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Home My WebLink About195-020T39895 TTT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: AOGCC WNS wells Geochem request 12/6/2022 DATE: 01/11/2023 Transmitted: North Slope, Colville River Unit, Alaska Via SFTP ___AOGCC WNS wells Geochem request email 12/6/2022 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: wells e-transmittal well folder Receipt: Date: Alaska/IT-Support Services |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 By Meredith Guhl at 10:28 am, Jan 19, 2023 194-026 T37450 191-147 T37451 196-006 T37452 195-020 & 204-245 T37453 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.19 10:37:44 -09'00' ) ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 May 23, 2005 R 5L'"' 6',",,~ IF- ~,..,,'" 'r Ii\'",,,,,, (Þ'.r....... 0 ,,,,,,,'¡,.,' ßI\~ MAY 2 4 20Q5 Alaska Oil ~'I f... ' 'I (51, ~H\¡S Cr~, ~!'(' j "'ilI"IìT'W,' . '\HI "'" ""lWwï~!ø~ìSaorì An~h~r~~~ Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for Alpine 1 B (APD #195-020 1305-054) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent P&A operations on the well Alpine 1 B. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, JIl. M~ M. Mooney Wells Group Team leader CPA I Drilling and Wells SC.ANNED MAY 272005 MMlskad O R---· \ r, ""·,.7 , t\t'· \ \ A L \t\..)u,\Y ) RE E~VED STATE OF ALASKA 5 ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 2 4: zoo. WELL COMPLETION OR RECOMPLETION REPORTAMg~l.d;lGn$,CommissiQ Oil 0 Gas U Plugged 0 Abandoned 0 Suspended 0 WAG 0 1 b. Well Class: P~ru::h~r~Q,~ 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 No. of Completions _ Other Service 0 Stratigraphic TesO 12. Permit to Drill Number: ) 1 a. Well Status: GINJ 0 WINJ 0 WDSPL 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1465' FSL, 2250' FWL, Sec. 1, T11 N, R4E, UM At Top Productive Horizon: 2002' FNL, 1617' FEL, Sec. 12, T11 N, R4E, UM Total Depth: 2207' FNL, 1522' FEL, Sec. 12, T11 N, R4E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 375455 y- TPI: x- 376813 y- Total Depth: x- 376904 y- 18. Directional Survey: Yes 0 No~ 5972482 5968986 5968778 Zone-4 Zone-4 Zone- 4 5. Date Comp., Susp., or Aband.: 4/30/2005 (Abandoned) 6. Date Spudded: February 18, 1995 7. Date TO Reached: 195-020 1 305-054 13. API Number: 50-103-20211-02 14. Well Name and Number: Alpine 1 B 15. Field/Pool(s): Colville River Field Alpine Oil Pool February 26, 1995 8. KB Elevation (ft): 38' RKB 9. Plug Back Depth (MD + TVD): surface 10. Total Depth (MD + TVD): 8850' MD 17531' rvD 16. Property Designation: ADL 380075 11. Depth where SSSV set: none 19. Water Depth, if Offshore: N/A 17. Land Use Permit: nla 20. Thickness of Permafrost: feet MSL nla 21. Logs Run: none 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20" 94# B 38' 110' 38' 110' 26" 350 sx AS I 13-3/8" 68# L-80 38' 1765' 38' 1765' 16" 350 sx AS III, 650 sx ASI 7" 29# L-80 38' 8839' 38' 7522' 8.5" 235 sx Class G 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 8406'-8493' MD 7150'-7225' TVD SCANNE~) MAY (~ L~( 2005 24. TUBING RECORD DEPTH SET (MD) 8200' PACKER SET 8163' SIZE 3.5" 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED nla 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested Production for OIL-BBL Test Period --> Calculated OIL-BBL 24-Hour Rate -> Flow Tubing press. psi 27. Casing Pressure Plugged & Abandoned WA TER-BBL CHOKE SIZE GAS-OIL RATIO GAS-MCF GAS-MCF WATER-BBL OIL GRAVITY - API (corr) not available CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RBDMS BFl MAY 2 5 2005 NONEO R ¡ GIN A L ..i.~D.ó~ ...~·'AJ .,' .,~c.~." ~,"'. f./ ~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE 28. ') 29. ) GEOLOGIC MARKERS FORMATION TESTS NAME MD rvD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Alpine 1 B 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 :~~nnt:::ame ,) _1 Mi~ejA0onev µ~ 1~ Title: Phone Wells Group Team Leader 2b3~4·574 Date :5/2 3/0~ 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 ) Alpine 1 B Well Events Summary ) Date Summary 03/12/05 CLEAN ICE PAD AFTER BLOW - PULL WELLHOUSE - PULL VR PLUG - BUILD SCAFFOLD 03/12/05 PAD STILL BEING PREPPED E/LlNE ON LOCATION PREPPED FOR JOB. 03/12/05 DRIVE SLlCKLlNE LINE UNIT FROM KRU TO ALPINE. PREP TOOLS FOR JOB. WELL IS NOT READY FOR RIG UP, IN PROGRESS 03/13/05 PULLED VR PLUG FROM TUBING ENTRY PORT - DISCONNECTED J BOX WIRES - LATCHED AND PULLED WELLHEAD PACKOFF ASSB. - BACK THREADED & TIED DOWNHOLE WIRE TO SURFACE SPOOL - PULLED ELINE AND INDUCTOR COUPLING TO SURFACE - READY FOR SLlCKLlNE 03/13/05 RIG SLlCKLlNE TOOL STING ON E-LlNE. JAR OUT HANGER ASSEMBLY. E- LINE UNIT STILL POOH WI E- LINE CABLE, IN PROGRESS. 03/14/05 EQUALIZED & PULLED 2.75" XN PLUG W/ GAUGE @ 8124' RKB. TAG FILL @ 8427' RKB, EST 64' OF FILL. PULLED 1.5" DV @ 8108' RKB. SET 2.81" CAT STANDING VALVE @ 8124' RKB. LOAD TBG & 7" CSG W/285 BBLS OF 9.7 BRINE. 03/14/05 DEMO OLD LINE REMOVED FROM WELL. 03/15/05 PULLED 2.81" CAT STANDING VALVE @ 8124' RKB. WELL IS READY FOR CTU. 03/20/05 ICE PAD COSTS INTIAL PLUS THE ADDITION. 03/21/05 TESTED BOP'S TRAVEL FROM KRU TO ALPINE. SPOTTED UNIT UNABLE TO RAISE MAST BECAUSE OF DIRECTION AND VELOCITY OF THE WIND. 03/22/05 COMPLETED CEMENT SQUEEZE AND PLUG. PUMPED 21 BBLS OF 15.8# CLASS G CEMENT WI ADDITIVES. LAYED IN FROM 8417' RKB UP TO 7000' RKB. SQUEEZED DOWN ONE BBL AND OBTAINED SQUEEZE PRESSURE. PLACED 3 BBLS OF CEMENT IN IA. EST. GOOD CEMENT TOP @ 7435' RKB. LEFT BOTH TBG AND IA FULL OF 9.6# BRINE. 03/23/05 PRE-TBG PUNCH: DRIFT TUBING W/2.3" TO 2000' WLM (NO OBSTRUCTIONS). PT'D CEMENT TO 1500 PSI. READY FOR ElL. [Tag] 03/23/05 SHOT 9 TUBING PUNCHER HOLES (SMALL CHARGES) FROM 1014' TO 1016'. CIRCULATED WARM DIESEL AROUND @ 2 BPM. TBG AND IA FREEZE PROTECTED WITH DIESEL TO 1014' RKB. [Pert] 03/24/05 OBTAINED STATE WITNESSED COMBO MIT ON CEMENT PLUG BOTH TBG & IA TO 1525 PSI. HELD FOR 30 MIN WITH NO LOSSES. PERFORMED NO FLOW TEST (PASSED). UNABLE TO GET PAST CEMENT STRINGER IN TUBING @ 4705' WLM, OBTAINED SAMPLE OF CONTAMINATED CEMENT. DRIFT TUBING 2.809" G-RING TO 1300' WLM. 03/25/05 SET 3-1/2" BAKER N2 BRIDGE PLUG WITH MID ELEMENT AT 1025' -- TOP AT 1024.5'. 03/28/05 PUMPED SURFACE CEMENT PLUG USING 42 BBLS OF 15.8# AS1 CEMENT. FLUSHED DIESEL OUT OF TBG AND IA BY CIRCULATING 50 BBLS OF 9.7# BRINE INTO WELLBORE. CIRCULATED CEMENT DOWN TBG AND UP IA UNTIL GOOD CEMENT RETURNS WERE SEEN. WITNESSED BY STATE INSPECTOR. 04/02/05 BEGIN EXCAVATION OF WELLHEAD AND GUARD PILINGS FOR REMOVAL AND COMPLETION OF P&A'S 04/03/05 COMPLETED EXCAVATION OF WELLHEAD - READY FOR WELDERS TO CUT-OFF BELOW TUNDRA 04/05/05 DRILLED AND CUT WINDOWS IN CONDUCTOR - DRILL PILOT HOLE IN OUTER CASING- PRESSURE AND HIGH LEL LEVELS - DRILLED, TAPPED AND INSTALLED 1/4" BALL VALVE WHILE DECISIONING THE NEXT MOVE 04/06/05 PUMPED 1.5 BBLS DIESEL TO 1000 PSI THREE TIMES - 50 PSI LOSS IN 30 MINUTES - BLED BACK TO ZERO - OA CONTINUED TO BUILD SLIGHT PRESS. AFTER BLEEDING ) Alpine 1 B Well Events Summary ) 04/07/05 HEAT UP TREE - BLEED DOWN THROUGH 1/4" VALVE ON 133/8" - PREP AND ADD INTEGRAL FLANGE AND VALVE TO OPPOSITE SIDE OF TREE - PREP FOR BRINE SWEEP- TAGGED CEMENT @ 62' 04/08/05 Bleed OA for well secure, assist roustabouts in prep for P&A. RIG UP TANKS AND DISPLACE CASING WITH 9.7# CACL BRINE - WELL CONTINUED TO BUILD PRESS AFTER BRINE- NEEDS CEMENT [ANN COM ISSUES, WH Maintenance] 04/09/05 PUMPED 17.1 BBLS IN 133/8" WITH CEMENT TO THE SURFACE - PERFORMED HESITATION SQUEEZES TO 500 PSI TO ATTEMPT TO SEAL ANNULUS - LEFT 50 PSI ON WELL [Cement-Poly Squeeze] 04/10/05 CHECKED PRESSURE ON 133/8" ANNULUS VALVE - DRILLED THROUGH 1/4" VALVE ON CASING TO CLEAR CEMENT - 40 PSI GAS AND DIESEL PRESSURE ON SURFACE - HEAT UP TREE AND BLEED OFF TO WATCH PRESSURE BUILD UP 04/11/05 INITIAL PRESSURE ON OA-28 PSI - BLED AND GAINED PRESSURE - PIT TO 1500 PSI W/2 BBLS - LOST 150 PSI IN 15 MIN - BUMPED BACK TO 1500 PSI - LOST 175 PSI IN AN HOUR- BLED TO ZERO TO MONITOR OVERNIGHT 04/12/05 INITIAL PRESSURE ON OA = 24 PSI. BLED OA DOWN FROM 24 PSI TO 0 PSI, BLED BACK 15 GALLONS OF DIESEL. ATTEMPT TO CHECK CEMENT TOP IN OA UNABLE TO GET PLUM BOB PAST 3.5'. SII OA AND MONITOR PRESSURE CAME BACK UP TO 7 PSI IN APP: 45 MINS. LEFT SHUT IN TO MONITOR 04/13/05 INITIAL PRESSURE ON OA = 11 PSI. BLED OA DOWN FROM 11 PSI TO 0 PSI. BLED OUT 19- 3/4 GALLONS OF DIESEL. SHUT IN AND MONITOR. 04/14/05 INITIAL PRESSURE ON OA = 4 PSI. BLED OA DOWN FROM 4 PSI TO 0 PSI. BLEED 1-114+ GALLON OF DIESEL. SHUT IN TO MONITOR. 04/15/05 INITIAL PRESSURE ON OA = 1 PSI. BLED OA DOWN FROM 1 PSI TO 0 PSI. BLEED 2/3 GALLON OF DIESEL. MADE AN ATTEMPT TO GET PLUMB BOB DOWN INSIDE OF OA BUT ONLY ABLE TO GET TO 2' THIS TIME. SHUT IN TO MONITOR. 04/16/05 INITIAL PRESSURE ON OA = 0+ PSI. BLED OA DOWN FROM 0+ PSI TO 0 PSI. BLEED 1/2 PINT OF DIESEL. SHUT IN TO MONITOR. 04/17/05 INITIAL PRESSURE ON OA = 0 PSI. OPEN VALVE AND HEARD A WHISPER. BLEED 1/2 CUP OF DIESEL. SHUT IN TO MONITOR. 04/18/05 INITIAL PRESSURE ON OA = 0 PSI. BLEED 1/2 CUP OF DIESEL. SHUT IN TO MONITOR. 04/19/05 INITIAL PRESSURE ON OA = 0 PSI. BLEED 1/3 CUP OF DIESEL. SHUT IN TO MONITOR. 04/20/05 INITIAL PRESSURE ON OA = 0 PSI. BLEED 1/3 CUP OF DIESEL, A LITTLE LESS THAN YESTERDAY. SHUT IN TO MONITOR. 04/21/05 LUBRICATED IN 2-1/2 BBLS OF 9.8# NACL BRINE @ 150 PSI. BLED BACK 1/2 BBL OF DIESEL & 1/4 BBL OF 9.8# NACL BRINE. WRAPPED AND HEATED TREE. JOB IN PROGRESS. 04/22/05 INITIAL OA PRESSURE = 10 PSI. BEFORE PUMPING BLED BACK 15 GALLONS OF DIESEL & 2-1/2 GALLONS OF BRINE. BEGAN LUBRICATING PROCESS, PUMPED IN APP: 2 BBLS OF 9.8# NACL BRINE AND BLED BACK 14 GALLONS OF DIESEL AND 12-1/2 GALLONS OF BRINE. WORKED PUMP PRESSURES UP TO AS HIGH AS 1000 PSI DURING THE PUMP IN PORTION. LEFT OA WITH 0 PSI. 04/23/05 INITIAL OA PRESSURE 7 PSI. PUMPED IN APP: 68 GALLONS OF 9.8# NACL BRINE. BLED BACK APP: 57 GALLONS OF 9.8# NACL BRINE AND ABOUT 6 GALLONS OF DIESEL AND DIESEL Y FOAM (TOOK FOAM SAMPLES). PRESSURED UP OA TO 1000 PSI EACH PUMP IN AND LOST 100 PSI IN 30 MINUTES. LEFT 700 PSI ON OA AND SHUT IN FOR OVERNIGHT MONITORING. LAST BLEEDS ONLY SHOWED TRACE OF DIESEL OR DIESEL Y FOAM. ') Alpine 1 B Well Events Summary ) 04/24/05 INITIAL OA PRESSURE 500 PSI HAD DROPPED 200 PSI OVER NIGHT. PUMPED IN OA WITH 83 GALLONS OF 9.8# NACL BRINE. BLED BACK 64 GALLONS OF BRINE & 3+ GALLONS OF DIESEL. FLUSHED THRU OA LOW POINT UP THRU BOTH OA WELLHEAD AND HALLIBURTON VALVES TO THE TANK(1 BBL EACH). PRESSURED UP OA TO 1000 PSI AND WILL SIT OVER NIGHT. 04/25/05 FOUND INITIAL OA PRESSURE @ 700 PSI. HAD LOST 300 PSI IN 12 HRS. FLUSHED 9.8# NACL BRINE THROUGH LOW POINT AND OUT THE HIGH POINT 5 TIMES (APP: 15 GALLONS EACH TIME) ALLOWING IT TO SET @ ATMOSPHERIC PRESSURE AND FLOAT DIESEL TO SURFACE. DRAINED OUT BRINE AND DIESEL TRACE AFTER EACH SET. VERY MINIMAL DIESEL RECOVERED (TRACE). NO FLOW OBSERVED THROUGH OUT THIS PROCESS. LEFT OA FULL OF 9.8# NACL BRINE TO HIGH POINT BLEED @ 0 PSI AND SII FOR THE NIGHT TO MONITOR. 04/26/05 LUBRICATE AND BLEED NACL BRINE TO FLOAT DIESEL AND EMULSIONS FROM 133/8" OA 04/27/05 DRAINED BRINE IN WELLHEAD (15 GALLONS) DRILLED AND TAPPED OA AND INSTALLED 3/4" BALL VALVE FOR CEMENT JOB CEMENT SQUEEZE OA W/ .75 BBLS OF 15.6 TO 16# ARCTIC SET# 1 TO 1000 PSI- LEFT 1000 PSI SQUEEZE PRESSURE ON WELL 04/28/05 DRILLED CEMENT THROUGH BOTH TAPPED VALVES ON OA - ZERO PRESSURE SEEN- OPENED ANNULUS VALVES ON TREE - ZERO PRESSURE - BLED 10 GALLONS LlQUID- CEMENT CONTAMINATED AND SOFT - ADD HEAT TO TREE AND CONTINUE TO BLEED LIQUIDS TO PREP FOR WELL CUT-OFF 04/30/05 CUT OFF WELLHEAD - DRESSED AND PREPARED FOR INSPECTORS - ADDED CEMENT AS .. REQUIRED TO TOP OFF STRINGS - READY FOR INSPECTION AND CAPPING 05/01/05 INSPECT WELL WITH AOGCC INSPECTOR - WELD CAP ON CONDUCTOR - BEGIN ... BACKFILL OF EXCAVATION PHilLIPS Alasn.!t, Inc. A SubSidiary of PHILLIPS PETROLEUM COMPANY r~ _1 !ALPINE1B I API: 501032021102 SSSV Type: Nipple Annular Fluid: CONOUCTOR (0-110, 00:20.000, Wt:94.00) NIP (1232-1233, 00:3.500) SURF CASING (0-1765, 00:13.375, Wt:68.00) NIP (8069-8070, 00:3.500) Gas Lift landrel/Oummy Valve 1 (8108-8109, 00:6.018) NIP (8124-8125, 00:3.500) PKR (8163-8164, 00:6.059) Perf (8406-8493) PROD CASING (0-8839, 00:7.000, Wt:29.00) FISH (8731-8748, 00:5.500) !I 11- a =c Reference Log: Last Tag: 8442 Last Tag Date:. .3/30/01 'I: Casing String,:, ALL Description CONDUCTOR SURF CASING PROD CASING : Tubing String· TUBING : Size I Top 1.3.500 . .0 ! Perforations Summary Interval TVD I 8406- 8493 . 7147 - 7222 : Gas Lift Mandrelslvalves f St MD TVD Man Man I Mfr Type 1. 8108 6894 CAMCO MMM CAMCO ! Other (plu~s, equip., etc.) - JEWELRY , 'Depth TVD Type 1232 1232 NIP 8069 6861 NIP 8124 6907 NIP 8163 6940 PKR 8184 6958 WLEG : Fish· FISH Depth 8731 FISH Description ~INE ) ALPINE 18 Well Type: TH Orig Completion: 3/12/95 Last W/O: 4/2/01 Angle ~ TS: deg ~ Angle ~ TO: 31 deg ~ 8850 Rev Reason: Set permanent gauges by ImO Last Update: 5/2/01 Ref Log Date: TO: 8850 ftKB Max Hole Angle: 43 deg ~ 6022 Size 20.000 13.375 7.000 Top o o o Bottom TVD Wt Grade Thread 110 110 94.00 1765 1765 68.00 L-80 BTC 8839 8839 29.00 L-80 BTC TVD Wt Grade Thread 6971 9.30 L-80 EUE 8RD MOD Ft SPF Date Type Comment 87 6 3/19/96 (PERF 21/8" EJ; 3/19/96 is approximate perf date Bottom 8200 Zone Status VMfr V Type V aD Latch Port TRO DMY o Date Run 3/11/96 Vlv Cmnt TG 1.5 0.000 Description ID 2.813 2.813 2.750 4.000 2.992 Otis 'X' Landing Nipple Otis 'X' Landing Nipple Otis 'XN' Landing Nipple - set permanent Panex gauge assembly 4/2/01 Baker 'FAB-1' Packer, w/10' GBH-22 Locator Seal Assy Wireline Re-entry Guide Comment 16.15' Fish: Emerg Release Sub, Spacer, Gun Hanger, TDF Firing- 3/11/01 Milled out cement w/2 15/16" bi-center bit from 8248' - 8389'; PERFs open 3/31/01 Tubing & IA loaded with 10.0 ppg brine with 2000' diesel cap 4/2/01 Set permanent Panex gauge assembly with electric line communication to surface. \ J ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, '\7 e,j11 1)\¡1(VS P. I. Supervisor ti II DATE: May 1 2005 FROM: Chuck Scheve, Petroleum Inspector SUBJECT: Surface Abandonment Alpine 1 B PTD#195-020 Sunday. May 1.2005: I traveled to Conoco Phillips Alpine 1 B exploratory location to inspect the casing cut off and abandonment of this well. All casing strings were cut off at approximately 5' below original ground level and all were found to be full of cement. A 3/4" thick marker plate was welded to the conductor casing with the required information bead welded to it. SUMMARY: I inspected the casing cut off depth, and the P&A marker plate on the Alpine 1 B well and found all to be in order. Attachments: Alpine 1 B marker plate.JPG Alpine 1 B cut off.JPG ~(1'.h~·.~\i~'nMßV ~ -,1 ?o·rJ·~ C J."''''M '! ~ "(1...,...,.1 . J-, J .:J J. L.. \ tJ ) ) Alpine 1 B (ConocoPhillips) Suñace Abandonment Inspection Photos from Chuck Scheve, AOGCC May 1 2005 Casing cut Marker Plate installed ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg . '~qál 4 (Z1(D5" P. I. Supervisor ( DATE: March 28, 2005 FROM: John Crisp, Petroleum Inspector SUBJECT: Surface Cement Job Alpine 1 B Conoco/Phillips Alaska PTO 195-020 March 28. 2005: I traveled to Alpine well 1 B 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 @ 1025' MD. Tubing is perforated from 1016' MD to 1014'MO. I witnessed 15.8 ppg arctic set cement pumped down the tubing to a depth of 1016' MD. 37 bbl'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 975 psi @ 4bpm. Summary: I witnessed 15.8 arctic set cement pumped down the tubing & up the annulus on Alpine 1 B. The swab valve on the tree & the IA valve were closed after cement was observed @ surface. Attachments: None Non-Confidential SCþ.....¡..iE..'¡·\ !Vi ,'\'1 C) -;: r;Ofl!:'; ~ , \¡ E'~ ~ ",.~ ~ ~ r'" r ")~ _t'4 L ,U ,,) Surface Cement Job Alpine IB 03-28-05 IC.doc ") lc;.s -D -;V >~--tY~ Subject: Re: Alpine1B 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 monitor it.. Thanks, Guy Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy ./. schwartz@conocophillips.com SGANNEI) APR 1 8 2.005 1 of 1 4/18/2005 1 :28 PM ) ) ,~ç-Od-··D Subject: Alpine 1B and Bergschrund 2A P & A From: "Schwartz, Guy L" <Guy.L.Schwartz@conocophillips.com> Date: Thu, 14 Apr 2005 16:21 :58 -0500 To: tom_maunder@admin.state.ak.us CC: "Mooney, M" <M.Mooney@conocophillips.com> ~--., ..-.-..", " , " . ,....... . . .