ~ N~ 16. CMT vol adequate to circulate on conductor & surf csg. ~_Y_ ~ 17. CMT vol adequate to tie-in long string to surf csg . o .~-~Y ~ 18. CMT will cover all known productive horizons ...... Y~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. Y~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved..Y N 22. Adequate wellbore separation proposed .......... Y~ N 23. If diverter required, is it adeqnate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... (Y) N 26. BOPE press rating adequate; test to ~>~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ 28. Work will occur without operation shutdown ....... ~ %~N 29. Is presence of H2S gas probable ............. Y GEOLOGY .REMARKS 30. Permit can be issued w/o hydrogen sulfide measures.. 31. Data presented on potential overpressure zones 32. Seismic analysis of shallow gas zones ....... 33. Seabed condition su~ey (if off-shore)...~~.~.. Y 34. Contact name/phone for weekly progress reports [ ~plorato~ only] Comments/Instructions: DWJ '""~ - A:%FORMS%cheklist rev 11195 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. CONFIDENT AL * * * ALASKA COMPUTING CENTER * * * * ............................ * ....... SCHLUMBERGER ....... * ............................ * COMPANY NAME :'ARCO ALASKA, INC. WELL NAME : BERGSCHRUND #2A FIELD NAME : WILDCAT BOROUGH : NORTH SLOPE STATE : ALASKA API N~VlBER : 501032023201 REFERENCE NO : 96122 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-MAY-1996 15: 44 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/05/ 9 ORIGIN : FLIC REEL NA~IE : 96122 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., BERGSCHRUND #2A, API #50-103-20232-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/05/ 9 ORIGIN : FLIC TAPE NAME : 96122 CONTINUATION # : 1 PREVIOUS TAPE : COI~4ENT . ARCO ALASKA INC., BERGSCHRUND #2A, API #50-103-20232-01 TAPE HEADER WILDCAT MWD/MAD LOGS WELL NAFiE : API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION '. TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1 ST STRING 2ND STRING BERGSCHRUND #2A 501032023201 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 9-MAY-96 BIT RUN 1 BIT RUN 2 BIT RUN 3 96122 96122 96122 ST. AMOUR ST. AMOUR ST. AMOUR 9 liN 5E 984 1370 42.70 41.70 13.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 1827.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-~Y-1996 15: ~4 3RD STRING PRODUCTION STRING REMARKS: THIS TAPE CONTAINS THE MODIFIED LDWG FORMATTED DATA ON ARCO'S BERGSCHRUND #2A WELL. DATA ACQUIRED: LOGGING WHILE DRILLING CDR AND CDN. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: i EDITEDMERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE LDWG TOOL CODE START DEPTH CDR 1721.0 CDN 3912.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 88888.0 1827.0 1823.5 1819.0 1812.0 1806.5 1787.5 100.0 $ FtERGED DATA SOURCE LDWG TOOL CODE CDR CDR CDR CDN CDN STOP DEPTH .......... 7894.0 7790.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... CDR/CDN 88888.0 1827.0 1822.5 1817.5 1812.5 1806.5 1788.5 101.0 BIT RUN NO. BiERGE TOP M~RGE BASE 1 1827.0 4037.0 2 4037.0 5163.0 3 5163.0 7894.0 2 4037.0 5163.0 3 5163.0 7894.