==""". I . ,. , - 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 1 B: 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 AS1 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 more 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 office: 907-265-6958 Cell: 240-5696 ATO-1512 guy .1. schwartz@conocophillips.com 1 of 1 4/18/2005 1 :28 PM ,) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: ~~. ~~~~rvisor ~~ '7/¡ lo~ DATE: March 24, 2005 FROM: John Crisp, Petroleum Inspector SUBJECT: Cement Plug Tag Alpine 1 B Conoco/Phillips Alaska PTD195-020 March 24, 2005: I traveled to Alpine well 1 B to witness the Cement Plug tag & pressure test for permanent abandonment. I arrived on Location & the wire line unit was rigging up to RIH w/ a 2.25" 00 slick line bailer to verify cement inside 3.5" tubing. Cement was witnessed tagged @ 4705' MD. Bailer was broken down after POOH & Bailer was full of soft cement. I witnessed a successful pressure test on the tubing & IA that verified no /' communication to OA or Formation. Test was performed to 1525 psi. for 30 minutes. Summary: I witnessed a cement plug tag & tubing & casing pressure test for permanent abandonment of well Alpine 1 B. Attachments: None Non-Confidential SCANNED APR 2 5 2005 Cement Plug Tag Alpine IB 03-24-05 jc.doc - . - 0 - ~ ..- ~.'-- -. -- - - - -' - - 'r ...----0- / ) ') \qS-()ðO r \~ .cy:>~ ~ Subject: Re: Alpine IB and Bergschrund 2A P & A (pilings) From: Thomas Maunder <tom_maunder@admin.state.akus> Date: Mon, 14 Mar 2005 16:30:17 -0900 To: "Schwartz, Guy L" <Guy.L.Schwartz@conocophillips.com> 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" OD 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 ÇUY .1.schwartz@cqnocoph¡llips.com 1 of 1 4/18/2005 1 :27 PM ~:~.. , V fil~¡r ¡fi~ \ t I ¡ t ; \ ¡ I' \ (i I! I' I, ; . Lf Ii . I....:', ¡ I' ) I~. ,.i~ \ P.'f' !Æ:,~~' f,'l t"'{j-.!~ \ (:cO ¡ ¡..i,i,: ~/fi': I II'!,I' "'1\., rl"~~ï\'\ r'i ',I r ! i' r r ': ,I ,ll . r' ", ,~' ¡', r i' \ /i: \ I"v1Ì: I I., l_....,,' 1", rl)') :J¡ ,,'., ': 1\, '~\' " ',t...--ii' t, 'ð¡ \\~ .~ ) Ifû----ð¡)ò AItASIiA OILAlWD GAS CONSERVATION COMMISSION I /,/ ,II, , .I / ¡ J FRANK H. MURKOWSKI, 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: Alpine 1 B Sundry Number: 305-054 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 . day or weekend. A person may not appeal a Commission decision to Superior 0 unless rehearing has been requested. Ene!. SCANNED MAH 0 2 20D5 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 Subject: Application for Sundry Approval for Alpine #1 B (APD # 195-020) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval to plug and abandon the well Alpine #1 B. If you have any questions regarding this matter, please contact me at 263-4574 or Guy Schwartz at 265-6958. Sincerely, M. Mooney Wells Group Team leader CPAI Drilling and Wells MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] D D 20 AAC 25.280 Suspend D Operation Shutdown D Repair well D Plug Perforations D Pull Tubing D Perforate New Pool D 4. Current Well Class: Development D Stratigraphic D Exploratory [] Service D Perforate D Stimulate D Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): 38' RKB D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Waiver Annular Disp. D Other D 195-020 6. API Number: 50-103-20211-02 9. Well Name and Number: Alpine 1 B 10. Field/Pool(s): Colville River Field / Alpine Oil Pool PRESENT WEll CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8731' Size MD TVD Burst Collapse 20" 110' 110' 13-318" 1765' 1765' 7" 8839' 7522' 8. Property Designation: ADL 380075 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 8850' 7531' 8442' Length Casing Conductor Surface 80' 1735' Production 8809' Perforation Depth MD (ft): 8406'-8493' Packers and SSSV Type: 3.5" x 7" Baker FAB-1 Packer @ no SSSV 12. Attachments: Description Summary of Proposal [] Detailed Operations Program D BOP Sketch D 14. Estimated Date for Perforation Depth TVD (ft): 7150'-7225' Tubing Size: 3.5" Packers and SSSV MD (ft) 8163' 13. Well Class after proposed work: Exploratory [] Development D 15. Well Status after proposed work: Oil D Gas D WAG D GINJ D 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 Mike Moonev March 11, 2005 Date: Contact: Title: Signature Phone Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrìty'biJ.", BOP Test D ""~""''' Mechanical Integrity Test D Other: ~-- cor",' 1\' I SS I 0 ~~ E R BY ORDER OF THE COMrv11SSl0N .~----.-...._-=.......-.-------_...._=..~".., -- Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE Tubing Grade: 9.3# Tubing MD (ft): 8200' Service D Plugged D WINJ D Abandoned [] WDSPL 0 Mike Mooney @ 263-4574 Wells Group Team Leader Date Sundry Number: \',) \ Date . - --_._---='"~=------=-- y I Submit in Duplicate Alpine 1 B Plug and Abandon 10=403 summary Well History: Alpine 1 B was an exploration sidetrack to test the southern extent and width of the Alpine sand. The well was converted to an observation well for "full-time" reservoir surveillance prior to field start-up. Pressure gauges were hung off in the XN nipple and downhole pressure data is monitored real-time in Setcim. The value gained from the downhole data is now less useful due to the completion of nearby development injection wells. For these reasons, it is recommended to plug and abandon Alpine 1 B. An ice road spur will be built to facilitate the work which will be coordinated with other remedial well work in late February. Note that the OA has been cemented. TOe is at 84'. t--. . tS>~ oSr,~~~\¿.c~ \<é~~~. P&Asummarý¡ ~\..'" ~ 'N:) G..-v~n~ 1. Notify BLM/AOGCC 48hrs in advance of all pressure testing and suspension operations. 2. Pull permanent gauge completion. 3. Pressure test lA, OA and perform injectivity test on the formation with 9.4ppg brine. 4. Pull lower GLM dummy, tag TD and circulate 9.4 brine down tubing and up IA. (to remove all diesel). "1'"'-""''''- 5. RU CTU and pump 24 bbls cement for lower plug. Hesitate squeeze in cement to cover perfs then open 3 }2" 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 E-line and Tag cer:nent plug after 24 hr~ . Pressure test to 1500 psi for 30min. (put on chart). LOt'\&C\-~~~c.\a,'- 7. Set plug at 1000' in 3 }2' tubing with E-line. Perf through tubing at 995'. OA is cemented and to should be at about 84'. ' ,.,.,,,,,,....,,,..._..., 8. Establish circulation from tubing to IA. 9. Circulate cement down tubing taking returns up IA. When cement is to surface SIIA . Top ,,_,.~off OA with cement. Ðxcavate wellhead and cut all casing strings 3' below original ground level. Add cement as need to bringc<;,mentin all strings to surface. Weld on cover plate, ~d ~ackfill, I .1 - CO~-\-o.L:s, ~~<'C-\ð'\I?\"\e,\\o v...:;~\Û'.'~ ~lCl\'C Alpine 1 B Plug and Abandon 10-403 summary ,/'" / Well History: / Alpine 1 B was an exploration sidetrack to test the southern extent and width ø the Alpine sand. The well was converted to an observation well for "full-time" reservoir surv~lance prior to field start-up. Pressure gauges were hung off in the XN nipple and downhol9",þressure data is monitored real-time in Setcim. The value gained from the downhole"la is now less useful due to the completion of nearby development injection wells. For these easons, it is recommended to plug and abandon Alpine 1 B. An ice road spur will be built to cilitate the work which will be coordinated with other remedial well work in late February. / /' / P & A summary rl 1. Notify BLM/AOGCC 48hrs in advance of all ~essure testing and suspension operations. 2. Pull permanent gauge completion. 3. Pressure test lA, OA and perform inj~vity test on the formation with 9.4ppg brine. 4. Pull lower GLM dummy, tag TO al)((circulate 9.4 brine down tubing and up IA. 5. RU CTU and pump 24 bbls c~nt for lower plug. Hesitate squeeze in cement to cover perfs then open 3 %" x 7" an'.)Olus and displace 8 bbls of cement up the IA. I (this leaves about 300' of cem~t in the IA and tbg above the GLM) 6. Rig up E-line and Tag c~ent plug after 24 hrs . Pressure test to 1500 psi for 30min. (put on chart). / i 7. Set plug at 1000' ini %' tubing with E-line. Perf through tubing and 7" casing at 995' (need holes throu~ both). / 8. Establish circu~1ion from tubing to both annuluses. j 9. Circulate ce¥ent down tubing taking returns up IA. Shut IA , open OA and take cement returns to ~rface. Shut OA. i 1 o. Excavat~lwellhead and cut all casing strings 3' below original ground level. Add cement as nee~/to bring cement in all strings to surface. Weld on cover plate and backfill. l / PHilliPS Alaska, Inc. A of PHILLIPS PETROLEUM COMPANY ! ALPINE 1 B CONDUCTOR ---< (0-110, 00:20.000, Wt:94.00) NIP (1232-1233, 00:3.500) SURF CASING (0-1765, 00:13.375, Wt:68.00) NIP (8069-8070, 00:3.500) Gas Lift i land rei/Dummy : Valve 1 (8108-8109, 00:6.018) NIP (8124-8125, 00:3.500) PKR (8163-8164, 00:6.059) Perf (84(16.8.\93) F'ROD C,~3Ir J() (':I.è~33'd C.e, ~ (":":' \1\': ~'3 I~'I}, FI'~r: (87: 1.:~ ~~ ~ Cù : :":'':', )]INE ALPINE 1 B -- -_~-.-_n--__- Set permanent ---------g§l!9_~~J:~Y ImO ___LastJ¿p_d-,'!!~:!5£?/()J.. ._._----~ Thread St cemë-ríì w/2 15ifs" bi-center bit -from 8248' ~ â389:-PERFso-p-en~--- ~ 3i31/0 S. IA loaded_>":~~~.1Q_OnPpg--b~~I!~_~.I.t!1--29QO--(_'e~~1 cap. n. ~. -- .412iO.I_._.~.~¡ pemlan"nl P3n"x gauge ass"mbly Wllh el"ClrlC ¡ne.~()_~n')':In!.C?¡~()Ð .!Q..S~rfElce . i i I I ~'.'<I¡ i 'ii I j""',',,,,', """,,',,,,6,;,' , . I ft- , ¡I! II I. ,j ¡IT} =1 1- j E --i ' =-t r= " r- i F ~ r- ~ 1- ¡,.~J t, j . ~ t.. ,~ ~ ' ". 1 U , , RE: Alpine Well Abandonments Su bject: RE: Alpine Well Abandonments From: "Schwartz, Guy L" <Guy.L.Schwartz@conocophillips.com> Date: Man, 28 Feb 2005 14:05:23 -0600 To: Thomas Maunder <tom - maunder@admin.state.ak.us> Tom, AS per your request Alpine 1B 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 .l.schwart .com -----Original Message----- From: Thomas Maunder Sent: Monday¡ February 28, 2005 10:39 AM To: SchwartzI Guy L Subject: Re: Alpine Well Abandonments .state.ak. Guy, Have you been able to resolve the questions on these wells?? Tom 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 IB P & A summary.doc Content-Type: applicationlmsword Content-Encoding: base64 Bergschrund 2A P & A summary.doc C t t D . to Bergsehrund 2A P & A on en - escnp IOn: d summary. oc application/nlsword Content- Type: 1 of2 2;:;)812005 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 Alpine #lB (195-020 / 399-035) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the well conversion on the well Alpine #lB. If there are any questions, please contact me at 265-'1478. Sincerely, M. Erwin Alpine Operations Engineer Alpine Engineering ME/skad Oil & Gas Cons. C°mmissior~ AnChora.¢e - 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. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 1465' FSL, 2250' FWL, Sec. 1, T11 N, R4E, UN At top of productive interval: 2002' FNL, 1617' FEL, Sec. 12, T11N, R4E, UN At effective depth: At total depth: 2207' FNL, 1522' FEL Sec. 12, T11 N, R4E, UN Stimulate__ Alter casing _ Plugging _ Perforate _ Repair well_ OtherV__Well Conversion Type of Well: Development _~ Exploratory __~ Stratagrapic _~ Service X. 6. Datum of elavation (DF or KB feet): RKB 38' 7. Unit or Properly: Coiville River Unit 8. Well number: Alpine #1B 9. Permit number/approval number: 95-20 / 399-035 10. APl number: 50-103-20211-02 11. Field/Pool: Colville River Field / Alpine Oil Pool 12. Present well condition summary Total Depth: measured 8850 feet true vertical 7531 feet Effective Deptt measured 8248 feet true vertical 7014 feet Casing Length Size Conductor 80' 20" Surface 1735' 13-3/8" Production 8809' 7" Liner Plugs (measured) Junk (measured) Cemented 350 sx AS 1 350 sx AS III & 650 sx AS I 235 sx Class G Measured depth 110' 1765' 8839' True verticaldepth 110' 1765' 7522' Perforation Depth measured true vertical 8406'-8493',6 sp! 7150'-7225', 6 sp! Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 EUE Mod @ 7177' ME Packers and SSSV (type and measured depth) 3-1/2" x 7" Baker FAB-1 Packer @ 7165' ME: ,,E O ZOO/ ,a:,bska Oil & Gas Cons. Commissior~ Anchomcte ._ , 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 OiI-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 _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Michael Erwin " ~,~'~'"" , Form 10-404 Rev 06/15]88 Questions? Call Michael Erwin 265-1478 SUBMIT IN DUPLICAs Prepared by Sharon AIIsup-Drake Date Comment ALPINE #1 B Event History 03/03/01 03/08/01 03/10/01 03/11/01 03/30/01 03/31/01 04/01/01 04/02/01 PULLED BPV AND VR PLUGS FROM ANNULUS. PULL 2.813 XXN PLUG FROM 8137' WLM. DRIFTED THROUGH TBG W/2.70" & TAGGED BOTTOM AT 8238' WLM DRILLED CEMENT FROM 8248' TO 8310 W/AVG POP @ 10 FPH. USED 650 BBLS OF SLICK DIESEL & 50 BBLS OF DIESEL GEL. WELLBORE FREEZE PROTECTED W/DIESEL. JOB IN PROGRESS. DRILLED OUT CEMENT FROM 8310' TO 8389' W/AVG POP = 13 FPH. CLEANED THROUGH PERFS (PERF INTERVAL 8406'-8493') DOWN TO 8495' RKB & HIT HARD BTM. WELL CAME ON WITH RETURNS BETTER THAN 1 FOR 1. PUMPED 100 BBLS OF DIESEL DOWN TBG AFTER COMPLETION OF CLEANOUT. SIWHTP = 653 PSI & BlIP = 3180 PSI. WELL FREEZE PROTECTED W/DIESEL DOWN TO THE PERF'S. AT 200 FPH WITH TEMP & PRESS. TAGGED AT 8442 FT ELM (51' FILL, 36' PERFS OPEN). SBHP= 3180 PSI. GAUGE TBG TO XN NIP AT 8124' MD WITH 2.810" GAUGE RING. SET XN LOCK/PERMANENT PANEX GAUGE IN XN NIP. PULLED DGLV AT 8108' MD. LOADED TBG & IA WITH 10.0 PPG BRINE WITH 2000' DIESEL CAPS. LEFT POCKET OPEN. SET 1-1/2" DGLV W/RK LATCH @ 8094' WLM. PT IA TO 2000 PSI. PT TBG TO 2000 PSI. PULL CATCHER OFF XXN PLUG. DUMP 9 QUARTS OF FLUORINERT ON XXN PLUG. SUCCESSFULLY SET THE INDUCTIVE COUPLING INTO THE RECEIVER IN THE XN NIPPLE - SET UP COMMUNICATIONS THROUGH THE FMC HANGER AT SURFACE - SYSTEMS ALL WORKING. BHP AT GAUGE=3102 PSI. BHT AT GAUGE= 154 F. Page 1 of 1 8129101 'oo!jjo s!q'l lu jlOs~(m .~o uempok111ooS aoql!o ol polooa!p oq Kern uo!leo!j!aelO gu!paegoa so.u!nbuI 8g0-66g g£-96 Vi5 pumqosg.~o~t g£0-66£ 015-g6 [t[ ou!dlV Ie^mddv/L~puns 'oN l!m-~od 'p|o!d .~o^!~I Oll!^IOD Otll u!. om^.~os uo!le^.~osqo ol SllO~ o~1 jo uotsao^uoa :~oj '6661 '15I qo.mlAI polep sIe^oadde ~(:~puns gu!~olloj oql po^!ooo:~ ouI 'e>iseiv ODkIV '000i5 'g I ~(.mmqo~I jo olep luomoouom:moo pos!^o.~ e ql!~ '00015-666 jo uoseos peo.~ oo! oql I!lun pouodlsod uooq seq >po~ s!ql 'slu!e.IlSUOO snot.re^ ol on( '666 [ 'g I qoaelAI se loofmd oql jo dn-l.mls pol~odm poAmdde se soppuns oq& 'siio~ uo!le^.~osqo ol PlO!d ~o^!~t oII!^IOD otI1 ut. sIIo~ o~1 jo uo[s~o^uoo ::posodmd sl! jo uo!loldmoo u! poXeiop oq ii!~x 'ouI 'e>lse[v OD~IV leql pos!Ape ~q oseoid :uosuolsptlD 'qA[ :moo ut. sea odolS ql.~ON 'l!UFl :to^!~i Oll!^lOD SlIOA~ uo!le^~osqo ou!dlV aoj uo!leo!iddv :loo.fqnS 10966 e>ISelV 'o:gmoqauv aA!aG ou!dnmod [00g uo!ss!mmoD UO[leAilOSUOD Sero puc I!O e>Iselv uosuols!aqD 1.~oqo~I aouo!ss!mmoD 6661 ' [ 15 I!adv 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 1'. Type of request: Abandon _ Suspend __ Operation Shutdown __ Reenter suspended well _X_ Alter casing __ Repair well _ Plugging _ Time extension __ Stimulate _ Change approved program Pull tublng Variance Perforate Other 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development_ RKB 38 feet ~i Address: Exploratory__ 7. Unit or Property: P.O. Box 100360, Anchorage, Ak, 99510-0360 Stratagraplc _ Colville River Unit SeNJce X 4. Location ofwell at surface: 8. Well number: Alpine #lB 1465' FSL & 2250' FWL, Sec 1, T11N, R4E, UM At top of productive interval: 9. Permit number: 95-20 2002' FNL & 1617' FEL of Sec 12, T11 N, R4E, UM At effective depth: 10. APl number: 50-103-20211-02 At total depth: 11. Field/Pool: Colville River Field _ 2207' FNL & 1522' FEL of Sec 12, T11N, R4E, UM Alpine Oil Pool' 12. Present well condition summary Total Depth: measured 8850 feet Plugs (measured) true vertical 7531 feet Effective Depth: measured 8248 feet Junk (measured) true vertical 7014 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80 feet 20" 94# Gr B 350 sx ASI 110 feet 110 feet Surface 1735 feet 13-3/8" 68# L-80 350 sx ASIII 1765 feet 1765 feet 650 sx ASI Production 8809 feet 7" 29.0# L-80 235 sx Class G 8839 feet 7522 feet ORiGiNAL Perforation Depth measured 8406- 8493' 6 spt : true vertical 7150-7225' 6 spt Tubing (size, grade, and measured depth) 3-1/2", 9.3 ppf, L-80 EUE-Mod @ 7,177' MD Packers and SSSV (type and measured depth) 3-1/2"x 7" Baker FAB-1 Packer @ 7,165' MD 13. Attachments Description summary 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 FOR COMMISSION USE ONLY Conditions of approval: Notify Comission so representitive may witness IAPpr°va' Plug integrety _ BOP test ? Location clearance _ O\iG~IL) ¥" ..~ O~,,~ Mechanical integrety test _ Subsequent form required 10- /,~'O ("~,L\¥;v" '~(" ~,~¢\~,,~. Approved by order of the Commissioner Robert N. ChrJ.~t~_n~r~r~ ...---Commissioner Date ~ ~J~, '" Form10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Conversion Procedure Colville River Field Alpine #lB 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 8248'MD to 8399'MD with CTU. 3. Wash out the sand plugs, exposing the perfs from 8406'MD to 8493'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 8124'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 Alpine No. 1 B APl #50-103-2021 1-00 1465 FSL 2250 FWL S/1 T/11N R4E 20" Conductor @ 110' RKB 13-3/8" cemented to surface Cement 7 x 13-3/8" 350 sx Arctic Set 1 405 sx Arctic Set 3 TOC +/- 7900' 3-1/8" FMC Gert IV-A tubing hanger with 3-1/2" Fox pin down x 3" ISA BPV (BPV and VR plugs set) diesel to 1000' in tbg & annulus Otis 'X' LN @ 1,232' MD (2.813" ID) 13-3/8" 68 ppf L-80 BTC Surface Casing @ 1765' RKB KB=38' Pool 6 Spud 1/28/95 3-1/2" 9.3 ppf L-80 EUE 8rd MOD tbg Note' J-55 tbg installed; 1 joint between X LN & GLM and 4' P J below GLM Otis 'X' LN @ 8,069' MD (2.813" ID) Camco 1-1/2" MMM GLM w/TG latch 1 jt below 'X' LN @ 8108' MD DV set 3/11/96 Otis 'XN' LN @ 8,124' MD (2.750" ID) EOT @ 8200' MD Cement Plug 8248- 8399' M D ~.~;~.:.~;~ Sand Plug 8399-8616' WLM "" _ '," ~.~ ~,: .;,,: .;,,: ,:.,: ,:,~,,:.(,,:,~ ,;.~ ,:.~ ,:: .:, .: .:,: ................ _',' @ 8839' MD TD 8,850 MD Baker FAB-1 w/10' GBH-22 Iocator seal assembly (4.00" lB) @ 8163' RKB, 8179' WLM Tail pipe includes; 1.80-40 seal bore extension 2. 5" LTC x 4-1/2" EUE XO @ 8177' MD 3. 4-1/2" L-80 EUE 8rd Mod PJ @ 8178' MD 4. 4-1/2" WLEG @ 8184' MD Perf 8406'-8493' ELM 6 spf 2-1/8" EJ PBTD 8,747 MD TOF 8731 MD, 8721' WLM 3-3/8" OD 0.5' Emerg Release Sub 3-3/8" OD 5.45' Spacer , 5-1/2" OD 8.15' Gun Flanger 2-1/2" OB 1.68' TDF Firing Head 2-1/2" OD 0.37 Bull Plug Total 16.15' Long Updated I,; ~, 4/°,°-,,o. 20" Conductor @ 110' RKB 13-3/8" cemented to surface Cement 7 x 13-3/8" 350 sx Arctic Set 1 405 sx Arctic Set 3 XN ?X Housing & p,-, 2550 SRO ? res ;'~ St gauges TOC +/- 7900' EOT @ 820O' MD Fill @ 8616 WLM 3/15/96 7" 29 Ib/ft L-80 BTC @ 8839' MD TD 8,850 MD Colville River Field Alpine No. 1 B APl #50-103-20211-00 1465 FSL 2250 FWL S/1 T/11N R4E I I I 3-1/8" FMC Gen IV-A tubing hanger with 3-1/2" Fox pin down x 3" ISA BPV (BPV and VR plugs set) KB=38' Pool 6 diesel to 1000' in Spud 1/28/95 Otis 'X' LN @ 1,232' MD (2.813" ID) 13-3/8" 68 ppf L-80 BTC Surface Casing @ 1765' RKB 3-1/2" 9.3 ppf L-80 EUE 8rd MOD tbg I I , , 7/32" Electric Line from gauges to surface I I ' lO.6 ppg brine Note' J-55 tbg installed; 1 joint between X LN & GLM and 4' PJ below GLM Otis 'X' LN @ 8,069' MD (2.813" ID) Camco 1-1/2" MMM GLM w/TG latch 1 jt below 'X' LN @ 8108' MD DV set 3/11/96 Otis 'XN' LN @ 8,124' MD (2.750" ID) Baker FAB-1 w/10' GBH-22 Iocator seal assembly (4.00" ID) @ 8163' RKB, 8179' WLM Tail pipe includes; 1.80-40 seal bore extension 2. 5" LTC x 4-1/2" EUE XO @ 8177' MD 3.4-1/2" L-80 EUE 8rd Mod PJ @ 8178' MD 4.4-1/2" WLEG @ 8184' MD Perf 8406'-8493' ELM 6 spf 2-1/8" EJ PBTD 8,747 MD TOF 8731 MD, 8721' WLM 3-3/8" OD 0.5' Emerg Release Sub 3-3/8" OD 5.45' Spacer , 5-1/2" OD 8.15' Gun Hanger 2-1/2"OD 1.68' TDF Firing Head 2-1/2" OD 0.37 Bull Plug Total 16.15' Long Updated 2/18/99 PERMIT 95-020 95-020 DATA 6742 GEOTOPS AOGCC Individual Well Geological Materials Inventory T DATA PLUS ~'"1700-9940 MPT/GRC/CNP/RHOB/ROP 1 R 0 1 95-020 LIS R 0 95-020 95-020 95-020 95-020 95-020 95-020 95-020 Page: 1 Date: 03/12/98 95-020 95-020 RUN RECVD 95-020 95-020 95-020 DGR / EWR4 / MD DGR / EWR4 / TVD FORMATION LOG FORMATION LOG ~/1785-8850 ~L/'1785_7455 ~" i 2 0 - 8 8 5 0 L.,L/'~ 12 0 - 8 8 5 0 i.i., FLUID SAMPLER L 8200-8600 PRDSS BLDUP DATA L 8094-8094 PRESS BLDUP SVY ~L/80 - 8600 SRFCE WLL TEST R HALIBURTON 2/26/96-3/10/96 DSK RES FLD STUDY R 09/09/96 08/~4/95 04/20/95 04/20/95 04/20/95 9-14 07/09/95 9-14 07/09/95 1 04/20/95 1 04/20/95 1 04/20/95 1 06/12/95 1 07/23/96 1 07/23/96 1 07/23/96 07/23/96 09/16/96 10-407 R COMPLETION DATE / / / DAILY WELL OPS R / / / TO / / / Are dry ditch samples required? yes no And received? Was the well cored? yes no Analysis & description received? Are well tests required? yes no Received? yes no Well is in compliance Initial COMMENTS / / / / / / yes no yes no DIV OF OIL P, ND G~S F~X NO, 907~62~852 P, 02 TONY KNOWLF_$, GOVF~RNOR DEPARTMENT OF NATURAL RESO~CES DIVISION OF OIL AND GAS 3601 G STREET, SUITE 13B0 ANCHORAGE, ALASKA PHONE: (907) 762-2549 December 17, 1997 D. W. Johnston, Chairman, AOGCC Alaska Oil and Gas Conservation Comm{ssion 3001 Porcupine Drive Anchorage, AK 99501-3192 Subject: Release of ARCO Alpine No. 1 and lA wells Dear Commissioner Johnston: On February 7, 1997, I granted extended confidentiality for the Alpine No. 1, No. lA and No. lB wells until 30 days after unleased acreage significant to the well was offered for lease in State Sale 86. Sale 86 was held on November 17, 1997. Therefore, the wells no longer qualify for extended confidentiality and the well data for Alpine No. 1 and No. 1A should be released on December 18, 1997. Well data for Alpine No. lB should be released 25 months from its completion date, which was March 23, 1996. By copy of this letter I am notifying ARCO Alaska Inc. of the upcoming release of this well data. Kenneth A. Boyd DireCtor Cc: Jim Ruud, Land Manager, ARCO Alaska Inc. RECEIVED DEC :'' 'c i'a i ..... "" · d tr I) ! ¥ tot' [,) ! L ill,Il) l'R;~ NO, ~U fbUT:3Ub;" ?,02/U2 DNY KNOW].E$, GOVERNOR DEPARTMENT OF NATURAL RESO~~ D/V/S/ON OF OIL AND GAS February 7, 1997 360] "¢" STREET, SUITF. 1550 NNCHORAGE, AlalSKA 99505-$948 pHONE: (907) 26~-$784 Land Manager ~o,C ~ ~° ARCO Alaska Inc. P.O. Box 100360 ~ ~~' ~10-0360 . ,..-~.~.....~~ /Subject.' Request for extended confidentiality "~ k~~CO Alpine No I, IA, and lB De~ Mr. Sutter: In your January 22, 1997 letter you requested extended confidentiality for the ARCO Alpine No. 1, lA, and lB wells under the authority of llAAC 83.153. Under this statute: "IX the commissioner finds that reports of information required under A.S. 31.05.035(a) contain significant infom~ation relating to the valuation of unleased land within a three mile radius dj: the well from whicl-t these reports or information are obtained, the commissioner will upon written request of the owner of [he well, keep r. he reports or information eonfidenfi~ for a reasonable time not to exceed 90 days after the disposal of the unleased land, unless the owner of the well gives permission to release the reports and information at an earlier date. The commissioner will, in his or her discretion, extend confidentiality to reports or information under AS 31.05.035 from a well located more than three miles from any unlea.qed land if the owner of the well Rom which these reports or information are derived makes a sufficient showing that ~e reports or information contain significant information relating to the valuation of unleased land beyond the three-mile radius." The Alpine No. I, IA, and lB wells lie greater than three miles but less than five from unleased land which is cta-rently included as part of the State Lease Sale 86. Following your request for exmnded confidentialitT, a review of the data was made by Division of Oil and Gas technical staff. This review was aided by a technical meeting held ojHanuary 31, 1997 with members of ARCO's land and geos¢ience staff. Based upon the recommendation of division technical smS-f and under the departmental delegation of authority, I agree to extend the confidentiality of the ARCO Alpine No. 1, lA, and lB wells until 30 days after State Sale 86, which is currently scheduled for September 30, 1997. No further extension of confidentiality for this well data will be granted. RECEIVED FEB 10 1997 Alaska Oil & Gas Cons. ComimSsion Anchorage .Y.~.' ,~..-..,. -,- ...:. ...~.: ..: ~: · ,., ... D I V OF 01L fiND FhX NO, 9075623852 P, 03/03 ,-,~',~,io letter I am re~uestina'that the Alaska Oil and Oas Conservation By copy ,, ..... ~ ~ ' d lB Commission extend thc ¢onfidentiahty of data from the'Alpine No. 1, iA, an wells until further notice. Since. rely, Kenneth A. Boy/ Director cc: D.W. Johnston, Commissioner, AOGCC RECEIVED FEB 10 199"/ Alaska 0il& Gas Cons. Co~]mi_ssi0r~ Anchoragt~ q ~ {"'1 2 0 9 5 '~' 0 2 0 ['-] ARCO Exploration Company I-'l ARCO Oil and Gas Company O ARCO Alaska, Inc.,~, Record Of Shipment Of Confidential Information To: IDistrict: Alaska AOGCC Attn.- Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 From: ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Attn.: Kelli Thibodeau (907)265-6240 (X) Enclosed ( )Under separate cover ( )Via Alpine 1 B ) Reservior Fluid Study as Displayed by Core Laboratories (File Code: JRB#2 Well) Note - Please veri,fy aod acknowledge receipt, by signing and retur.nincj a copy of this transmittal. Signed by ' ' ///~.~"/-~ _/~/~ ,J,/~//~(',~/.~x./,-~ [ Date Received/b/Y~~ I Date09/13/96 Remarks: Please Note that all included information is CONF/DENT~E:c F_IV E I) SEP 1 6 1996 Alaska Oil & Gas Cons. commission Anchorage ARCO Alaska, Inc. Post Office B... ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~ %-"- Date' September 9, 1996 Subject: Alpine lB Reservoir Fluid Study From/Location: T.J. Scarbrough 1304 ATO, Anchorage To: Distribution Enclosed is the Core Laboratories' fluid study RFL960094 performed on a bottom hole sample from well Alpine #lB, code named JRB #2 If there are any questions, please call. Sr. Engineer RECEIVED SEP 1 6 1996 Alaska 0il & Gas Cons. CommJssio~ Anchorage AR3B-6003-93 242-2603 CORE LABORATORIES Reservoir Fluid Study for Arco Exploration & Production Technology JRB#2 Well North Slope, Alaska RFL 960094 19-Jun-96 A product of Core Laboratories, Inc. RECEIVED SEP 1 G 1996 Alaska Oil & Gas Cons. Commission Anchorage. The analyses, opinions or interpretations contained in Ibis reporl are based upon obsentations and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best judgement of Core Laboratories. Core Laboratories assumes no responsibility and makes no warranty or representations, express or implied, as to the productivity, proper operations or profitableness, however, of any oil, gas, coal or other mineral, property, well or sand in oonnestion with which such report is used or relied upon for any reason whatsoever. PETROLEUM SERVICES June 19, 1996 Arco Exploration and Production Technology 2300 West Piano Parkway Rm PRC -E 1304 Piano, TX 75075 ATTENTION: Mr. Russ Bone Subject: Reservoir Fluid Study Well: JRB #2 Location: North Slope, Alaska File: RFL 960094 Dear Mr. Bone, Three samples of subsurface fluid were shipped to our laboratory in Carrollton, Texas for use in a reservoir fluid study. The results of this study are presented on the following pages. It has been a pleasure to perform this reservoir fluid study for Arco Exploration and Production Technology. Should any questions arise or if we may be of further service in any way, please do not hesitate to contact us. Sincerely, Supervising Engineer Reservoir Fluid Analysis KWK 16 cc: Addressee 15 bound & I unbound Core Laboratories, Inc. 1875; Monetary Lane, Carrollton, Texas 75006-7012, (214) 466-2673, Telex 163166, CO RDAL UT, Fax (214) 323-3930 Laboratory Procedures Arco Exploration & Production Technology Reservoir Fluid Study JRB #2 Well North Slope, Alaska RFL 96CX)94 PRELIMINARY QUALITY CHECKS OF SAMPLES RECEIVED On May l, 1995, three samples of subsurface fluid contained in Arco one liter capacity sample cylinders were received in our Carrollton, Texas laboratory. Bubblepoint determinations of each liquid sample were measured at reservoir temperature as a quality check. A summary of samples received in the laboratory may be found on page two. SAMPLE COMPOSITION The composition of reservoir fluid was measured through a heptanes plus residual fraction by low temperature fractional distillation. The heptanes plus fi'action was further analyzed by gas chromatography through hexatriacontanes plus. A chromatographic "fingerprint" of this compositional data is presented in the appendix. The composition and density of the fluid can be found on pages three, four and five. PRESSURE- VOL UME RELATIONSHIP A portion of the reservoir fluid was charged to a high pressure, windowed cell heated to the reported reservoir temperature of 160°F. During the constant composition expansion at this temperature, a bubblepoint was observed at 2276 psig. The results of the pressure-volume relations are presented on pages six and seven. DIFFERENTIAL VAPORIZATION During the differential vaporization at the reservoir temperature, the fluid evolved a total of 910 cubic feet of gas at 14.65 psia and 60°F per barrel of residual oil at 60°F. The resulting relative oil volume factor was 1.524 barrels of saturated fluid per barrel of residual oil at 60°F. The oil density and the properties of the evolved gases were measured at each point during the differential pressure depletion and the data included in the summary of the differential vaporization data on page eight. MUL TI-PRESSURE VISCOSITY The viscosity of the reservoir fluid was measured over a wide range of pressures at 1600F in a rolling ball viscosimeter. The results of the viscosity measurements are presented on page nine. SEPARATOR TESTS Small portions of the reservoir fluid were subjected to a single-stage and a multi-stage separator test to determine gas/oil milo, stock tank oil gravity and formation volume factor. These data can be found on page 10. The gases generated during the multi- stage separator test were collected and compositionally analyzed. These compositions are presented on pages 11 through 13. The composition of the stock tank oil can be found on page 14. The separator test data were used to adjust the differential vaporization data to surface conditions and are summarized on pages 16 and 17. Three gas depleted oils at specified pressures and reservoir temperature were prepared and subjected to flash separation at the conditions of the above multi-stage separator test. These data can be found on page 15. GRAPHICAL REPRESENTA TION8 This report includes graphical representations and analytical expressions. The statistical summaries represent an objective estimate of non-systematic error using a preset level of confidence. Confidence intervals are calculated using the Student "t" density distribution tables. An appendix is also included which contains equations and nomenclature which extend and define the analytical expressions and data relationships presented in the report. TABLE OF CONTENTS Laboratory Procedures Summary of PFT Data Preliminary Quality Checks Reservoir Fluid Composition Pressure-Volume Relations Differential Vaporization Viscosity of Reservoir Fluid Separator Flash Analysis Separator Test Gas Compositions Stock Tank Oil Composition Gas Depleted Oils Separator Flash Analysis Differential Vaporization adjusted to Separator Conditions ......... : .......... 3-5 6,7 8 10 11-13 14 15 16,17 Equations and Nomenclature Chromatographic "Fingerprint" ................... .Appendix-A ................... ~Appendix-B LIST OF FIGURES Pressure- Volume Relations RelativeVolume .................... `4-1 Y-Function .................... .4 -2 Differential Vaporization Relative Oil Volume .................... B-1 Solution Gas~Oil Ratio .................... B-2 Oil Density .................... B-3 Incremental Gas Gravity .................... B-4 Deviation Factor, Z .................... B-5 Viscosity Analysis Viscosity below Saturation Pressure Single-Phase Oil Viscosity C-I C-2 Differential Vaporization Adjusted to Separator Conditions Solution Gas~Oil Ratio Formation Volume Factor .................... D-1 .................... D-2 Arco Exploration & Production Technology JRB#2 Well RFL 960094 SUMMARY OF PVT DATA Reported Reservoir Conditions Average Reservoir Pressure .................. Average Reservoir Temperature ............ 