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-MAY-1996 15:44 PAGE: REMARKS: THIS FILE CONTAINS MODIFIED LDWG FORMATTED INFORMATION FOR LOGGING WHILE DRILLING CDR AND CDN DATA. THE DATA IN THIS FILE WAS TIED TO SCHLUMBERGER WIRELINE DIPOLE SONIC GAMMA RAY DATED 21-FEB-1996. DATA WAS TIED FROM FIRST READING DOWN TO THE CASING SHOE AT 1827' WHERE THE WELL WAS SIDETRACKED. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA, INC. Company Name FN WILDCAT Field Name WN BERGSCHRUND #2A Well Name APIN 501032023201 API Serial Number FL 1370' FWL & 0964' FNL Field Location SECT 9 Secti on TOWN 1 IN Township RANG 5 E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation LATI 70. 326583N Latitude LONG 150. 892024W Longi rude PDAT MSL Permanent da rum EPD FT O. Elevation of Permanent Datum LMF KB Log Measured From APD FT 42.7 Above Permanent Datum EKB FT 42.7 Elevation of Kelly Bushing EDF FT 41.7 Elevation of Derrick Floor EGL FT 13.1 Elevation of Ground Level TDD FT 7896. Total Depth - Driller TDL FT 7896. Total Depth - Logger BLI FT 7894. Bottom Log Interval TLI FT 1721. Top Log Interval DFD G/C3 10.1 Drilling Fluid Density RMS OH~M 0.35 Resistivity of Mud Sample MST DEGF 65. Mud Sample Temperature RMFS OH~4M 0.272 Resistivity of Mud Filtrate S MFST DEGF 65. Mud Filtrate Sample Temperatu BHT DEGF 153. Bottom Hole Temperature LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-MAY-1996 15:44 PAGE: TABLE TYPE : CURV DEFI DEPT Depth RA CDR ATTN RESISTIVITY RP CDR PHSF RESISTIVITY VRA QRO VERY ENHANCED AMPLITUDE RESISTIVITY VRP QRO VERY EArHANCED PHASE RESISITIVTY DER DIELECTRIC RESISITIVTY ROP RATE OF PENETRATION FET TI~E AFTER BIT GR Gamma Ray RHOB Bulk Density DRHO Del ta RHO PEF PhotoElectric Factor CALN NUCLEAR CALIPER NPHI Thermal Neutron Porosity DEV Hole Deviation AZ Hole Azimuth ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 8 9 11 12 13 14 15 16 0 0.5 FT 16 65 68 65 66 68 66 0 65 FT 66 68 66 1 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-MAY-1996 15:44 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OHI~M O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OHNJ4 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OP~4~ O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OHT~S O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OH~ O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E O0 000 O0 0 1 1 1 4 68 0000000000 CALNMWD IN O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S O0 000 O0 0 1 1 1 4 68 0000000000 DEV MWD DEG O0 000 O0 0 1 1 1 4 68 0000000000 AZ MWD DEG O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7894.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 196.364 FET. MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD C_ALN.MP~ -999.250 NPHI.MWD -999.250 DEV. MWD 9.190 AZ.~D DEPT. 7500.000 RA.MWD 2.798 RP.MWD 2.746 VRA.MWD VRP.MWD 2.753 DER.MWD 2.764 ROP.MWD 55.159 FET.MWD GR.MWD 90.649 RHOB.MWD 2.487 DRHO.MWD -0.008 PEF.MWD CALN.MWD 8.541 NPHI.MWD 26.500 DEV.MWD 10.343 AZ.MWD DEPT. 7000.000 RA.MWD 1.390 RP.MWD 1.233 VRA.MWD VRP.MWD 1.255 DER.MWD 1.289 ROP.MWD 140.749 FET.MWD GR.MWD 287.927 RHOB.MWD 2.331 DRHO.MWD -0.013 PEF.MWD CALN. MWD 8.500 NPHI.MWD 40.400 DEV. MWD 14.156 AZ.MWD DEPT. 6500.000 RA.MWD 5.526 RP.MWD 5.299 VRA.MWD VRP.MWD 5.313 DER.MWD 