3270 ps~g 160 'F Pressure-Volume Relations Saturation Pressure ............................... Avg Single-Phase Compressibility ......... 2276 12.57 psig E-6 vNIpsi ( 5000 to 2276 psig ) Differential Vaporization Data ( at 2276 psig and 160 °F ) Solution Gas/Oil Ratio ........................... Relative Oil Volume ............................... Density of Reservoir Fluid ..................... 910 1.524 0.6831 scf / bbl of residual oil at 60 °F bbi / bbl of residual oil at 60 °F gm/cc Reservoir Fluid Viscosity 0.454 cp at 2276 psig and 160 °F Se )arator Test Results Separator Conditions Formation Total Solution Tank Oil Gravity Volume Factor Gas/Oil Ratio ( °APl at 60 °F ) psig °F (A) (B) 85 130 1.521 912 37.5 50 135 1.520 909 37.4 Prepared Gas Depleted Oils 85 130 1.453 741 37.5 85 130 1.374 569 37.5 85 130 1.286 375 37.5 (A) Barrels of saturated oil per barrel of stock tank oil at 60 °F. (B) Total standard cubic feet of gas per barrel of stock tank oil at 60 °F. Page I CORE LABORATORIES Arco Exploration & Production Technology JRB#2 Well RFL 960094 PRELIMINARY QUALITY CHECKS and Summary of Samples Received Sampling Conditions Bubblepoint Conditions Approximate Cylinder Number Sampling Sample Water Date psig °F psig °F Volume Recovered (cc) (cc) g3A00404** 93A00394 g3A00906 * * * 2,225 160 500 0 * * * 2,147 160 500 0 * * * 2,125 160 500 0 93A00404'* * * * 2,330 180 500 0 * Data not forwarded to Core Laboratories Inc. ** Sample used for all subsequent analyses. Page 2 CORE LABORATORIES ~..,o Exploration & Production Tec, JRB #2 Well RFL 960094 )logy Composition of Reservoir Fluid ( by Low Temperature Distillation ! Extended Gas Chromatography ) L~ Component Mol % Wt % MW Dens (gm/cc) Hydrogen 0.00 Hydrogen Sulfide 0.00 Carbon Dioxide 0.34 0.16 44.010 0.8172 Nitrogen 0.32 0.10 28.013 0.8086 Methane 36.48 6.29 16.043 0.2997 Ethane 6.27 2.03 30.070 0.3558 Propane 8.80 4.17 44.097 0.5065 i-Butane 1.75 1.09 58.123 0.5623 n-Butane 5.02 3.14 58.123 0.5834 i-Pentane 1.69 1.31 72.15 0.6241 n-Pentane 2.47 1.92 72.15 0.6305 Hexanes 3.42 3.17 86.18 0.6632 Heptanes plus 33.44 76.62 213.22 0.8514 Note: Plus Fraction MW and Density are measured values. Plus fraction MW has been corrected for benzene content. Composition has been adjusted for Hextane minus content identified in distillation residue. Sample Characteristics This is Core Lab sample number 804 Average Molecular Weight ........................ 93.0 Sample Density (at 60 °F) ......................... 0.7019 Page 3 CORE LABORATORIES -co Exploration & Production Te~'~,nology JRB #2 Well RFL 960094 Component Composition of Heptanes Plus Fraction ( From Chromatographic Technique ) (qm/cc) n-Pentanes minus .00 .00 Hexanes .00 .00 Methylcyclopentane .81 .32 .7529 84.2 0.37 Benzene .05 .02 .8836 78.1 0.02 Cyclohexane 2.28 .90 .7826 84.2 0.98 Heptanes 8.79 4.13 .6875 100.2 5.12 Methylcyclohexane 5.06 2.33 .7732 98.2 2.56 Toluene 1.32 .57 .8710 92.1 0.55 Octanes 9.28 4.97 .7063 114.2 5.98 Ethylbenzene .42 .21 .8708 106.2 0.20 Meta & Para Xylenes 1.17 .58 .8664 106.2 0.57 ortho-Xylene .60 .30 .8838 108.2 0.29 Nonanes 7.83 4.59 .7212 128.3 5.42 iso-Pmpylbenzene .41 .23 .8656 1 20.2 0.23 n-Propylbenzene .50 .28 .8656 1 20.2 0.27 1,2,4-Trimethylbenzene .85 .46 .8798 1 20.2 0.47 Decanes 6.61 4.15 .7780 134.0 4.54 Undecanes 6.47 4.46 .7890 147.0 4.81 Dodecanes 5.28 3.97 .8000 161.0 4.22 Tridecanes 5.25 4.31 .8110 175.0 4.52 Tetmdecanes 4.41 3.93 .8220 190.0 4.07 Pentadecanes 4.08 3.94 .8320 206.0 4.04 Hexadecanes 3.22 3.35 .8390 222.0 3.40 Heptadecanes 2.65 2.95 .8470 237.0 2.98 Octadecanes 2.76 3.25 .8520 251.0 3.25 Nonadecanes 2.28 2.77 .8570 263.0 2.75 Eicosanes 1.83 2.36 .8620 275.0 2.33 Heneicosanes 1.83 2.22 .8670 291.0 2.18 Docosanes 1.38 1.98 .8720 305.0 1.93 Tricosanes 1.22 1.82 .8770 318.0 1.77 Tetracosanes 1.12 1.74 .8810 331.0 1.69 Pentacosanes 1.06 1.72 .8850 345.0 1.65 Hexacosanes .89 1.50 .8890 359.0 1.44 Heptacosanes .87 1.52 .8930 374.0 1.45 Octacosanes .81 1.48 .8960 388.0 1.41 Nonacosanes .65 1.24 .8990 402.0 1.18 Triacontanes .66 1.28 .9020 416.0 1.21 Hentriacontanes .67 1.36 .9060 430.0 1.28 Tritriacontanes .41 .87 .91 20 458.0 0.81 Tetratriacontanes .39 .87 .9140 472.0 0.81 Pentatriacontanes .40 .91 .9170 486.0 0.84 Hexatriacontanes plus 3.43 19.22 1.0520 1198.2 15.56 Sample Characteristics This is Core Lab sample number 630 Total Liquid Molecular Weight ................................ 213.3 Total Liquid Density (gm/cc) ................................... 0.8515 Total Liquid APl Gravity .......................................... 34.5 Properties of Heavy Fractions Plus Fractions I Mo, I Wt I Dens.yl °AP, I MW 1% 1% I(qnVcc)l I Heptanesplus 96.86 98.76 0.853 34.3 217.5 Decanes plus 60.83 80.09 0.886 28.0 280.8 Undecanes plus 54.22 75.94 0.893 26.8 298.7 Pentadecanes plus 32.83 59.27 0.921 22.0 385.1 Eicosanes plus 17.87 43.01 0.954 16.7 513.4 Tricosanes plus 13.03 35.45 0.972 14.O 596.8 Triacontanes plus 6.40 25.43 1.013 8.0 848.C~ Pentatriacontanes plus 3.83 20.13 1.045 3.8 1122.0 Page 4 CORE LABORATORIES ,'co Exploration & Production Technology JRB #2 Well RFL 960094 Component Composition of Low Temperature Distillation Residue ( From Chromatographic Technique ) ((jnVcc) n-Pentanes minus .00 .00 Hexanes .17 .07 .6632 86.2 0.09 Methylcyclopentane .81 .32 .7529 84.2 0.37 Benzene .05 .02 .8836 78.1 0.02 Cyclohexane 2.28 .90 .7826 84.2 0.98 Heptanes 8.78 4.13 .6875 100.2 5.12 Methylcyclohexane 5.05 2.33 .7732 98.2 2.56 Toluene 1.32 .57 .8710 92.1 0.55 Octanes 9.26 4.94 .7063 114.2 5.97 Ethylbenzene .42 .21 .8708 106.2 0.20 Meta & Para Xylenes 1.16 .58 .8664 106.2 0.57 ortho-Xylene .60 .30 .8838 106.2 0.29 Nonanes 7.62 4.59 .7212 128.3 5.42 is~Propylbenzene .41 .23 .8656 1 20.2 0.23 n-Pmpylbenzene .50 .28 .8656 120.2 0.27 1,2,4-Trimethylbenzene .85 .46 .8798 120.2 0.47 Decanes 6.60 4.15 .7780 134.0 4.54 Undecanes 6.46 4.46 .7890 147.0 4.81 Dodecanes 5.25 3.97 .8000 161.0 4.22 Tddecanes 5.25 4.31 .8110 175.0 4.52 Tetmdecanes 4.41 3.93 .8220 190.0 4.07 Pentadecanes 4.07 3.94 .8320 206.0 4.04 Hexadecanes 3.21 3.35 .8390 222.0 3.40 Heptadecanes 2.65 2.95 .8470 237.0 2.96 Octadecanes 2.76 3.25 .8520 251.0 3.24 Nonadecanes 2.24 2.77 .8570 263.0 2.75 Eicosanes 1.82 2.35 .8620 275.0 2.32 Heneicosanes 1.62 2.22 .8670 291.0 2.18 Docosanes 1.38 1.98 .8720 305.0 1.93 Tdcosanes 1.21 1.81 .8770 318.0 1.75 Tetracosanes 1.12 1.74 .8810 331.0 1.69 Pentacosanes 1.06 1.72 .8850 345.0 1.65 Hexacosanes .89 1.50 .8890 359.0 1.44 Heptacosanes .87 1.52 .8930 374.0 1.45 Octacosanes .81 1.48 .8960 388.0 1.40 Nonacosanes .66 1.24 .8990 402.0 1.17 Triacontanes .65 1.28 .9020 416.0 1.21 Hentriacontanes .67 1.36 .9060 430.0 1.28 Dotriacontanes .44 .92 .9090 444.0 0.86 Tritriacontanes .40 .87 .91 20 458.0 0.81 Tetratriacontanes .39 .87 .9140 472.0 0.81 Pentatriacontanes .40 .91 .9170 486.0 0.84 Hexatriacontanes plus 3.42 19.20 1.0520 1196.2 15.54 Sample Characteristics This is Core Lab sample number 606 Total Liquid Molecular Weight ................................ 213.0 Total Liquid Density (gm/cc) ................................... 0.8512 Total Liquid APl Gravity .......................................... 34.6 Properties of Heavy Fractions Plus Fractions Heptanes plus Decanes plus Undecanes plus Pentadecanes plus Eicosanes plus Tricosanes plus Triacontanes plus Pentatriacontanes plus 100.00 100.00 0.851 34.6 213.0 96.69 98.69 0.852 34.3 217.4 60.72 80.05 0.886 28.0 280.7 54.12 75.90 0.893 26.8 298.6 32.75 59.23 0.921 22.0 385.0 17.82 42.97 0.954 16.7 513.4 13.00 36.42 0.972 14.0 596.6 6.38 25.41 1.013 8.0 848.1 3.82 20.11 1.045 3.8 1121.8! Page 5 CORE LABORATORIES Arco Exploration & Production Technology JRB#2 Well RFL 960094 VOLUMETRIC DATA (at 160 °F) Saturation Pressure (Psat) ............................. Density at Psat ............................................... 2276 psig 0.6831 gm/cc AVERAGE SINGLE-PHASE COMPRESSIBILITIES Pressure Range psig Single-Phase Compressibility v/v/psi 5000 to 4500 4500 to 4000 4000 to 3500 3500 to 3000 3000 to 2500 2500 to 2276 11.04 E-6 11.73 E-6 12.49 E -6 13.37 E -6 14.40 E -6 15.24 E -6 Page 6 CORE LABORATORIES Arco Exploration & Production Technology JRB#2 Well RFL 960094 PRESSURE-VOLUME RELATIONS (at 160 °F) Pressure psig Relative Volume (A) Y-Function (B) Density gm/cc 5000 0.9658 4500 0.9711 4000 0.9768 3500 0.9829 3000 0.9895 2800 0.9923 2700 0.9937 2600 0.9951 2500 0.9966 2400 0.9981 2300 0.9996 b]2276 1.0000 2270 1.0009 2264 1.0019 2258 1.0028 2251 1.0039 2246 1.0047 2223 1.0085 2163 1.0189 2048 1.0413 1873 1.0829 1674 1.1452 1477 1.2293 1300 1.3330 1140 1.4612 1004 1.6087 908 1.7436 664 2.2860 534 2.7950 385 3.8177 2.680 2.574 2.455 2.336 2.230 2.133 2.052 1.994 1.847 1.769 1.679 0.7073 0.7034 0.6993 0.6949 0.6903 0.6884 0.6874 0.6864 0.6854 0.6844 0.6833 0.6831 (A) Relative Volume: V/Vsat or volume at indicated pressure per volume at saturation pressure. (B) Where: Y-Function (Psat - P) (Pabs) * (V/Vsat- 1) Page 7 CORE LABORATORIES Arco Exploration & Production Technology JRB#2 Well RFL 960094 RELATIVE VOLUME ( at 160 °F ) 0.9950 0.9900 0,9850 0.9800 0.9750 0..9700 0.9650 2000 2500 3000 3500 Pressure, psig 4500 50O0 Relative Volume Expression: y= a + b (Xd)^i + c (Xd)'"j where: a= 1.05132e+ 00 b= -3.94548e- 01 c= 3.43225e- 01 i= 0.955 .j= 0,,995 Note: Xd (dimensionless 'X') = Pi / Psat, psig Confidence level: Confidence interval: 'r squared': 99 % +/- 0.00006 .999966 LEGEND Laboratory Data Confidence Limits Analytical Expression Saturation Pressure: 2276 psig Current Reservoir Pressure: 3270 psig Pressure-Volume Relations Figure A-1 CORE LABORATORIES 3,50 Arco Exploration & Production Technology JRB#2 Well RFL 960094 Y-FUNCTION ( at 160 °F ) 2.50 ........................................ 1 ~ t .............. ~:-' -' --- ........ ~ ................. ~ ............ 1 ,~50 I 0 50l 1 ,,00 1000 1500 2000 2500 Pressure, psig Y-function Expression: y= a + b (Xd)^i where: a= 1.44762e+ 00 b= 1.36919e+ 00 i= 1,000 Note: Xd (dimensionless 'X') = Pi / Psat, psig Confidence level: Confidence interval: 'r squared': 99 % +/- 0.0091 .999581 LEGEND o Laboratory Data ............... Confidence Limits Analytical Expression Saturation Pressure: 2276 psig Current Reservoir Pressure: 3270 psig Pressure-Volume Relations Figure A-2 CORE LABORATORIES Arco Exploration & Production Technology JRB#2 Well RFL 960094 DIFFERENTIAL VAPORIZATION (at 16o °F) Pressure psig Solution Gas/Oil Ratio Rsd (A) Relative Oil Volume Bod (B) Relative Total Volume Btd (C) Oil Density gm/cc Deviation Factor Z Gas Formation Volume Factor (D) Incremental Gas Gravity (Air=1.000) b)~2276 910 1.524 1.524 0.6831 2000 811 1.480 1.604 0.6926 0.815 0.00707 1800 743 1.450 1.687 0.6993 0.825 0.00794 1600 677 1.421 1.797 0.7061 0.835 0.00904 1400 613 1.393 1.947 0.7128 0.847 0.01045 1200 552 1.367 2.156 0.7195 0.859 0.01235 1000 492 1.341 2.459 0.7263 0.872 0.01501 800 434 1.315 2.931 0.7332 0.887 0.01902 600 375 1.289 3.741 0.7405 0.904 0.02570 400 313 1.260 5.407 0.7484 0.924 0.03894 200 238 1.222 10.477 0.7584 0.950 0.07732 100 186 1.194 20.203 0.7655 0.968 0,14739 0 0 1.052 0.7962 @60°F =1.000 0.742 0.740 0.736 0.732 0.730 0.732 0.744 0.775 0.845 1.010 1.193 1.874 Gravity of Residual Oil = 37.3 °APl at 60 °F Density of Residual Oil = 0.8377 gm/cc at 60 °F (A) Cubic Feet of gas at 14.65 psia and 60 °F per Barrel of residual oil at 60 °F. (B) Barrel of oil at indicated pressure and temperature per Barrel of residual oil at 60 'F. (C) Barrels of oil plus liberated gas at indicated pressure and temperature per Barrel of residual oil at 60 °F. (D) Cubic Feet of gas at indicated pressure and temperature per Cubic Feet at 14.65 psia and 60 °F. Page 8 CORE LABORATORIES 1 Arco Exploration & Production Technology JRB#2 Well RFL 960094 RELATIVE OIL VOLUME ( at 160 °F ) 1.50 1.30 1 ..20 1.10 1.00 / '2000 2500 3000 3500 ~0 ~0 5~ Pressure, psig 0 500 1000 1500 2000 2500 Pressure, psig Relative Oil Volume Expression: y= a + b (Xi)^i + c (Xi)^j + d (Xi)^k where: a= 1.05179e+ O0 b= 4.35213e-02 c= 3.36912e-03 d= 3.86128e-08 Note: Xi (incremental 'X') = pressure, psig Confidence level: Confidence interval: 'r squared': i: 0.212 j: 0.444 k= 1.957 99 % +/-0.00034 .999991 LEGEND o Laborato .ry Data .............. Confidence Limits Analytical Expression Saturation Pressure: 2276 psig Differential Vaporization Figure B-1 CORE LABORATORIES o lOOO 800 6O0 400 200 Arco Exploration & Production Technology JRB~2 Well RFL 960094 SOLUTION GAS/OIL RATIO ( scf/bbl at 160 °F ) o 500 1000 1500 2000 2500 Pressure, psig solution Gas/Oil Ratio Expression: y= a + b (Xi)^i + c (Xi)^j where: a= 2.89380e-.01 b= 3.95543e+ 01 c= 6.81843e-04 i= 0.334 j= 1,,714 Note: Xi (incremental 'X') = pressure, psig Confidence level: Confidence interval: 'r squared': 99 % +/,- 1.42 scf/bbl .99996 LEGEND o Laboratory Data .............. Confidence Limits Analytical Expression Saturation Pressure: 2276 psig Differential Vaporization Figure B-2 CORE LABORATORIES 0.800 Arco Exploration & Production Technology JRB~2 Well RFL 960094 OIL DENSITY ( gm/cc at 160 °F ) 0.780 0.'760 0.740 0.72O 0.700 0.680 0.710 0.700 0.690 0.680 2000 2500 3000 3500 4000 4500 5000 Pressure, psi! 0 500 1000 1500 2000 2500 Pressure, psig Oil Phase Density Expression: y= a + b (Xd)^i + c (Xd)^j where: a= 7.96247e- 01 b= -7.. 13577e- 02 c= --4.18268e- 02 Note: Xd (dimensionless 'X') = Pi / Psat, psig i= 0.275 j= 1.416 Confidence level: Confidence interval: 'r squared': 99 % +/- 0.00029 gm/cc .999889 LEGEND o Laboratory Data ................ Confidence Limits Analytical Expression Saturation Pressure: 2276 psig Differential Vaporization Figure B-3 CORE LABORATORIES Arco Exploration & Production Technology JRB#2 Well RFL 960094 GAS GRAVITY ( at 160 °F ) 1.20 0.80 ................................. 0,,60 -- 0 5OO lOOO Pressure, psig 1500 2000 Gas Gravity Expression: y= a + b (Xd)^i + c (Xd)^j + d (Xd)^k where: a= 1.8738'1e+00 i= 0.912 b= -1.41606e+ 02 j= 0.822 c= -4.41076e+ 03 k= 0.825 d= 4.55123e+ 03 Note: Xd (dimensionless 'X°) = Pi / Psat, psig Confidence level: 99 % Confidence interval: +/- 0.0128 'r squared': ,.998211 LEGEND o Laboratory Data .................. Confidence Limits Analytical Expression Saturation Pressure: 2276 psig Differential Vaporization Figure B-4 CORE LABORATORIES Arco Exploration & Production Technology JRB#2 Well RFL 960094 DEVIATION FACTOR, Z ( at 160 °F ) 1.000 ....................................................................................................... ~ \\ \ \ \ \ 0.950 0,900 0.850 0.800 0 500 1000 1500 Pressure, psig 2000 Deviation Factor Expression: y= a * b (Xd)^i + c (Xd)^j where: a= 1.00002e+00 i= 0.684 b= -3.25348e- 01 j= 0.9'77 c= 1.28424e- 01 Note: Xd (dimensionless 'X°) = Pi / Psat, psig Confidence level: 99 % Confidence interval: +I- 0.0014 'r squared': .999629 LEGEND o Laboratory Data .................Confidence Limits Analytical Expression Saturation Pressure: 2276 psig Differential Vaporization Figure B-E, CORE LABORATORIES Arco Exploration & Production Technology JRB#2 Well RFL 960094 RESERVOIR FLUID VISCOSITY (at 160 °F) Pressure Oil Viscosity cp Gas Viscosity * Oil/Gas Viscosity Ratio 5000 0.542 4500 0.526 4000 0.510 35O0 0.493 3000 0.477 2500 0.461 b~2276 0.454 2000 0.497 1800 0.528 1600 0.561 1400 0.595 1200 0.632 1000 0.673 800 0.720 600 0.777 400 0.852 200 0.972 100 1.08 0 1.70 0.0176 28.2 0.0167 31.6 0.0159 35.2 0.0152 39.2 0.0145 43.5 0.0140 48.2 0.0134 53.6 0.0129 60.3 0.0122 69.8 0.0112 86.6 0.0104 104 * Gas Viscosity data calculated from correlation of Lee A.L., ~lez M.H., and Eakin B.E., "The Viscosity of Natural Gases", Journal of Petroleum Technology, August, 1966, pp. 997-10(X). Page 9 CORE LABORATORIES Arco Exploration & Production Technology JRB#2 Well RFL 960094 RESERVOIR FLUID VISCOSITY ( cp at 160 °F ) 1.20 1 ..00 0.80 0.60 0.0180 o.o1~o ~i-'-~' 0'0100 ~'-- [ Cagulated Gas Visms~y 0 500 1000 1500 2000 Pressure, psig 0 500 1000 1500 2000 2500 Pressure, psig Oil Viscosity Expression: y= a + b (Xd)^i + c (Xd)^j + d (Xd)^k where: a= 1.70279e+ 00 b= -1.40748e+ 00 c= -6.59749e-01 d= 8.18526e-01 i= 0.253 j= 1.389 k= 1.128 Note: Xd (dimensionless 'X') = Pi / Psat, psig Confidence level: Confidence interval: 'r squared': 99 % +/-0.0037 cp .999854 LEGEND Laboratory Data Confidence Limits Analytical Expression Saturation Pressure: 2276 psig Rolling-Ball Viscosity Figure C-1 CORE LABORATORIES Arco Exploration & Production Technology JRB#2 Well RFL 960094 SINGLE-PHASE FLUID VISCOSITY ( cp at 160 °F ) 0.400 2000 2500 3000 3500 4000 Pressure, psig 50oo Single-Phase Viscosity Expression: y= a + b (dX)^i where: a= 4.54084e- 01 b= 3.21468e- 05 Note: dX (delta 'X') = I Psat - Pi I, psig Confidence level: Confidence interval: 'r squared': i= 1.000 99 % +/-. 0.003 cp .996564 LEGEND o Laboratory Data ............ Confidence Limits Analytical Expression Saturation Pressure: 2276 psig Rolling-Ball Viscosity Figure C-2 CORE LABORATORIES Arco Exploration & Production Technology JRB#2 Well RFL 960094 SEPARATOR FLASH ANALYSIS Flash Gas/Oil Gas/Oil Stock Tank Formation Separator Specific Oil Phase Conditions Ratio Ratio Oil Gravity Volume Volume Gravity of Density ( scf/bbl ) ( scf/STbbl ) at 60 'F Factor Factor Flashed Gas ( gm/cc ) psig I °F (A) (B) ( 'APl) Bofb (C) (D) ( Air=1.000 ) 2276 160 0.6831 85 130 727 813 1.117 0.924 * 0.7843 60 170 15 17 1.129 1.205 * 0.7719 0 170 77 82 37.5* 1.521 1.058 1.987 * 0.7908 Rsfb = 912 2276 160 0.6831 50 135 754 843 1.119 0.942 0.7736 0 180 62 66 37.4 1.520 1.063 2.000 0.7872 Rs~ = 909 * Collected and analyzed in the laboratory by gas chromatography. (A) Cubic Feet of gas at 14.65 psia and 60 'F per Barrel of oil at indicated pressure and temperature. (B) Cubic Feet of gas at 14.65 psia and 60 °F per Barrel of Stock Tank Oil at 60 °F. (C) Barrels of saturated oil at 2276 psig and 160 'F per Barrel of Stock Tank Oil at 60 'F, (D) Barrels of oil at indicated pressure and temperature per Barrel of Stock Tank Oil at 60 °F, Page 10 CORE LABORATORIES ~rco Exploration & Production T~ JRB#2 Well RFL 960094 '~nology Composition of Primary Separator Test Gas ( From Chromatographic Technique ) Component Mole % GPM MW Hydrogen Sulf'~ie 0.00 Carbon Dioxide 0.73 44.010 Nitrogen 0.22 28.013 Methane 62.22 16.043 Ethane 13.49 3.588 30.070 Propane 14.14 3.875 44.097 isckButane 2.03 .660 58.123 n-Butane 3.98 1.248 58.123 iso-Pentane 0.91 .331 72.15 n-Pentane 0.87 .313 72.15 Hexanes 0.58 .237 86.18 Methytcyciopentane 0.14 .049 84.16 Benzene 0.02 .006 78.11 Cyclohexane 0.09 .030 84.16 Heptanes 0.26 .119 100.20 Methylcyclohexane 0.10 .040 98.19 Toluene 0.02 .007 92.14 Octanes 0.11 .056 114.23 Ethylbenzene 0.01 .004 106.17 Meta & Para Xylenes Trace .000 ortho-Xylene 0.01 .004 106.17 Nonanes 0.06 .034 128.26 iso-Pmpylbenzene Trace .000 n-Pmpylbenzene Trace .000 1,2,4-Trimethylbenzene Trace .000 Decanes 0.01 .005 134.00 Undecanes plus Trace .000 For Trace detections, component properties am assigned zero. Sampling Conditions 85 psig 130 °F Sample Characteristics This is Core Lab sample number 527 Critical Pressure (psia) ............................. 653.8 Critical Temperature (°R) ..........................460.3 Average Molecular Weight ........................ 26.76 Calculated Gas Gravity (air = 1.000) ......... 0.924 Calculated Average Molecular Weight of C7+ .............................................. 105.9 Calculated Average Density of C7+ .............................................. 0.720 Gas Gravity Factor, Fg ................................................ 1.0404 Super Compressibility Factor, Fpv at sampling conditions ............................. 1.0107 Gas Z-Factor at sampling conditions ............................. 0.g7g at 14.66 psia and 60 °F Heating Value, Btu/scf dry gas Gross ..................................................... 1555 Page 11 CORE LABORATORIES %rco Exploration & Production T' JRB#2 Well RFL 960094 ',nology Composition of Secondary Separator Test Gas ( From Chromatographic Technique ) Component Mole % GPM MW Hydrogen sulr~e o.oo Carbon Dioxide 0.60 44.010 Nitrogen O. 13 28.013 Methane 41.15 16.043 Ethane 15.16 4.032 30.070 Propane 22.98 6.298 44.097 iso-Butane 4.11 1.337 58.123 n-Butane 8.50 2.665 58.123 iso-Pentane 2.15 .782 72.15 n-Pentane 2.10 .756 72.15 Hexanes 1.36 .556 86.18 Methylcyclopentane 0.31 .109 84.16 Benzene 0.04 .011 78.11 Cyclohexane 0.18 .061 84.16 Heptanes 0.58 .257 100.20 Methylcyclohexane 0.23 .092 98.19 Toluene 0.05 .017 92.14 Octanes 0.22 .112 114.23 Ethylbenzene 0.03 .012 106.17 Meta & Para Xylenes 0.01 .004 106.17 ortho-Xylene 0.01 .004 106.17 Nonanes 0.09 .050 128.26 iso-Propylbenzene Trace .000 n-Propylbenzene 0.01 .004 1 20.20 1,2,4-Trimethylbenzene Trace .000 Decanes 0.02 .011 134.00 Undecanes plus Trace .000 , For Trace detections, component properties am assigned zero. Sampling Conditions 60 psig 170 °F Sample Characteristics This is Core Lab sample number 528 Critical Pressure (pr, ia) ............................. 633.6 Critical Temperature (°R) ..........................542.1 Average Molecular Weight ........................ 34.90 Calculated Gas Gravity (air = 1.000) ......... 1.205 Calculated Average Molecular Weight of C7+ .............................................. 105.0 Calculated Average Density of C7+ .............................................. 0.723 Gas Gravity Factor, Fg ................................................. 9110 Super Compressibility Factor, Fpv at sampling conditions ............................. 1.01 24 Gas Z-Factor at sampling conditions ............................. 0.976 at 14.66 psia and 60 °F Heating Value, Btu/scl dry gas Gross ..................................................... 1990 Page 12 CORE LABORATORIES Arco Exploration & Production Te,'hnology JRB#2 Well RFL 960094 Composition of Separator Test Stock Tank Gas ( From Chromatographic Technique ) Component Mole % GPM MW Hydrogen Sulf,:le 0.00 Carbon Dioxide 0.16 44.010 Nitrogen 0.01 28.013 Methane 6.77 16.043 Ethane 7.22 1.920 30.070 Propane 24.37 6.681 44.097 iso-Butane 7.44 2.421 58.123 n-Butane 19.34 6.064 58.123 iso-Pentane 9.29 3.381 72.15 n-Pentane 9.57 3.447 72.15 Hexanes 7.95 3.252 86.18 Methylcyclopentane 1.82 .640 84.16 Benzene 0.22 .061 78.11 Cyclohexane 1.06 .359 84.16 Heptanes 2.94 1.349 100.20 Methylcyclohexane 1.06 .424 98.19 Toluene 0.19 .063 92.14 Octanes 0.52 .265 114.23 Ethylbenzene 0.01 .004 106.17 Meta & Para Xylenes Trace .000 ortho-Xylene Trace .000 Nonanes 0.06 .034 128.28 iso-Propylbenzene Trace .000 n-Pmpylbenzene Trace .000 1,2,4-Tdmethylbenzene Trace .000 Decanes Trace .000 Undecanes Trace .000 Dodecanes plus Trace .000 For Trace detections, component properties are assigned zero. Sampling Conditions 0 psig 170 °F Sample Characteristics This is Core Lab sample number 510 Critical Pressure (psia) ............................. Critical Temperature (°R) .......................... Average Molecular Weight ........................ Calculated Gas Gravity (air = 1.000) ......... Calculated Average Molecular Weight of C7+ .............................................. Calculated Average Density of C7+ .............................................. at 14.66 psia and 60 °F Heating Value, Btu/scf dry gas 559.9 737.1 57.54 1.987 101.3 0.713 3185 Page 13 CORE LABORATORIES ~,rco Exploration & Production Tr JRB #2 Well RFL 960094 ~nology Composition of Separator Test Stock Tank Oil ( From Chromatographic Technique ) Component MolI Wt IDens'Y [ MW I V~ % I % l(gnVcc)! I n-Butane minus 4.06 1.15 .5691 55.2 1.69 iso-Pentane 2.24 .83 .6241 72.2 1.11 n-Pentane 3.16 1.17 .6305 72.2 1.56 Hexanes 5.72 2.53 .6632 86.2 3.19 Methylcyciopentane 2.20 .95 .7529 84.2 1.05 Benzene .27 .11 .8838 78.1 0.10 Cyclohexane 1.67 .72 .7826 84.2 0.77 Heptanes 6.56 3.37 .8875 100.2 4.10 Methylcyclohexane 3.87 1.95 .7732 98.2 2.11 Toluene 1.04 .49 .8710 92.1 0.47 Octanes 7.43 4.34 .7063 114.2 5.14 Ethylbenzene .37 .20 .8708 106.2 0.19 Meta & Para Xylenes 1.01 .55 .8664 106.2 0.53 ortho-Xylene .51 .28 .8838 106.2 0.27 Nonanes 6.32 4.16 .7212 128.3 4.83 iso-Pmpylbenzene .34 .21 .8656 1 20.2 0.20 n-Propylbenzene .42 .26 .8656 120.2 0.25 1,2,4-Trimethylbenzene .55 .34 .8798 120.2 0.33 Decanes 5.88 4.04 .7780 1 34.0 4.34 Undecanes 5.48 4.13 .7890 147,0 4.37 Dodecanes 4.59 3.79 .8000 161.0 3.98 Tridecanes 4.41 3.96 .8110 175.0 4.08 Tetradecanes 3.71 3.61 .8220 190.0 3.67 Pentadecanes 3.43 3.62 .8820 206.0 3.64 Hexadecanes 2.73 3.11 .83g0 222.0 3.10 Heptadecanes 2.39 2.91 .6470 237.0 2.88 Octadecanes 2.28 2.94 .8520 251.0 2.89 Nonadecanes 1.99 2.68 .8570 263.0 2.62 Eicosanes 1.60 2.25 .8620 275.0 2.18 Heneicosanes 1.35 2.01 .8670 291.0 1.94 Docosanes 1.27 1.98 .8720 305.0 1.90 Tricosanes 1.12 1.83 .8770 318.0 1.75 Tetracosanes 1.02 1.73 .8810 331.0 1.64 Pentacosanes .93 1.64 .8850 345.0 1.55 Hexacosanes .81 1.50 .8890 359.0 1.41 Heptacosanes .74 1.42 .8930 374.0 1.33 Octacosanes .88 1.36 .8960 388.0 1.27 Nonacosanes .61 1.25 .8,990 402.0 1.16 Triacontanes .56 1.20 .9020 416.0 1.11 Hentriacontanes .49 1.09 .9060 430.0 1.00 Dotriacontanes .45 1.02 .9090 444.0 0.94 Tritriacontanes .36 .85 .91 20 458.0 0,78 Tetratriacontanes .33 ,80 .91 40 472.0 0.74 Pentatriacontanes .33 .82 .9170 486.0 0.74 Hexatriacontanes plus 2.72 18.85 1.0425 1351.1 15.12 Sample Characteristics This is Core Lab sample number 614 Total Liquid Molecular Weight ................................ 195.0 Total Liquid Density (gm/cc) ................................... 0.8363 Total Liquid APl Gravity .......................................... 37.5 Properties of Heavy Fractions Plus FraCtions I Wt Density *APl MW ' % (gm/cc) I I Hexanes plus Heptanes plus Decanes plus Undecanes plus Pentadecanes plus Eicosanes plus Pentacosanes plus Triacontanes plus Pentatriacontanes plus 90.54 96.85 0.647 35.4 208.6 80.68 92.54 0.855 33.9 223.7 52.26 76.39 0.886 28.1 285.0 46.38 72.35 0.893 26.9 304.2 28.19 56.86 0.920 22.1 393.2 15.37 41.60 0.951 17.1 527.7 9.01 31.80 0.979 12.9 887.8 5.24 24.63 1.008 8.8 915.9 3.05 19.67 1.037 4.9 1257.5 Page 14 CORE LABORATORIES Arco Exploration & Production Technology JRB#2 Well RFL 960094 PREPARED GAS DEPLETED OILS SEPARATOR FLASH ANALYSIS Flash Gas/Oil Gas/Oil Stock Tank Formation Separator Specific Oil Phase Conditions Ratio Ratio Oil Gravity Volume Volume Gravity of Density ( scf/bbl ) ( scf/STbbl ) at 60 °F Factor Factor Flashed Gas ( gm/cc ) psig I °F (A) (B) ( "APl ) Bofb (C) (D) ( Air=l.000 ) 1800 160 0.6993 85 130 547 616 1.127 0.964 0.7871 60 170 20 23 1.136 1.252 0.7754 0 170 97 102 37.5 1.453 1.057 1.992 0.7912 Rs~ = 741 1200 160 0.7195 85 130 368 420 1.141 1.011 0.7857 60 170 24 28 1.147 1.309 0.7748 0 170 114 121 37.5 1.374 1.058 1.993 0.7909 Rs~ = 569 600 160 0.7405 85 130 181 210 1.159 1.062 0.7797 60 170 27 32 1.164 1.377 0.7681 0 170 126 133 37.5 1.286 1.058 2.001 0.7908 Rs~ = 375 (A) Cubic Feet of gas at 14.65 psia and 60 °F per Barrel of oil at indicated pressure and temperature. (B) Cubic Feet of gas at 14.65 psia and 60 °F per Barrel of Stock Tank Oil at 60 °F. (C) Barrels of saturated oil at specified pressure and 160 °F per Barrel of Stock Tank Oil at 60 °F. (D) Barrels of oil at indicated pressure and temperature per Barrel of Stock Tank Oil at 60 °F. Page 15 CORE LABORATORIES A,..,~ Exploration & Production Technology JRB#2 Well RFL 960094 DIFFERENTIAL VAPORIZATION ADJUSTED TO SEPARATOR CONDITIONS* Pressure psig Solution Gas/Oil Ratio Rs (A) Formation Volume Factor Bo (B) Gas Formation Volume Factor (C) Oil Density gm/cc Oil/Gas Viscosity Ratio b)) 5OOO 4500 4000 3500 3000 2800 27OO 2600 2500 240O 2300 2276 2000 1800 1600 1400 1200 1000 800 600 400 200 100 0 912 912 912 912 912 912 912 912 912 912 912 912 813 744 678 615 553 494 435 377 315 241 189 1.469 1.477 1.486 1.495 1.505 1.509 1.511 1.514 1.516 1.518 1.521 1.521 1.477 1.447 1.419 1.391 1.365 1.339 1.313 1.287 1.258 1.220 1.192 1.050 0.00707 0.00794 0.00904 0.01045 0.01235 0.01501 0.01902 0.02570 0.03894 0.07732 0.14739 0.7073 0.7034 0.6993 0.6949 0.6903 0.6884 0.6874 0.6864 0.6854 0.6844 0.6833 0.6831 0.6926 0.6993 0.7061 0.7128 0.7195 0.7263 0.7332 0.7405 0.7484 0.7584 0.7655 0.7962 28.2 31.6 35.2 39.2 43.5 48.2 53.6 60.3 69.8 86.6 104 *Separator Conditions First Stage Second Stage Stock Tank 85 psig at 130 °F 60 psig at 170 °F 0 psig at 170 °F (A) Cubic Feet of gas at 14.65 psia and 60 °F per Barrel of Stock Tank Oil at 60 °F. (B) Barrel of oil at indicated pressure and temperature per Barrel of Stock Tank Oil at 60 °F. (C) Cubic Feet of gas at indicated pressure and temperature per Cubic Feet at 14.65 psia and 60 °F. Page 16 CORE LABORATORIES Pressure psig Arco Exploration & Production Technology JRB#2 Well RFL 960094 DIFFERENTIAL VAPORIZATION ADJUSTED TO SEPARATOR CONDITIONS* Solution Gas/Oil Ratio Rs (A) Formation Volume Factor Bo (B) Gas Formation Volume Factor (C) Oil Density gm/cc 5000 909 1.468 0.7073 4500 909 1.476 0.7034 4000 909 1.485 0.6993 3500 909 1.494 0.6949 3000 909 1.504 0.6903 2800 909 1.508 0.6884 2700 909 1.510 0.6874 2600 909 1.512 0.6864 2500 909 1.515 0.6854 2400 909 1.517 0.6844 2300 909 1.519 0.6833 2276 909 1.520 0.6831 2000 811 1.476 0.00707 0.6926 1800 742 1.446 0.00794 0.6993 1600 677 1.417 0.00904 0.7061 1400 613 1.390 0.01045 0.7128 1200 552 1.363 0.01235 0.7195 1000 492 1.338 0.01501 0.7263 800 434 1.312 0.01902 0.7332 600 375 1.286 0.02570 0.7405 400 313 1.257 0.03894 0.7484 200 239 1.219 0.07732 0.7584 100 187 1.191 0.14739 0.7655 0 1.049 0.7962 Oil/Gas Viscosity Ratio 28.2 31.6 35.2 39.2 43.5 48.2 53.6 60.3 69.8 86.6 104 *Separator Conditions First Stage Stock Tank 50 psig at 135 °F 0 psig at 180 °F (A) Cubic Feet of gas at 14.65 psia and 60 °F per Barrel of Stock Tank Oil at 60 °F. (B) Barrel of oil at indicated pressure and temperature per Barrel of Stock Tank Oil at 60 °F. (C) Cubic Feet of gas at indicated pressure and temperature per Cubic Feet at 14.65 psia and 60 °F. Page 17 CORE LABORATORIES Arco Exploration & Production Technology JRB#2 Well RFL 960O94 lO00 SOLUTION GAS/OIL RATIO ( scf/STbbl ) 8OO 600 400 200 Saturation Pressure 2,276 psig 5OO 1000 1500 2000 2500 Pressure, psig LEGEND Differential Vaporization -~- 85 psig at 130 °F 50 psig at 135 °F DV Adjusted to Separator Figure D-1 CORE LABORATORIES Arco Exploration & Production Technology JRB#2 Well RFL 960094 FORMATION VOLUME FACTOR 1.40 1.30 1.20 1 ,,10 1.00 Saturation Pressure 2,276 psig 1000 20O0 3000 400O 50OO Pressure, psig LEGEND Differential Vaporization -~- 85 psig at 130 °F 50 psig at 135 °F DV Adjusted to Separator Figure D-2 CORE LABORATORIES NOMENCLATURE AND EQUATIONS & WHOLE OIL CHROMATOGRAM APPENDIX RFL 960094 EXTENSIONS TO ANALYTICAL EQUATIONS Appendix A Sin,qle-Phase Relations: Average Compressibility - (al.l) Two-Phase Relations: Constant Mass Expansion Relative Volume - -a rv~ =--: 1-~ vb Ys Differential Relative Total Volume - for 0_< P~ <P~ (al .2) [ R,,. - R,,~ ]/3 ~ ,a,, =C, Differential Gas Formation Volume Factor - for 0 < P~ <P~ (al.3) Formation Volume Factor (adjusted for surface separation) - (al.4) Solution Gas/Oil Ratio (adjusted for surface separation) - for 0 < P~ <P~ (al.5) for 0 < P~ <P~ (al.6) Page A-I EXTENSIONS TO ANALYTICAL EQUATIONS Appendix A DEFINITION OF TERMS Definition of Variables - C~ L P T Z Formation Volume Factor Isothermal Coefficient of Compressibility Conversion Constant for gas to liquid volume (e.g., 5.61459 cf/bbl) Limits of Confidence, :i: Pressure Relative Volume (from constant mass expansion) Gas in Solution Temperature Volume Y-function (from constant mass expansion) Gas Deviation Factor Definition of Subscripts - in absolute units b at bubble point pressure from differential vaporization analysis f from flash separation test (separator test) g gas phase any discreet point o oil phase r reservoir s in solution t total at working conditions at base conditions Page A-2 g~dl ~°~ 8 888§ ALU O~::)u 91,OU .................. -~ ~--(1~ ~ueas:~ema~ul~:~Ou- ......................... ~ Ol. OU ~ o § o § I AUJ 'esuodse~J TONY KNOWLES, GOVERNOR A/~SKA OIL AND GAS CONSERVATION CO~SSION 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 giB 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). · · Chairman ~ cc: Blair Wondzell 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 following data: REPORTS as Displaye by Halliburton- Surface Well Test February-(contains 3.5" floppy with digital data) ~{~"'-0 ~ Alpine lb ~...~ t~'~'~ Bergschrund 2,~ q~-.,~,j~ Neve 1 If you have any questions comments Please call me at (907) 265-6240 or Email me lankat@expLaaLarco, 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 199B AJasl~ Oil & Gas Cons. ~on 2of2 Approved for transmittal by: F. M. HoneYcutt Manager, No~h Alaska Exploration ~.