5.373 ROP.MWD 278.173 FET. MWD GR.MWD 93.112 RHOB.MWD 2.526 DRHO.MWD -0.005 PEF. MWD CALN.MWD 8.615 NPHI.MWD 25.800 DEV. MWD 17.674 AZ.MWD DEPT. 6000.000 ~.MWD 5.171 RP.MWD 4.965 VRA.MWD VRP.MWD 4.934 DER.MWD 5.035 ROP.MWD 237.288 FET.MWD GR.MWD 99.268 RHOB.MWD 2.513 DRHO.MWD 0.006 PEF. MWD CALN. MWD 8.737 NPHI.MWD 28.500 DEV. MWD 22.553 AZ.MWD DEPT. 5500.000 RA.MWD 5.301 RP.MWD 5.537 VRA.MWD VRP.MWD 5.614 DER.MWD 5.464 ROP.MWD 187.336 FET. MWD GR.MWD 88.495 RHOB.MWD 2.519 DRHO.MWD 0.023 PEF.MWD CALN. MWD 8.756 NPHI.MWD 29.600 DEV. MWD 25.617 AZ.MWD -999.250 -999.250 -999.250 325.290 2.887 2.514 3.389 322.121 1.356 1.254 3.596 315.755 5.676 0.688 3.557 316.690 5.176 1.439 3.657 315.300 5. 855 O. 833 3. 815 316.307 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-MAY-1996 15:44 PAGE: DEPT. 5000.000 RA.MWD VRP.MWD 5.303 DER.MWD GR.MWD 83.762 RHOB.MWD CALN.MWD 9.090 NPHI.MWD DEPT. 4500.000 RA.MWD VRP.MWD 4.408 DER.MWD GR.MWD 85.758 RHOB.MWD CALN. MWD 8.689 NPHI.MWD DEPT. 4000.000 RA.MWD VRP.MWD 3.480 DER.MWD GR.MWD 110.644 RHOB.MWD CALN. MWD 9.325 NPHI.MWD 5.397 RP.MWD 5.273 ROP.MWD 2.422 DRHO.MWD 33.000 DEV.MWD 4.479 RP.MWD 4.427 ROP.MWD 2.397 DRHO.MWD 32.100 DEV. MWD 3.524 RP.MWD 3.430 ROP.MWD 2.314 DRHO.MWD 38.300 DEV.MWD DEPT. 3500.000 RA.MWD 6.125 RP.MWD VRP.MWD 5.549 DER.MWD 5.531 ROP.MWD GR.MWD 120.570 RHOB.MWD -999.250 DRHO.MWD CALN.MWD -999.250 NPHI.MWD -999.250 DEV. MWD DEPT. 3000.000 RA.MWD 2.696 RP.MWD VRP.MWD 2.608 DER.MWD 2.640 ROP.MWD GR.MWD 106.739 RHOB.MWD -999.250 DRHO.MWD CALN. MWD -999.250 NPHI.MWD -999.250 DEV. MWD DEPT. 2500. 000 RA.MWD VRP. MWD 3. 796 DER . MWD GR. MWD 95.559 RHOB. MWD CALN.~WD -999.250 NPHI.MWD DEPT. 2000.000 RA.MWD VRP.MWD 2.781 DER.MWD GR.MWD 116.735 RHOB.MWD CALN. MWD -999.250 NPHI.MWD DEPT. 1721.000 RA.MWD VRP.MWD -999.250 DER.MWD GR.MWD 43.819 RHOB.MWD CALN. I~WD -999.250 NPHI.MWD 4.337 RP.MWD 3.800 ROP.MWD -999.250 DRHO.I~WD -999.250 DEV. MWD 3.210 RP.MWD 2.985 ROP.MWD -999.250 DRHO.MWD -999.250 DEV.MWD 5.212 64.057 0.067 25.151 4. 404 264. 336 O. 025 24. 464 3.387 115.389 0.066 24.661 5.327 124.142 -999.250 25.214 2.609 115.045 -999.250 24.093 3.643 86.976 -999.250 17.849 2.887 83.334 -999.250 4.915 -999.250 RP.I4WD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 DEV. MWD -999.250 VRA . MWD FET.MWD PEF. MWD AZ. MWD VRA . MWD FET.MWD PEF. MWD AZ . MWD VRA . MWD FET. MWD PEF.MWD AZ.MWD VRA . MWD FET. MWD PEF. MWD AZ . MWD VRA . MWD FET. MWD PEF. MWD AZ.MWD VRA . MWD FET.MWD PEF. MWD AZ.MWD VRA . MWD FET. MWD PEF. MWD AZ . MWD VRA . MWD FET. MWD PEF. MWD AZ. MWD 5.553 3.333 3.660 314.441 4.505 0.499 3.562 317.685 3.488 -999.250 4.879 319.384 5.876 0.764 -999.250 316.404 2.753 0.887 -999.250 316.683 4.268 0.703 -999.250 316.917 2.947 0.603 -999.250 326.823 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-MAY-1996 15:44 PAGE: **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/05/ 9 ORIGIN .. FLIC TAPE NA~E : 96122 CONTINUATION # : 1 PREVIOUS TAPE : CO~_2TT : ARCO ALASKA INC., BERGSCHRUND #2A, API #50-103-20232-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/05/ 9 ORIGIN : FLIC REEL NAME : 96122 CONTINUATION # : PREVIOUS REEL : CO~4ENT : ARCO ALASKA INC., BERGSCHRUND #2A, API #50-103-20232-01