~,' ARCO ALASKA, INC. Alpine No. lB Surface Well Test February 26 - March 10, 1996 RF_CEIVED JUL 2 3 '199~ oil & Gas Cons. Commission Anchorage I'"'1 - HALLIBURTON Halliburton Energy Services 6900 Arctic Blvd, Anchorage, Alaska 99518 (907) 344-2929 (907) 344-6746 Attention: Daniel Wuthrich James Mills Robert Richey Phone Number: Facsimile Number: HALLIBURTON HALLIBURTON ENERGY SERVICES Anchorage,, Alaska CUSTOMER: WELL NUMBER: FIELD: AREA: TEST DATE: TEST NUMBER: ARCO Alaska, INC. Alpine No. 1 B Coleville River Delta Prudhoe Bay, Alaska February 26 - March 10, 1996 Surface Test 1', 2 & 3 HALLIBURTON report' copies have been sent to. the following companies and:/or individuals: # COPIES RECIPIENT 9 ARCO Alaska, INC, Attn: Tim. Scarbrough T#022696-T#030395-T#030896 ARCO ALASKA, INC. Alpine No. lB Surface Well Test February 26 - March 1, 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: FIELD AREA: COUNTY/LSD: STATE/PROVINCE: COUNTRY: 020196 26-Feb-96 Kenai Steve Tyburski Tim Scarbrough Wellhead Land ARCO Alaska, INC. Coleville River Alpine No. lB 8406 to 8493 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: TEST SUMMARY 8, 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 SECTION 3: ASCII FILE DATA Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: DST #1 Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC HES ReD: Steve Tyburski Tubing Vol. bbl/ff: 0.01 Date/Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 26-Feb 7:55 0.000 Arrive Location. Hold Safety Meeting. 26-Feb 8:15 0.333 Build berm, attach SSV to wing valve, run flowline 26-Feb 16:00 8.083 Hold Pre-flow safety meeting 26-Feb 18:00 10.083 Fill Separator with methanol and pressure test vessel to 1000# 26-Feb 20:00 12.083 Test Completed 26-Feb 20:30 12.583 Pressure test flowline to heater inlet valves to 5000# 26-Feb 20:45 12.833 Test completed 26-Feb 21:00 13.083 Pressure test choke manifold to 5000# ....... 26-Feb 21:20 13.417 Test completed 26-Feb 21:30 13.583 Heat trace and insulate flowline from choke to wellhead ,, 26-Feb 23:00 15.083 Schlumberger rigging up to run guns 27-Feb 1:00 17.083 Schlumberger RIH with first gun run, flowline open to tanks. ,, , 27-Feb 3:19 19.400 Shut in at wellhead in preparation for firing of guns 27-Feb 3:25 19.500 .Guns fired, no apparent pressure increase at surface 27-Feb 4:25 20.500 Make up second set if guns and RIH. 27-Feb 6:20 22.417 145 ~'~ Guns fired, tbg pressureto 172# 27-Feb 8:40 24.750 Out of hole with E-line, make up third set of guns and RIH. 27-Feb 10:50 26.917 Guns fired, pull out of hole with E-line 27-Feb 13:28 29.550 600 8 Adj. Open well on 8~64 adjustable choke. Diesel Reported As Water 27-Feb 13:30 29.583 105 16 Adj. Change choke to 16/64 adjustable 27-Feb 13:45 29.833 16 Adj. 27-Feb 14:00 30.083 16 Adj. · , 27-Feb 14:15 30.333 16 Adj. page no: 1.1 Alpnl B1 / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: DST #1 Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC HES Rep: Steve Tyburski Tubing Vol. bbl/ff: 0.01 Date/Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) iiiii 27-Feb 14:30 30.583 16 Adj. 27-Feb 14:45 30.833 16 Adj. 27-Feb 15:00 31·083 16 Adj. 27-Feb 15:15 31.333 16 Adj. 27-Feb 15:20 31.417 33 16 Adj. Shut in~ell at wing valve and rig down Schlumberger 27-Feb 16:20 32.417 16 Adj. Rig up hot.oiler for injection of Deisel 27-Feb 17:10 33.250 1600 16 Adj. .Open.well for flow on 16/64 adjustable choke 27-Feb 17:17 33.367 1550 18 Adj. Change choketo 18/64 27-Feb 17:20 33.417 1400 20 Adj. Change choke to 20/64 27-Feb 17:23 33.467 300 16 Adj. Decrease choke to 16/64 27-Feb 17:30 33.583 210 16 Adj. 27-Feb 17:45 33.833 22 16 Adj· 27-Feb 18:00 34.083 22 16 Adj. 27-Feb 18:15 34.333 23 16 Adj. 27-Feb 18:30 34.583 22 16 Adj. 27-Feb 18:45 34.833 21 15.5 Adj. 27-Feb 19:00 35.083 22 15.5 Adj. 27-Feb 19:15 35.333 21 15.5 Adj. 27-Feb 19:30 35.583 21 15.5 Adj. 27-Feb 19:45 35.833 21 15.5 Adj. 27-Feb 20:00 36.083 21 15.5 Adj. 27.-Feb 20:15 36.333 21 15.5 Adj. 27-Feb 20:22 36.450 21 15.5 Adj. Shut in at choke manifold, wait on CTU, monitor surface press. page no: 1.2 Alpnl B1 / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: DST #1 Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC HES Rep: Steve Tyburski Tubing Vol. bbllft: 0.01 Date/Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64tbs) 27-Feb 20:30 36.583 255 Total volume recovered: 5.1 BBLS 27-Feb 21':00 37.083 545 27-Feb 21:30 37.583 655 27-Feb 22:00 38.083 685 27-Feb 22:30 38.583 704 27-Feb 23:00 39.083 718 27-Feb 23:30 39.583 722 28-Feb 0:00 40.083 724 28-Feb 0:30 40.583 725 28-Feb 1:00 41.083 726 28-Feb 1:30 41.583 726 28-Feb 2:00 42.083 726 28-Feb 2:30 42.583 726 .... 28-Feb 3:00 43.083 726 ,,, 28-Feb 3:30 43.583 726 28-Feb 4:00 44.083 726 28-Feb 4:30 44.583 726 28-Feb 5:00 45.083 726 28-Feb 5:30 45.583 726 28-Feb 6:00 46.083 725 Dowell CTU on location and rigging up 28-Feb 6:30 46.583 724 28-Feb 7:00 47.083 725 .... 28-Feb 7:30 47.583 725 page no: 1.3 Alpnl B1 / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: DST #1 Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC HES Rep: Steve Tyburski Tubing Vol. bbllft: 0.01 Date/Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature' Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64tbs) 28-Feb 8:00 48.083 800 Open well for flow, C/T running in hole 28-Feb 8:20 48.417 300 20 Adj. 28-Feb 8:30 48.583 300 20 Adj. 28-Feb 8:40 48.750 300 22 Adj. 28-Feb 8:50 48.917 300 22 Adj. C/T at 2000' 28-Feb 9:00 49.083 300 22 Adj. Holding 300# at choke manifold 28-Feb 9:10 49.250 300 22 Adj. 28-Feb 9:20 49.417 100 17 Adj. Pressure dropping off at choke manifold 28-Feb 9:30 49.583 230 17 Adj. 28-Feb 9:40 49.750 450 18 Adj. 28-Feb 9:50 49.917 400 30 Adj. C/T Going to 4000' 28-Feb 10:00 50.083 280 18 Adj. N2 at 500 scf/m 28-Feb 10:10 50.250 250 14 Adj. 28-Feb 10:20 50.417 200 14 Adj. 28-Feb 10:30 50.583 260 22 Adj. C/T at 4000' 28-Feb 10:40 50.750 640 32 Adj. 28-Feb 10:50 50.917 300 32 Adj. N2 stopped pumping, C/T going to 6000' 28-Feb 11:00 51.083 270 16 Adj. 28-Feb 11:10 51.250 250 14 Adj. N2 back up at 500 scf/min 28-Feb 11:20 51.417 220 8 Adj. Put flow into vessel, C/T at 6000' 28-Feb 11:30 51.583 180 8 Adj. N2 at 350 scf/m 28-Feb 11:40 51.750 100 Adj. Shut in at choke N2 lost prime 28-Feb 11:50 51.917 100 Adj. page no: 1.4 Alpnl B1 / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: DST #1 Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC HES Rep: Steve Tyburski Tubing Vol. bbllff: 0.01 Date/Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 28-Feb 12:00 52.083 150 Adj. N2 pumping at 500 scf/m 28-Feb 12:10 52.250 400 10 Adj. 28-Feb 12:20 52.417 300 30 Adj. 28-Feb 12:30 52.583 280 36 Adj. 28-Feb 12:45 52833 280 22 Adj. 28-Feb 13:00 53.083 240 10 Adj. 28-Feb 13:15 53.333 10 Adj. 28-Feb 13:30 53.583 10 Adj. ×. 28-Feb 13:45 53.833 10 Adj. 28-Feb 14:00 54.083 240 10 Adj. Open well for flow 28-Feb 14:15 54.333 10Adj~ 28-Feb 14:30 54.583 400 20 Adj. Open choke to 20~64, Fluid to surface 28-Feb 14:45 54.833 720 24 Adj. .......... 28-Feb 15:00 55.083 500 38 Adj. 28-Feb 15:15 55.333 340 38 Adj. 28-Feb 15:30 55.583 260 38 Adj. .... 28-Feb 15:45 55.833 250 6 Adj. All return are straight deisel 28-Feb 16:00 56.083 530 24 Adj. Oil to surface, APl-40.8 al~ 60 F 28-Feb 16:15 56.333 550 24 Adj. 28-Feb 16:30 56.583 200 24 Adj. 28-Feb 16:45 56.833 210 24 Adj. 28-Feb 17:00 57.083 200 38 Adj. 28-Feb 17:15 57.333 180 38 Adj. page no: 1.5 Alpnl B1 / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: DST #1 Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC HES Rep: Steve Tyburski Tubing Vol. bbl/ff: 0.01 Date/Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure 'Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) I 28-Feb 17:30 57.583 180 38 Adj. 28-Feb 17:45 57.833 210 38 Adj. 28-Feb 18:00 58.083 200 38 Adj. 28-Feb 18:15 58.333 180 38 Adj. 28-Feb 18:30 58.583 180 38 Adj. 28-Feb 18:45 58.833 180 38 Adj. 28-Feb 19:00 59.083 150 38 Adj. 28-Feb 19:15 59.333 280 38 Adj. , 28-Feb 19:30 59.583 280 38 Adj. Combustible gas at surface 28-Feb 19:45 59.833 215 38 Adj, 28-Feb 20:00 60.083 220 38 Adj. 28-Feb 20:15 60.333 200 38 Adj. 28-Feb 20:30 60.583 205 38 Adj. I 28-Feb 20:45 60.833 210 38 Adj. . 28-Feb 21:00 61.083 220 38 Adj. HES air supply line frozen, shut in well, shut down N2 , ,,, 28-Feb 21:15 61.333 21:28 Start pumping N2 at 550 scf/m 28-Feb 21:30 61.583 290 38 Adj. 28-Feb 21:45 61,833 160 38 Adj. 28-Feb 22:00 62.083 100 38 Adj. 28-Feb 22:15 62.333 220 38 Adj. 28-Feb 22:30 62.583 160 38 Adj. 28-Feb 22:45 62.833 190 38 Adj, 28-Feb 23:00 63.083 170 38 Adj. page no: 1.6 Alpnl B1 / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: DST #1 Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# × 200" WC HES Rep: Steve Tyburski Tubing Vol. bbl/ft: 0.01 Date/Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 28-Feb 23:15 63.333 170 38 Adj. 28-Feb 23:30 63.583 160 38 Adj. 28-Feb 23:45 63.833 165 38 Adj. 29-Feb 0:00 64.083 160 38 Adj. N2 Shut down 29-Feb 0:15 64.333 130 38 Adj. 29-Feb 0:30 64,583 95 38 Adj. 29-Feb 0:45 64.833 90 38 Adj. 29-Feb 1:00 65.083 80 38 Adj. 29-Feb 1:15 65.333 80 38 Adj. 29-Feb 1:30 65.583 80 38 Adj. 29-Feb 2:00 66.083 80 38 Adj. Start taking half hour readings 29-Feb 2:30 66.583 77 38 Adj. 29-Feb 3:00 67.083 100 38 Adj. 29-Feb 3:30 67.583 170 38 Adj. 29-Feb 4:00 68.083 170 38 Adj. 29-Feb 4:30 68.583 180 38 Adj. Go to 15 minute readings 29~Feb 4:45 68.833 160 38 Adj. .... 29-Feb 5:00 69.083 150 38 Adj. 29-Feb 5:15 69,333 140 38 Adj. 29-Feb 5:30 69.583 170 38 Adj. 29-Feb 5:45 69.833 170 38 Adj. 29-Feb 6:00 70.083 145 38 Adj. ,,, 29-Feb 6:15 70.333 140 38 Adj. HES lost instrument air, .shut in at manifold page no: 1.7 Alpnl B1 / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: DST #1 Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# × 200" WC HES Rep: Steve Tyburski Tubing Vol. bbllft: 0.01 Date/Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 29-Feb 6:30 70.583 125 38 Adj. 06:26 open for flow, go to half hour readings 29-Feb 7:00 71.083 120 31 38 Adj. 29-Feb 7:30 71.583 135 32 38 Adj. 29-Feb 8:00 72.083 130 30 38 Adj. 29-Feb 8:30 72.583 130 32 38 Adj. HES instrument air line frozen, shut in at choke ,, 29-Feb 9:00 73.083 38 Adj. 29-Feb 9:30 73.583 190 31 38 Adj. 09:20 Air back on line, open well 29-Feb 10:00 74.083 110 31 38 Adj. 29-Feb 10:30 74.583 120 32 38 Adj. 29-Feb 11:00 75.083 140 29 38 Adj. 29-Feb 11:30 75.583 135 28 38Adj. 29-Feb 12:00 76.083 115 30 38Adj. 29-Feb 12:30 76.583 120 30 38 Adj. 29-Feb 13:00 77.083 115 30 38 Adj. Start dumping out of water leg 29-Feb 13:30 77.583 110 31 38 Adj. 29-Feb 14:00 78.083 110 33 38 Adj. 29~Feb 14:30 78.583 110 33 38 Adj. 29-Feb 15:00 79.083 110 38 38 Adj. 29-Feb 15:30 79.583 120 38 38 Adj. 29-Feb 16:00 80.083 125 38 38 Adj. 29-Feb 16:30 80.583 125 38 38 Adj. 29-Feb 17:00 81.083 125 38 38 Adj. 29~Feb 17:30 81.583 125 38 38 Adj. CTU rigging down page no: 1.8 Alpnl B1 / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: DST #1 Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC HES Rep: Steve Tyburski Tubing Vol. bbl/ft: 0.01 Date/Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64tbs) 29-Feb 18:00 82.083 130 38 38 Adj. 29-Feb 18:30 82.583 132 36 38 Adj. Changed to .750 orifice 29-Feb 19:00 83.083 132 36 38 Adj. 29-Feb 19:30 83.583 133 36 38 Adj. 29-Feb 20:00 84.083 132 36 38 Adj. ,,,,, 29-Feb 20:30 84.583 132 36 38 Adj. 29-Feb 21:00 85.083 133 36 38 Adj. , , 29-Feb 21:30 85.583 132 36 38 Adj. Trace B.S.&W 29-Feb 22:00 86.083 132 36 38 Adj. 29-Feb 22:30 86.583 130 36 38 Adj. 29-Feb 23:00 87.083 133 32 38 Adj. 29-Feb 23:30 87.583 142 40 38 Adj. 01-Mar 0:00 88.083 141 40 38 Adj. 01-Mar 0:30 88.583 150 41 38 Adj. Shut in Well To Test Shut In tool (00:28). Reopen (00:30), V 01-Mar 1:00 89.083 152 43 38 Adj. 01-Mar 1:30 89.583 160 45 38 Adj. 01-Mar 2:00 90.083 165 50 38 Adj. 01-Mar 2:30 90.583 150 44 38 Adj. .... 01-Mar 3:00 91.083 135 40 38 Adj. 01-Mar 3:30 91,583 135 41 38 Adj. 01-Mar 4:00 92.083 130 38 38 Adj. , 01-Mar 4:30 92.583 140 39 38 Adj. ., 01-Mar 5:00 93.083 138 41 38 Adj. BS&W: 0% page no: 1,9 Alpnl B1 / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: DST #1 Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC HES Rep: Steve Tyburski Tubing Vol. bbllft: 0.01 Date/Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 01-Mar 5:30 93.583 135 41 38 Adj. 01-Mar 6:00 94.083 143 40 38 Adj. 01-Mar 6:30 94.583 145 39 38 Adj. 01-Mar 7:00 95083 145 41 38 Adj. 01-Mar 7:30 95.583 140 41 38 Adj. 01-Mar 7:57 96.033 140 42 38 Adj. Close downhole shut in tool, shut in at manifold and heater 01-Mar 9:40 97.750 Bleed down flowline to 150 psi from 400 psi .... page no: 1.10 Alpnl B1 / Job Log ~ 0 Z 0 0 8 8 8 8 8 8 8 8 8 8 8 8 8 ° ° 8 8 8o o o o d ~ d 0 o o 0 d ~ d d d 0 0 0 ~ 0 8 8 8 8 8 ~ 8 8 8 8 8© 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8 8° °o o o d o d o o o 0 o o d o o d o o o o 8 8 8 8 8 8 8 8 8 8 8 8 8° 0 °o o o 8 o 0 o d d o d o d o o o d o o o o d o o o o o o o o o o o o o o o o o o o o o 08~88~88~88°~o~88o o o o o ~ ~ o o o o o o o ~ ~ ~ o o ~ o o o o o ~ ~ ~ ~ 0 ~ 0 E ~C~ 8 ~ ° ° ° ~ 8 ~ ° ~ 8~ o . ........... ~ .... ~ .......... , ........ ,, ....... o o · ~ ~ E 1 ~ ~ E .... 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Well Number: Alpine #1B Test Number: DST #1 HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: 1.6667 Date/Time Truck Tank Starting Strap Ending Strap Vol Cum Number Number Transferred Volumn (mm/dd/yy hh:mm) (ft) (in) (bbls) (fl) (in) (bbls) (bbl) (bbl) 01-Mar-96 13:00 142-018 2 13.00 1.00 261.67 7.00 11.67 250.01 250.01 01 -Mar-96 13:00 142-018 3 4.00 2.25 83.75 2.00 1.00 41.67 42.08 292.09 03-Mar-96 13:45 142-018 4 11.00 10.00 236.67 9.00 15.00 221.67 513.76 03-Mar-96 13:45 142-018 3 2.00 1.00 41.67 5.75 9.58 32.08 545.84 Page 7.1 Alpinlbl / Tank Transfer Data Halliburton Energy Services Tank Farm Totals Summary Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: DST #1 H.E.S. Rep: Steve Tyburski Company Rep: Tim Scarbr0ugh 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 6.67 15.42 0.00 22.08 0.00 08-Mar-96 10:00 2 6.67 255.01 250.01 11.67 0.00 08-Mar-96 10:00 3 17.08 66.67 74.17 9.58 0.00 08-Mar-96 10:00 4 23.33 188.34 221.67 15.00 (25.00) 08-Mar-96 10:00 5 0.00 0.00 0.00 0.00 0.00 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 Totals 53.75 525.43 545.84 58.33 (25.00) Fluid Split Fluid Splits At Recorded Conditions To Correlate To Tank Volumes. Oil (bbl) 410.54 Water2 (bbl) 0.01 Diesel1 (bbl) 115.00 Notes:~ Estimated By Customer. 2 Includes solids and gel fluids.(BS&W) 3 Volume Difference Due To Measurments, Expansion or Contraction. Page 8.1 AlpnlB1 / Tank Farm Summary This Section Left Intentionally Blank. 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: 030396 3-Mar-96 Kenai Steve Tyburski Tim Scarbmugh Wellhead Land ARCO Alaska, INC. Coleville River Alpine No. lB 8406 to 8493 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 Customer: ARCO Alaska, INC. Well' Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Gas Meter Run ID: 3.83 Barton Recorder Range: 1500~ X 200" WC HES Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 03-Mar 14:26 0.000 450 200 Open well for post-frac flow to APC tanks, attempting to maintain 03-Mar 14:30 0.067 300 200 .5 bbl/min flow rate. All Fluids Repo~ted As Water lill Oil To Surf. 03-Mar 15:00 0.567 260 I' 03-Mar 15:30 1.067 240 200 03-Mar 16:00 1.567 200 200 03-Mar 16:30 2.067 150 200 ~,, 03-Mar 17:00 2.567 20 By-pass choke, deisel giving way to gel 03-Mar 17:30 3.067 20 200 03-Mar 18:00 3.567 25 450 03-Mar 18:30 4.067 25 500 03-Mar 19:00 4.567 35 Trace of sand. Gas To Surface. , , 03-Mar 19:30 5067 35 580 03-Mar 20:00 5.567 35 650 03-Mar 20:30 6.067 85 750 Put flow back through choke manifold 03-Mar 21:00 6.567 175 780 Rocking choke every 15 min. 03-Mar 21:30 7.067 180 850 03-Mar 22:00 7.567 247 880 03-Mar 22:30 8.067 245 900 03-Mar 23:00 8567 245 920 03-Mar 23:30 9.067 245 950 PH-8 04-Mar 0:00 9.567 245 950 Trace of sand. 04-Mar 0:30 10.067 250 950 04-Mar 1:00 10.567 250 975 Page no: 1.1 Final_Reports / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# X 200" WC HES Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64tbs) 04-Mar 1:30 11.067 250 1000 Fluid rate to APC tank 30 bbl/hr. 04-Mar 2:00 11.567 250 1050 04-Mar 2:30 12.067 250 1075 04-Mar 3:00 12.567 250 1080 Oil To Surface. 04-Mar 3:30 13.067 250 1110 Trace of sand. 04-Mar 4:00 13.567 250 1100 PH-8 04-Mar 4:30 14.067 250 1100 PH-8 04-Mar 5:00 14.567 300 1150 PH-8 04-Mar 5:30 15.067 300 1150 PH-8 04-Mar 6:00 15.567 300 1150 PH-8 04-Mar 6:30 16.067 300 1150 PH-8 04-Mar 7:00 16.567 400 1250 PH-8 04-Mar 7:30 17.067 450 1250 PH-8 04-Mar 8:00 17.567 450 1250 PH-8, Raise flow rate to .75 bbl/min 04-Mar 8:30 18.067 450 1270 PH-8 04-Mar 9:00 18.567 450 1290 PH-8 04-Mar 9:30 19.067 360 1320 PH-8, Changethe flow rateto 1 bbl/min 04-Mar 10:00 19.567 370 1350 PH-8 04-Mar 10:30 20.067 225 1440 PH-8, trace of sand 04-Mar 11:00 20.567 220 500 Well is slugging, PH-8, 10:52 Bleed casing from 1490 to 500 04-Mar 11:30 21.067 220 520 PH-8 04-Mar 12:00 21.567 450 550 PH-8 Total fluid recovered since opening is roughly 580 bbls. 04-Mar 12:30 22.067 475 475 PH-8, Trace of sand Page no: 1.2 Final_Reports / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# × 200" WC HES Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 04-Mar 13:00 22.567 450 450 PH-8, Trace of sand 04-Mar 13:30 23.067 400 500 PH-8, Trace of sand 04-Mar 14:00 23.567 500 500 Switch to HES tanks #3 & #4. #3 I.S. = 5.75" #4 I.S. = 4" 04-Mar 14:30 24.067 650 500 20 Adj. Estimated 725.4 bbls Fluid to Frac Tanks.(23 hours 34 minutes) 04-Mar 15:00 24.567 650 52 500 20 Adj. Flow into separator. Close off Flow to tank #3. 04-Mar 15:30 25.067 640 50 500 28 Adj. 15:17 change choke to 24/64, 15:27 choke to 28/64 04-Mar 16:00 25.567 450 48 500 40 Adj. 15:40 Choke to 40/64 04-Mar 16:30 26.067 440 48 500 54 Adj. 16:15 choke to 54/64, 16:30 choke to 28/64 04-Mar 17:00 26.567 490 50 500 28 Adj. 04-Mar 17:30 27.067 480 50 400 38 Adj. 04-Mar 18:00 27.567 445 50 410 38 Adj. 04-Mar 18:30 28.067 450 51 500 38 Adj. 04-Mar 19:00 28.567 500 54 500 38 Adj. 04-Mar 19:30 29.067 510 54 500 38Adj. Switch to Tank #3. I.S. =8" 04-Mar 20:00 29.567 520 54 500 38 Adj. 04-Mar 20:30 30.067 525 52 500 38 Adj. 04-Mar 21:00 30.567 525 52 500 38 Adj. 04-Mar 21:30 31.067 530 52 500 38 Adj. Switch to Tank #2. I.S. = 7". 04-Mar 22:00 31.567 510 55 550 38 Adj. 22:04 Change choke to 44/64 04-Mar 22:30 32.067 500 55 575 34 Adj. 22:15 Change choke to 34/64 04-Mar 23:00 32.567 500 55 575 34 Adj. 04-Mar 23:30 33.067 510 53 575 34 Adj. 05-Mar 0:00 33.567 510 53 575 37 Adj. Increased choke to 37/64 'T i Page no: 1.3 Final_Reports / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# X 200" WC HES Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 05-Mar 0:30 34.067 500 53 575 37 Adj. Changed to 1.250 orifice plate. 05-Mar 1:00 34.567 490 52 575 37 Adj. 05-Mar 1:30 35.067 490 52 575 37 Adj. 01:45 increase choke to 39~64 05-Mar 2:00 35.567 490 52 600 39 Adj. Injecting emulsion breaker. Switch to Tank #3. I.S. = 3' 10.75" 05-Mar 2:30 36.067 475 50 600 39 Adj. 05-Mar 3:00 36.567 470 51 625 39 Adj. 05-Mar 3:30 37.067 475 51 625 39 Adj. 05-Mar 4:00 37.567 475 51 650 39 Adj. 05-Mar 4:30 38.067 475 51 650 39 Adj. 05-Mar 5:00 38.567 450 52 650 39 Adj. 05-Mar 5:30 39.067 475 51 650 39 Adj. Switch to Tank #2. I.S. = 1' 2". 05-Mar 6:00 39.567 475 52 650 39 Adj. 05-Mar 6:30 40.067 475 51 650 39 Adj. 05-Mar 7:00 40.567 410 50 650 43 Adj. 06:45 choke to 43/64 05-Mar 7:30 41.067 405 50 650 43 Adj. 05-Mar 8:00 41.567 400 50 650 43 Adj. 05-Mar 8:30 42.067 405 56 700 43 Adj. Switch to Tank~4. I.S. - 6" 05-Mar 9:00 42.567 405 58 700 43 Adj. 05-Mar 9:30 43.067 410 60 700 43 Adj. 05-Mar 10:00 43.567 415 59 710 43 Adj. 05-Mar 10:30 44.067 415 58 720 43 Adj. 05-Mar 11:00 44.567 415 60 720 43Adj. Switch to Tank #3. I.S. - 3'6.5" 05-Mar 11:30 45.067 415 59 720 48 Adj. Page no: 1.4 Final_Reports / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# X 200" WC HES Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hfs) (psig) (Deg. F.) (psig) (64ths) 05-Mar 12:00 45.567 390 56 710 48 Adj. 05-Mar 12:30 46.067 390 56 700 48 Adj. 05-Mar 13:00 46.567 370 58 730 48 Adj. 13:20 Change choke to 56/64 05-Mar 13:30 47.067 330 56 760 56 Adj. 05-Mar 14:00 47.567 330 58 760 56 Adj. Switch to Tank CfA. I.S.: 7" 05-Mar 14:30 48.067 330 60 800 56 Adj. 05-Mar 15:00 48.567 330 62 810 56 Adj. 15:05 Change choke to 64/64 05-Mar 15:30 49.067 300 61 825 64 Adj. 05-Mar 16:00 49.567 300 61 850 64 Adj. 05-Mar 16:30 50.067 300 61 860 64 Adj. Switch to Tank #3. I.S. = 11" 05-Mar 17:00 50.567 300 60 880 64 Adj. 05-Mar 17:30 51.067 300 60 900 64 Adj. 05-Mar 18:00 51.567 300 60 900 64 Adj. 05-Mar 18:30 52.067 300 60 900 64 Adj. 05-Mar 19:00 52.567 300 62 900 64 Adj. 05-Mar 19:30 53.067 300 62 900 64Adj. 19:32 Change choke to 72/64. Switch to Tank #4. I.S.=7". 05-Mar 20:00 53.567 300 62 900 72 Adj. 05-Mar 20:30 54.067 300 60 910 72 Adj. 05-Mar 21:00 54.567 300 60 910 72 Adj. 05-Mar 21:30 55.067 290 60 940 72 Adj. 05-Mar 22:00 55.567 290 60 950 72 Adj. 05-Mar 22:30 56.067 290 60 950 72 Adj. Switch to Tank#3. I.S. = 1' 6.5" 05-Mar 23:00 56.567 290 60 950 72 Adj. Page no: 1.5 Final_Reports / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# × 200" WC HES Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hfs) (psig) (Deg. F.) (psig) (64ths) 05-Mar 23:30 57.067 290 60 950 72 Adj. 23:35 Change choke to 80/64, drop back pressure to 150 # 06-Mar 0:00 57.567 290 60 950 80 Adj. 06-Mar 0:30 58.067 275 60 960 80 Adj. 06-Mar 1:00 58.567 270 60 960 80 Adj. Switch to Tank ¢/4. I.S. - 2' 2.5". 06-Mar 1:30 59.067 265 60 960 80 Adj. 06-Mar 2:00 59.567 265 60 990 80 Adj. 06-Mar 2:30 60.067 265 61 990 80 Adj. 06-Mar 3:00 60.567 265 61 995 80 Adj. Switch to Tank#3. I.S. - 7.5" 06-Mar 3:30 61.067 270 64 1000 80 Adj. 06-Mar 4:00 61.567 265 63 1000 80 Adj. 06-Mar 4:30 62.067 265 63 1000 80 Adj. 06-Mar 5:00 62.567 260 63 1000 80 Adj. 06-Mar 5:30 63.067 260 63 1000 80 Adj. 06-Mar 6:00 63.567 260 63 1000 80 Adj. 06-Mar 6:30 64.067 260 64 1000 80 Adj. Switch to Tank #-4. I.S. -- 10" 06-Mar 7:00 64.567 250 64 1000 80 Adj. 06-Mar 7:30 65.067 250 65 1000 80 Adj. 06-Mar 8:00 65.567 250 65 1000 80 Adj. 06-Mar 9:00 66.567 250 65 1000 80 Adj. Start taking 1 hour readings. Switch to Tank #2. I.S. = 7.5". 06-Mar 10:00 67.567 250 66 1000 80 Adj. 06~Mar 11:00 68.567 250 65 1000 80 Adj. 11:30 Bleed down casing to 75# 06-Mar 12:00 69.567 250 64 75 80 Adj. Switch to Tank #3. I.S. - 1' 5". 06-Mar 13:00 70.567 250 63 75 80 Adj. Drop back pressure to 130# Page no: 1.6 Final_Reports / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# X 200" WC HES Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 06-Mar 14:00 71.567 250 63 75 80 Adj. 06-Mar 15:00 72.567 250 63 75 80 Adj. Switch to Tank #4. I.S. -- 6". 06-Mar 16:00 73.567 250 63 75 80 Adj. 06-Mar 17:00 74.567 250 63 78 80 Adj. 06-Mar 18:00 75.567 250 63 78 80Adj. Switch to Tank #3. I.S.=2'7". 06-Mar 19:00 76.567 250 63 85 80 Adj. 06-Mar 20:00 77.567 250 63 100 80 Adj. Switch to Tank #-4. I.S. = 1' 4.25". 06-Mar 21:00 78.567 250 63 100 80 Adj. 06-Mar 22:00 79.567 250 63 100 80 Adj. Switch to Tank #3. I.S. = 7.5" 06-Mar 23:00 80.567 250 63 110 80 Adj. 07-Mar 0:00 81.567 250 63 110 80 Adj. 07-Mar 1:00 82.567 250 63 120 80Adj. Switch to Tank #4. I.S.- 10'5" 07-Mar 2:00 83.567 250 63 120 80 Adj. Switch to Tank #2. I.S. - 1' 1.75" 07-Mar 3:00 84.567 250 63 120 80 Adj. 07-Mar 4:00 85.567 250 65 120 80 Adj. 07-Mar 5:00 86.567 265 65 120 80 Adj. Switch to Tank #3. I.S. = 1' 4.25" 07-Mar 6:00 87.567 265 65 135 80 Adj. 07-Mar 7:00 88.567 260 65 150 80 Adj. 07-Mar 8:00 89.567 260 65 180 80 Adj. Switch to Tank #4. I.S. = 1' 10.25" 07-Mar 9:00 90.567 250 65 180 80 Adj. 07-Mar 10:00 91.567 255 65 180 80 Adj. 'Switch to Tank #3. I.S. = 2'. 07-Mar 11:00 92.567 240 65 180 80 Adj. 07-Mar 12:00 93.567 245 65 180 80 Adj. Page no: 1.7 FinaLReports / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# X 200" WC HES Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure~ Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 07-Mar 13:00 94.567 245 65 180 80Adj. Switch to Tank #-4. I.S. - 1'. 07-Mar 14:00 95.567 245 65 180 80 Adj. 07-Mar 15:00 96.567 245 65 180 80 Adj. 07-Mar 16:00 97.567 245 65 180 80 Adj. Switch to Tank #3. I.S. - 9". 07-Mar 17:00 98.567 245 65 180 80 Adj. 17:20 Stop injecting emulsion breaker 07-Mar 18:00 99.567 245 65 190 80 Adj. 07-Mar 19:00 100.567 245 65 190 80 Adj. Switch to Tank #4. I.S. - 7". 07-Mar 20:00 101.567 240 64 220 80 Adj. 07-Mar 21:00 102.567 245 64 230 80 Adj. 07-Mar 22:00 103.567 240 64 250 80 Adj. 22:25 - ElL RIH. Switch to Tank #2. I.S. = 6.5" 07-Mar 23:00 104.567 240 65 240 80 Adj. 23:40 - ElL OOH 08-Mar 0:00 105.567 240 70 250 80 Adj. 08-Mar 1:00 106.567 240 71 250 80Adj. Switch to Tank ~. I.S. - 5'5". 08-Mar 2:00 107.567 240 71 250 80 Adj. 08-Mar 3:00 108.567 240 71 250 80 Adj. 03:25 - ElL RIH. Switch to Tank #3. I.S. = 6". 08-Mar 4:00 109.567 240 71 250 80 Adj. 08-Mar 5:00 110.567 240 70 250 80 Adj. 08-Mar 6:00 111.567 235 69 260 80 Adj. Switch to Tank ~4. I.S. = 1' 0.5". 08-Mar 7:00 112.567 240 70 260 80 Adj. 08-Mar 8:00 113.567 240 70 260 80 Adj. 08-Mar 9:00 114.567 240 70 250 80 Adj. Switch to Tank #3. I.S. - 11.5". 08-Mar 9:11 114.750 240 70 250 80 Adj. Shut In Well Downhole. 08-Mar 9:15 114.817 Shut In Well at Choke Manifold. Page no: 1.8 Final_Reports / Job Log Customer: ARCO Alaska, INC. Well: Alpine #lB Stage: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Welt Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 II Wellhead Data II 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 Cumin. 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) 3-Mar 14:26 450.0 200.0 100.0 Open well for post-frac flow to APC tanks, attempting to maintain 3-Mar 14:30 300.0 200.0 100.0 0.00 0.00 0.74 266.67 0.00 .5 bbl/min flow rate. All Fluids Repoded As Water Till Oil To Surf. 3-Mar 15:00 260.0 200.0 100.0 0.00 0.00 6.30 266.67 0.00 3-Mar 15:30 240.0 200.0 100.0 0.00 0.00 15.00 417.78 0.00 3-Mar 16:00 200.0 200.0 100.0 0.00 0.00 27.50 600.00 0.00 3-Mar 16:30 150.0 200.0 100.0 0.00 0.00 35.00 360.00 0.00 3-Mar 17:00 20.0 200.0 100.0 0.00 0.00 40.00 240.00 0.00 By-pass choke, deisel giving way to gel 3-Mar 17:30 20.0 300.0 100.0 0.00 0.00 45.00 240.00 0.00 3-Mar 18:00 25.0 450.0 100.0 0.00 0.00 50.00 240.00 0.00 .. .-~ 3-Mar 18:30 25.0 500.0 100.0 0.00 0.00 55.00 240.00 0.00 -- 3-Mar 19:00 35.0 500.0 100.0 0.00 0.00 65.00 480.00 0.00 Trace of sand. Gas To Surface, 3-Mar 19:30 35.0 580.0 100.0 0.00 0.00 75.00 480.00 0.00 3-Mar 20:00 35,0 650.0 100.0 0.00 0.00 87.50 600.00 0.00 3-Mar 20:30 85.0 750.0 100.0 0.00 0.00 105.00 840.00 0.00 Put flow back through choke manifold 3-Mar 21:00 175.0 780.0 100.0 0.00 0.00 122.50 840.00 0.00 Rocking choke every 15 min. 3-Mar 21:30 180.0 850.0 100.0 0.00 0.00 136.11 653.33 0.00 3-Mar 22:00 247.0 880.0 100.0 0.00 0.00 142.78 320.00 0.00 3-Mar 22.30 245.0 900.0 100.0 0.00 0,00 150.71 380.95 0.00 Page 2.1 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Alpine #lB Stage: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 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) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 3-Mar 23:00 245.0 920.0 100.0 0.00 0.00 160.00 445.78 0.00 3-Mar 23:30 245.0 950.0 100.0 0.00 0.00 170.56 506.67 0.00 PH-8 4-Mar 00:00 245.0 950.0 100.0 0.00 0.00 181.43 521.90 0.00 Trace of sand, 4-Mar 00:30 250.0 950.0 100.0 0.00 0.00 192.41 526.98 0.00 4-Mar 01:00 250.0 975.0 100.0 0.00 0.00 203.22 518.73 0.00 4-Mar 01:30 250.0 1000.0 100.0 0.00 0.00 217.50 685.71 0.00 :luid rate to APC tank 30 bbl/hr. 4-Mar 02:00 250.0 1050.0 100.0 0.00 0.00 232.50 720.00 0.00 4-Mar 02:30 250.0 1075.0 100.0 0.00 0.00 243.33 520.00 0.00 , 4-Mar 03:00 250.0 1080.0 650 5.30 254.43 253.18 472.52 0.00 Oil To Surface. 4-Mar 03:30 250.0 1110.0 40.0 12,21 331.83 257.79 221.22 0.00 Trace of sand. 4-Mar 04:00 250.0 1100.0 40.0 19.71 360.00 262.79 240.00 0.00 PH-8 4-Mar 04:30 250.0 1100.0 40.0 26.77 338.67 267.49 225.78 0.00 PH-8 4-Mar 05:00 300.0 1150.0 50.0 32.89 293.78 273.61 293.78 0.00 'PH-8 4-Mar 05:30 300.0 1150.0 30.0 43.39 504.00 278.11 216.00 0.00 PH-8 4-Mar 06:00 300.0 1150.0 25.0 53.51 486.00 281.49 162.00 0.00 PH-8 4-Mar 06:30 300.0 1150.0 20.0 65.51 576.00 284.49 144.00 0.00 PH-8 4-Mar 07:00 400.0 1250.0 17.0 82.11 796.80 287.89 163.20 0.00 PH-8 4-Mar 07:30 450.0 1250.0 22.0 94.59 599.04 291.41 168.96 0.00 ~H-8 Page 2.2 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Alpine #1 B Stage: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Wellhead Data ~ 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 Cumin. 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) 4-Mar 08:00 450.0 1250.O 22.0 107.70 628.99 295.10 177.41 0.00 PH-8, Raise flow rate to .75 bbl/min 4-Mar 08:30 450.0 1270.O 16.0 121.31 653.19 297.69 124.42 0.00 PH-8 4-Mar 09:00 450.0 1290.0 17.0 138.57 828.68 301.23 169.73 0.00 PH-8 4-Mar 09:30 360.0 1320.0 30.0 156.07 840.00 308.73 360.00 0.00 PH-8, Change the flow rate to 1 bbl/min 4-Mar 10:00 370.0 1350.0 30.0 171.12 722.40 315.18 309.60 0.00 PH-8 4-Mar 10:30 225.0 1440.0 25.0 195.12 1152.00 323.18 384.00 0.00 PH-8, trace of sand 4-Mar 11:00 220.0 500.0 36.0 228.46 1600.52 341.94 900.29 0.00 Well is slugging, PH-8, 10:52 Bleed casing from 1490 to 500 4-Mar 11:30 220.0 520.0 22.0 244.92 789.99 346.58 222.82 0.O0 PH-8 4-Mar 12:00 450.0 550.0 22.0 250.80 282.05 348.24 79.55 0.00 PH-8 Total fluid recovered since opening is roughly 580 bbls. 4-Mar 12:30 475.0 475.0 22.0 267.00 777.51 352.80 219.30 0.00 PH-8, Trace of sand 4-Mar 13:00 450.0 450.0 22,0 278.70 561.60 356.10 158.40 0.00 PH-8, Trace of sand 4-Mar 13:30 400.0 500.0 17.0 307.41 1378.47 361.99 282.34 0.00 PH-8, Trace of sand 4-Mar 14:00 500.0 500.0 22.0 351.09 2096.65 374.31 591.36 0.00 Switch to HES tanks #3 & #4. #3 I.S. = 5.75" #4 I.S. = 4" 4-Mar 14:30 650.0 500.0 20 Adj. 11.0 354.43 160.20 374.72 19.80 0.00 Estimated 725.4 bbls Fluid to Frac Tanks.(23 hours 34 minutes) ,, . , . , .... 4-Mar 15:00 650.0 52.0 500.0 20 Adj. 18.0 363.31 426.27 376.67 93.57 0.00 Flow into separator. Close off Flow to tank #3. 4-Mar 15:30 640.0 50.0 500.0 28 Adj. 14.0 364.39 51.60 376.84 8.40 8.12 390.00 7.558 15:17 change choke to 24/64, 15:27 choke to 28/64 4-Mar 16:O0 450.0 48.0 500.0 40 Adj. 40.0 377.14 612.00 385.34 408.00 22.33 682.00 1.114 15:40 Choke to 40/64 4-Mar 16 30 440.0 48.0 500.0 54 Adj. 22.0 404.36 1306.73 393.04 369.60 35.25 620.00 0.474 16:15 choke to 54/64, 16:30 choke to 28/64 Page 2.3 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Alpine #lB Stage: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WG H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Wellhead Data ~ Cumulative Volumes and Rates I[ 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) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 4-Mar 17:00 490.0 50.0 500.0 28 Adj. 22.0 428.90 1178.02 400.01 334.44 46.67 548.00 0.465 4-Mar 17:30 480.0 50.0 400.0 38 Adj. 14.0 452.06 1111.61 403.80 181.98 55.77 437.00 0.393 4-Mar 18:00 445.0 50.0 410.0 38 Adj. 15.0 481.29 1402.97 408.99 248.98 64.71 429.00 0.306 4-Mar 18:30 450.0 51.0 500.0 38 Adj. 11.0 508.21 1292.27 412.34 160.62 71.40 321.00 0.248 4-Mar 19:00 500.0 54.0 500.0 38 Adj. 12.0 532.17 1149.99 415.64 158.40 77.56 296,00 0.257 4-Mar 19:30 510.0 54.0 500.0 38 Adj. 13.0 556.29 1157,78 419.27 174.22 85.50 381.00 0.329 Switch to Tank#3. I.S. = 8" 4-Mar 20:00 520.0 540 500.0 38 Adj. 14.0 574.72 884.70 422,30 145.62 93.60 389.00 0.440 4-Mar 20:30 525.0 52.0 500.0 38 Adj. 15.0 601.08 1265.19 426.99 225.00 107.56 670.00 0.530 4-Mar 21:O0 525.0 52.0 500.0 38Adj. 15.0 629.56 1366.88 432.05 243.00 120.19 606.00 0.443 4-Mar 21:30 530.0 52.0 500.0 38Adj. 5.0 646.46 811.43 432.94 43.01 134.17 671.00 0.827 Switch to Tank #2. I.S. = 7". 4-Mar 22:00 510.0 55.0 550.0 38 Adj. 5.0 671.62 1207.64 434.28 64.01 148.21 674.00 0.558 22:04 Change choke to 44164 4-Mar 22:30 500.0 55.0 575.0 34 Adj. 5.0 710.90 1885.53 436.36 100.01 163.65 741.00 0.393 22:15 Change choketo 34/64 4-Mar 23:130 500.0 55.0 575.0 34 Adj. 5.0 744.29 1602.72 438.13 85.01 179.60 766.00 0.478 4-Mar 23:30 510.0 53.0 575.0 34 Adj. 5.0 767.46 1111.83 439.36 58.99 195.90 782.00 0.703 5-Mar 00:O0 510.0 53.0 575.0 37 Adj. 5.0 792.59 1206.37 440.70 64.01 214.50 893.00 0.740 Increased choke to 37/64 5-Mar 00:30 500.0 53.0 575.0 37 Adj. 5.0 834.21 1997.94 442.90 106.01 231.65 823.00 0.412 Changed to 1.250 orifice plate. 5-Mar 01:00 490.0 52.0 575.0 37 Adj. 5.0 866.32 1541.02 444.61 82.01 249.12 839,00 0.544 5-Mar 01:30 490.0 52.0 575.0 37 Adj. 5.0 898.14 1527.69 446.30 81.00 266.94 855.00 0,560 01:45 increase choke to 39/64 Page 2.4 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Alpine #lB Stage: Post Frac Flow Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 II Wellhead Data II Cumulative Volumes and Rates ,11 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) 5-Mar 02:00 490.0 52.0 600.0 39 Adj. 10.0 923.37 1211.01 449.13 135.98 285.94 912.00 0.753 Injecting emulsion breaker. Switch to Tank#3. I.S. = 3' 10.75" 5-Mar 02:30 475.0 50.0 600.0 39 Adj. 5.0 965.04 2000.06 451.34 106.01 304.25 879.00 0.439 5-Mar 03:00 470.0 51.0 625.0 39 Adj. 8.0 997.66 1565.64 454.21 137.59 322.02 853.00 0.545 5-Mar 03:30 475.0 51.0 625.0 39 Adj. 5.0 1025.55 1338.94 455.69 70.99 340.96 909.00 0.679 5-Mar 04:00 475.0 51.0 650.0 39 Adj. 5.0 1055.71 1447.49 457.29 76.99 359.96 912.00 0.630 5-Mar 04:30 475.0 51.0 650.0 39 Adj. 5.0 1100.91 2169.86 459.69 115.01 377.98 865.00 0.399 ... 5-Mar 05:00 450.0 52.0 650.0 39 Adj. 5.0 1133.42 1560.30 461.42 82.99 395.98 864.00 0.554 5-Mar 05:30 475.0 51.0 650.0 39 Adj. 5.0 1165.99 1563.61 463.14 82.99 414.10 870.00 0.556 Switch to Tank #2. I.S. = 1' 2". 5-Mar 05:00 475.0 52.0 650.0 39 Adj. 5.0 1207.86 2009.48 465.37 106.99 432.89 902.00 0.449 ,, 5-Mar 06:30 475.0 51.0 650.0 39 Adj. 5.0 1240.42 1563.05 467.10 82.99 451.77 906.00 0.580 5-Mar 07:00 410.0 50.0 650.0 43 Adj. 5.0 1278.78 1841.37 469.14 97.99 474.25 1079.00 0.586 06:45 choke to 43/64 5-Mar 07:30 405.0 50.0 650.0 43 Adj. 5.0 1320.41 1997.95 471.35 106.01 496.02 1045.00 0.523 5-Mar 08:00 400.0 50.0 650.0 43 Adj. 6.0 1355.25 1672.31 473.60 107.99 518.00 1055.00 0.631 5-Mar 08:30 405.0 56.0 700.0 43 Adj. 6.0 1390.98 1715.17 475.90 110.41 541.08 1108.00 0.646 Switch to Tank #4. I.S. = 6" 5-Mar 09:00 405.0 58.0 700.0 43 Adj. 6.0 1430.10 1877.91 478.45 122.40 563.73 1087.00 0.579 5-Mar 09:30 410.0 60.0 700.0 43 Adj. 6.0 1472.82 2050.49 481.20 131.99 586.46 1091.00 0.532 5-Mar 10:00 415.0 59.0 710.0 43 Adj_ 6.0 1510.36 1801.87 483.63 116.41 609.23 1093.00 0.607 5-Mar 10:30 415.0 58.0 720.0 43 Adj. 6.0 1550.76 1939.32 486.23 124.79 632.14 110000 0.567 Page 2.5 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Alpine #lB Stage: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ × 200" WC H.E,S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Wellhead Data II 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 Cumin. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 5-Mar 11:00 415.0 60.0 720.0 43 Adj. 5.0 1592,24 1990.99 488.44 106.01 655.56 1124,00 0,565 Switch to Tank #3. I.S. = 3' 6.5" 5-Mar 11:30 415.0 59.0 720.0 48Adj. 5.0 1623.65 1507.62 490.10 79.99 678.85 1118,00 0.742 5-Mar 12:00 390.0 56.0 710.0 48Adj. 5.0 1670.19 2233.72 492.58 118.99 702,94 1156.00 0.518 5-Mar 12:30 390.0 56.0 700.0 48 Adj. 8.0 1709.18 1871.55 495.98 163.20 723.25 975.00 0.521 5-Mar 13:00 370.0 58.0 730.0 48 Adj. 6.0 1751.16 2015.18 498.68 129.60 746.83 1132.00 0.562 13:20 Change choke to 56~64 5-Mar 13:30 330.0 56.0 760.0 56 Adj, 5.0 1798.72 2283.06 501.20 121.01 773.83 1296.00 0.568 5-Mar 14:00 330.0 58.0 760.0 56 Adj. 5.0 1842.22 2087.92 503.51 111.00 800.02 1257.00 0.602 Switch to Tank #4. I.S, = 7" 5-Mar 14:30 330.0 60.0 800.0 56Adj, 16,0 1883.50 1981,58 511.45 380.78 825.27 1212.00 0.612 5-Mar 15:00 330.0 62.0 810.0 56Adj. 5.0 1930.41 2251.51 513.95 120.00 850.85 1228.00 0.545 15:05 Change choke to 64/64 5-Mar 15:30 300.0 61.0 825.0 64 Adj, 5.0 2012.84 3956.49 518.32 210.00 877.83 1295.00 0.327 5-Mar 16:00 300.0 61.0 850.0 64 Adj. 5.0 2030,03 825.40 519.24 43.99 903.48 1231,00 t.491 5-Mar 16:30 300.0 61.0 860.0 64 Adj. 5.0 2067.70 1808.05 521.24 96,00 929.60 1254.00 0.694 Switch to Tank #3. I.S. '- 11" 5-Mar 17:O0 300.0 60,0 880.0 64 Adj. 5.0 2120.86 2551.86 524.07 136.01 955.50 1243.00 0.487 5-Mar 17:30 300.0 60.0 900.0 64Adj, 5.0 2167.58 2242.65 526.55 118.99 980.29 1190.00 0.531 5-Mar 18:00 300.0 60.0 900.0 64 Adj. 5.0 2203.56 1726.88 528.47 91.99 1005.87 1228.00 0.711 5-Mar 18:30 300.0 60.0 900.0 64 Adj. 5.0 2256.12 2522.69 531.26 133.99 1031.71 1240.00 0.492 5-Mar 19:00 300.0 62.0 900.0 64 Adj. 5.0 2304.32 2313.75 533.84 124.01 1057.46 1236.00 0.534 5-Mar 19:30 300.0 62.0 900.0 64 Adj. 5.0 2343.90 1900.05 535.95 100.99 1082.68 1211.00 0.637 19:32 Change choke to 72/64. Switch to Tank #4. I.S. = 7". Page 2.6 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Alpine #1B Stage: Post Frac Flow Company Rep: 'rrm Scarbrough Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Wellhead Data II 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 Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 5-Mar 20:00 300.0 62.0 900.0 72 Adj. 5.0 2394.23 2415.47 538.63 129.00 1108.62 1245.00 0.515 5-Mar 20:30 300.0 60.0 910.0 72 Adj. 5.0 2452.62 2803.11 541.74 148.99 1135.43 1287.00 0.459 5-Mar 21:00 300.0 60.0 910.0 72 Adj. 5.0 2490.85 1834.86 543.78 97.99 1161.37 1245.00 0.679 5-Mar 21:30 290.0 60.0 940.0 72 Adj. 5.0 2529.25 1842.55 545.82 97.97 1187.75 1266.00 0.687 5-Mar 22:00 290.0 60.0 950.0 72 Adj. 5.0 2574.89 2190.77 548.26 117.00 1211.86 1157.00 0.528 5-Mar 22:30 290.0 60.0 950.0 72 Adj. 5.0 2621.53 2238.69 550.74 118.99 1235.00 1111.00 0.496 Switch to Tank #3. I,S. = 1' 6,5" 5-Mar 23:00 290.0 60.0 950.0 72 Adj. 5.0 2667.56 2209.64 553.20 118.01 1262.63 1326.00 0.600 5-Mar 23:30 290.0 60.0 950.0 72 Adj. 50 2717.73 2408.02 555.86 127.99 1288.69 1251.00 0.520 23:35 Change choke to 80/64, drop back pressure to 150 # 6-Mar 00:00 290.0 60.0 950.0 80 Adj. 2.0 2763.34 2189.20 556.81 45.31 1319.84 1495.00 0.683 6-Mar 00:30 275.0 60.0 960.0 80 Adj. 2.0 2807.41 2115.62 557.72 43.60 1347.34 1320.00 0.624 _ 6-Mar 01:O0 270.0 60.0 960.0 80 Adj. 2.0 2854.95 2281.73 558.70 47.20 1377.11 1429.00 0.626 Switch to Tank #4. I.S. = 2' 2.5", 6-Mar 01:30 265.0 60,0 960.0 80 Adj. 2.0 2898,98 2113.38 559.61 43.60 1405.29 1353.00 0.640 6-Mar 02:00 265.0 60.0 990.0 80 Adj. 2.0 2948.02 2353.98 560.62 48.80 1435.54 1452.00 0.617 6-Mar 02:30 265.0 61.0 990.0 80 Adj. 2.0 2995.26 2267,52 561,60 46.80 1461.92 1266.00 0.558 6-Mar 03:00 265.0 61.0 995.0 80 Adj. 2.0 3036.65 1986.65 562.46 41.20 1489.44 1321.00 0.665 Switch to Tank #3. I.S. = 7.5" 6-Mar 03:30 270.0 64.0 1000.0 80 Adj. 2.0 3077.83 1976.81 563.31 40.80 1517.77 1360.00 0.688 6-Mar 04:00 265.0 63.0 1000,0 80Adj. 2.5 3135.42 2764.48 564.81 72.00 1544.79 1297.00 0.469 6-Mar 04:30 265.0 63.0 1000.0 80Adj. 2.0 3183.47 2306.12 565.80 47.60 1572.81 134500 0.583 Page 2.7 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Alpine #lB Stage: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Date/Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumin. Rate Cumin. 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) 6-Mar 05:00 260.0 63.0 1000.0 80 Adj. 2.0 3223.24 1909.35 566.62 39.60 1600.88 1347.00 0.705 6--Mar 05:30 260.0 63.0 1000.0 8OAdj. 2.0 3277.73 2615.44 567.75 54.00 1629.40 1369.00 0.523 6-Mar 05:00 260.0 63.0 1000.0 80Adj. 2.0 3327.13 2371.02 568.77 49.20 1656.98 1324.00 0.558 6-Mar 06:30 260.0 64.0 1000.0 80 Adj. 2.0 3370.31 2072.82 569.67 42.80 1684.59 1325.00 0.639 Switch to Tank #4. I.S. = 10" 6-Mar 07:00 250.0 64.0 1000.0 80 Adj. 2.0 3376.74 308.58 569.80 6.40 1713.34 1380.00 4.472 6-Mar 07:30 250.0 65.0 1000.0 80Adj. 2.0 3423.96 2266.71 570.77 46.80 1742.88 1418.00 0.626 6--Mar 08:00 250.0 65.0 1000.0 80Adj. 2.0 3472.16 2313.19 571.77 48.00 1772.75 1434.00 0.620 :/~o-Mar 250.0 65.0 10OO.0 80 Adj. 2.0i 3565.77 ~,'246.62 573.71 46.40 1831.92 1420.00 0.632 Start taking 1 hour readings. Switch to Tank #2. I.S. = 7.5". 6-Mar 10:00 250.0 66.0 1000.0 80 Adj. 2.0 3663.71 2350.63 575.74 48.80 1891.09 1420.00 0.604 6-Mar 11:00 250.0 65.0 1000.0 80Adj. 2.0 3757.72 2256.38 577.68 46.60 1949.29 1397.00 0.619 11:30 Bleed down casing to 75~ -- 6-Mar 12:00 250.0 64.0 75.0 80 Adj. 2.0 3845.28 2101.37 579.49 43.40 2011.09 1483.00 0.706 Switch to Tank #3. I.S. = 1' 5". 6-Mar 13:00 250.0 63.0 75.0 80 Adj. 1.0 3944.22 2374.61 580.51 24.40 2071.17 1442.00 0.607 Drop back pressure to 130~ 6-Mar 14:00 250.0 63.0 75.0 80 Adj. 1.5 4037.09 2228.88 581.94 34.35 2130.21 1417.00 0.636 6-Mar 15:00 250.0 63.0 75.0 80 Adj. 1.5 4128.68 2198.09 583.36 34.05 2192.75 1501.00 0.683 Switch to Tank #4. I.S. = 6". 6-Mar 16:00 250.0 63.0 75.0 80 Adj. 1.5 4229.14 2410.95 584.91 37.35 2251.75 1416.00 0.587 6-Mar 17:00 250.0 63.0 78.0 80Adj. 1.5 4321.60 2219.07 586.34 34.20 2311.42 1432.00 0.645 6-Mar 18:00 250.0 63.0 78.0 80 Adj. 1.5 4413.58 2207.62 587.76 34.20 2369.71 1399.00 0.634 Switch to Tank #3. I.S. = 2' 7". 6-Mar 19:00 250.0 63.0 85.0 80Adj. 1.5 4519.43 2540.26 589.40 39.15 2425.63 1342.00 0.528 Page 2.8 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Alpine #lB Stage: Post Frac Flow Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Wellhead Data ]] Cumulative Volumes and Rates II , Date/Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumin. 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) 6-Mar 20:00 250.0 63.0 100.0 80 Adj. 1.5 4606.17 2081.90 590.74 32.25 2479.34 1289.00 0.619 Switch to Tank #4. I.S, = 1' 4,25". 6-Mar 21:00 250.0 63.0 100.0 80Adj. 1.5 4700.67 2267.89 592.20 34.95 2533.59 1302.00 0.574 6-Mar 22:00 250.0 63.0 100.0 80Adj. 1.5 4782.17 1955.95 593.46 30.30 2588,71 1323.00 0,676 Switch to Tank #3. I.S. = 7.5" 6-Mar 23:00 250.0 63.0 110.0 80 Adj. 1.5 4882.34 2404.08 595.00 37.05 2645.25 1357,00 0.564 7-Mar 00:00 250.0 63.0 110.0 80 Adj. 0.5 4978.52 2308.44 595.49 11.80 2701.79 1357.00 0.588 7-Mar 01:00 250.0 63.0 120.0 80 Adj. 0.5 5060.86 1976.15 595.91 10.05 2759.04 1374.00 0.695 Switch toTank #4. I.S. = 10' 5" 7oMar 02:00 250.0 63.0 120.0 80 Adj. 0.5 5154.60 2249,75 596.39 11.50 2815.17 1347.00 0,599 Switch toTank #2. I.S. = 1' 1.75" 7-Mar 03:00 250.0 63.0 120.0 80 Adj. 0.5 5254.56 2398.99 596.90 12.20 2873.84 1408.00 0.587 7-Mar 04:00 250.0 65.0 120.0 80 Adj. 0.5 5344.99 2170.24 597.36 11.10 2932.71 1413.00 0.651 7-Mar 05:00 265.0 65.0 120.0 80 Adj. 0.5 5433.85 2132.78 597.81 10.85 2988.00 1327.00 0.622 Switch toTank #3. I.S. = 1' 4.25" -- 7-Mar 06:00 265.0 65.0 135.0 80 Adj. 1.0 5530.31 2315.04 598.81 23.80 3045.25 1374.00 0.594 7-Mar 07:00 260.0 65.0 150.0 80Adj. 1.0 5613.84 2004.72 599.66 20.50 3102.63 1377.00 0.687 7-Mar 08:00 260.0 65.0 180.0 80Adj. 1.0 5700.57 2081.60 600.55 21.40 3164.17 1477.00 0.710 Switch to Tank #4. I.S. = 1' 10.25" 7-Mar 09:00 250.0 65.0 180.0 80Adj. 1.0 5805.30 2513.29 601.62 25.70 3228.17 1536.00 0.611 7-Mar 10:00 255.0 65.0 180.0 80 Adj. 1.3 5895.04 2153.89 602.78 27.75 3291.88 1529.00 0.710 Switch to Tank #3. I.S, = 2'. 7-Mar 11:00 240.0 65.0 180.0 80 Adj. 1.3 5990.96 2302.11 604.01 29.50 3356.46 1550.00 0.673 7-Mar 12:00 245.0 65.0 180.0 80Adj. 1.3 6084,75 2250.99 605.22 29.00 3422.25 1579.00 0.701 7-Mar 13:00 245.0 65.0 180.0 80Adj. 1.0 6171.95 2092.73 606.11 21.40 3483.92 1480.00 0.707 Switch to Tank #4. I.S. = 1'. Page 2.9 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Alpine #1B Stage: Post Frac Flow Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Wellhead Data II 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 Cumm. Rate GOR Comments (dd-mmm hh:mrn) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 7-Mar 14:O0 245.0 65.0 180.0 80 Adj. 1.0 6259.49 2100.98 607.01 21.60 3546.59 1504.00 0.716 7-Mar 15:00 245.0 65.0 180.0 80 Adj. 1.0 6352.39 2229.55 607.96 22.80 3607.59 1464.00 0.657 7-Mar 16:00 245.0 65.0 180.0 80 Adj. 1.0 6443.58 2188.52 608.90 22.50 3669.21 1479.00 0.676 Switch to Tank #3, I.S. = 9". 7-Mar 17:00 245.0 65.0 180.0 80 Adj. 1.0 6537.30 2249.26 609.85 23.00 3732.00 1507.00 0,670 17:20 Stop injecting emulsion breaker 7-Mar 18:00 245.0 65.0 190.0 80 Adj. 1.0 6627.68 2169.14 610.78 22.30 3793.04 1465.00 0.675 7-Mar 19:00 245.0 65.0 190.0 80 Adj. 1.0 6716.51 2131.92 611.69 21.80 3853.50 1451.00 0.681 Switch to Tank #4. I.S. = 7". 7-Mar 20:00 240,0 64.0 220.0 80 Adj. 1,0 6810.99 2267.64 612.66 23.30 3913.59 1442.00 0.636 7-Mar 21:00 245.0 64.0 230.0 80Adj. 1.0 6899.44 2122.81 613.57 21.70 3974.54 1463.00 0.689 7-Mar 22:00 240.0 64.0 250.0 80 Adj. 1.0 6992.30 2228.64 614.52 22.90 4036.25 1481.00 0.665 22:25- ElL RIH. Switch to Tank #2. I.S. = 6.5" 7-Mar 23:00 240.0 65.0 240.0 80 Adj. 1.0 7088.09 2298.89 615.50 23.50 4095.46 1421.00 0.618 23:40- ElL OOH -- 8-Mar 00:00 240.0 70.0 250.0 80 Adj. 1.0 7178.92 2180.06 616.43 22.40 4158.29 1508.00 0.692 8-Mar 01:00 240.0 71.O 250.0 80 Adj. 1.0 7262.10 1996.27 617.30 20.80 4220.42 1491.00 0.747 Switch to Tank #4. I.S. = 5' 5". 8-Mar 02:00 240.0 71.0 250.0 80 Adj. 1.0 7361.85 2394.00 618.33 24.60 4279,63 1421.00 0.594 8-Mar 03:00 240.0 71.0 250.0 80 Adj. 1.0 7451.53 2152.16 619.24 22.00 4338.84 1421.00 0.660 03:25- E/L RIH. Switch to Tank #3. I.S. = 6". 8-Mar 04:00 240.0 71.0 250.0 80 Adj. 1.0 7547.23 2296.84 620.23 23.60 4398.54 1433,00 0.624 8-Mar 05:00 240.0 70.0 250.0 80 Adj. 1.0 7635.68 2122.81 621.13 21.70 4457.67 1419.00 0.668 8-Mar 06:00 235.0 69.0 260.0 80 Adj. 1.0 7719.98 2023.24 622.00 20.80 4513.84 1348.00 0.666 Switch to Tank #4. I.S, = 1' 0.5". 8-Mar 07:00 240.0 70.0 260.0 80Adj. 1.0 7813.73 2250,06 622.95 23.00 4574.79 1463.00 0.650 Page 2,10 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Alpine #lB Stage: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 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-rnmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 8-Mar 08:00 240.0 70.0 260.0 80 Adj. 1.0 7901.27 2100.98 623.85 21.60 4634.92 1443.00 0.687 8-Mar 09:00 240.0 70.0 250.0 80Adj. 1.1~-~ 7988.47 2092.73 624.75 21.40 4695.50 1454.00 0.695 Switch to Tank #3. I.S. = 11.5". ..~ 8-Mar 09:11 240.0 70.0 250.0 80 Adj. 1.0 801-1.2-8 2986.69 624.98 30.54 4706.61 1454.00 0.487 Shut In Well Downhole. 8-Mar 09:15 ~ Shut In Well at Choke Manifold. . Page 2.11 Final_Reports/Results Summary Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1,5OC~ X 200" WC H.E.S. Rep: Steve Tyburski 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 CHLORI[ (hh:mm) (psig) (64tbs) (%) (bbls) (bbls) ({~i)60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 3-Mar 14:26 450.0 100.0 60.0 0.00 3-Mar 14:30 3(X).0 100.0 0.74 0.00 600 O00 0.00 0.74 266.67 0.00 3-Mar 15:00 260.0 100.0 5.56 0.00 60.0 0.00 0.00 5.56 266.67 0.00 3-Mar 15:30 240.0 100.0 8.70 0.00 60.0 0.00 0.00 8.70 417.78 0.00 3-Mar 16:00 200.0 100.0 12.50 0.00 60.0 0.00 0.00 12.50 600.00 0.00 3-Mar 16:30 150.0 100.0 7.50 000 60.0 0.00 0.00 7.50 360.00 0.00 3-Mar 17:00 200 1000 5.00 000 60.0 0.00 0.00 5.00 240.00 0.00 6,000 3-Mar 17:30 200 100.0 5.00 0.00 60.0 0.00 0.00 5.00 240.00 0.00 3-Mar 18:00 25.0 100.0 5.00 000 60.0 0.00 0.00 5.00 240.00 0.00 3-Mar 18:30 25.0 100.0 5.00 0.00 60.0 0.00 0.00 5.00 240.00 0.00 3-Mar 19:00 35.0 100.0 10.00 0.00 60.0 0.00 0.00 10.00 48000 0.00 19,000 3-Mar 19:30 35.0 100.0 10.00 0.00 60.0 0.00 0.00 10.00 480.00 0.00 3-Mar 20:00 35.0 100.0 12.50 0.00 60.0 0.00 0.00 12.50 600.00 0.00 3-Mar 20:30 85.0 100.0 17.50 0.00 60.0 0.00 0.00 17.50 840.00 0.00 3-Mar 21:00 175.0 100.0 17.50 0.00 60.0 0.00 0.00 17.50 840.00 0.00 30,000 3-Mar 21:30 180.0 100.0 13.61 0.00 60.0 0.00 0.00 13.61 653.33 0.00 31,000 3-Mar 22:00 247.0 100.0 6,67 0.00 60.0 0.00 0.00 6.67 320.00 0.00 26,000 3-Mar 22:30 245.0 100.0 7.94 0.00 60.0 0.00 0.00 7.94 380.95 0.00 25,000 , , Page 3.1 Final_Reports / Separator Reading Customer: ARCO Alaska, INC. Well: Alpine #18 Test Number: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S, Rep: Steve Tyburski 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 CHLORIE (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) 3-Mar 23:00 245.0 100.0 9.29 0.00 60.0 0.00 0.00 9.29 445.78 0.00 23,000 3-Mar 23:30 245.0 100.0 10.56 0.00 60.0 0.00 0.00 10.56 506.67 0.00 23,000 4-Mar 00:00 245.0 100.0 10.87 0.00 60.0 0.00 0.00 10.87 521.90 0.00 24,000 4-Mar 00:30 250.0 100.0 10.98 0.00 60.0 0.00 0.00 10.98 526.98 0.00 23,500 4-Mar 01:00 250.0 100.0 10.81 0.00 60.0 0.00 0,00 10.81 518.73 0.00 23,500 4-Mar 01:30 250.0 100.0 14.29 0.00 60.0 0.00 0.00 14.29 685.71 0.00 27,500 4-Mar 02:00 250.0 100.0 15.00 0.00 60.0 0.00 0.00 15.00 720.00 0.00 27,500 4-Mar 02:30 250.0 100.0 10.83 0.00 60.0 0.00 0.00 10.83 520.00 0.00 27,500 4-Mar 03:00 250.0 65.0 15.14 5.30 60.0 5.30 254,43 9.84 472.52 0.00 27,500 4-Mar 03:30 250.0 40.0 11.52 6.91 60.0 6.91 331.83 4.61 221.22 0.00 26,5r 4-Mar 04:00 2~.0 40.0 12.50 7.50 60.0 7.50 360.00 5.00 240.00 0.00 25,000 4-Mar 04:30 250.0 40.0 11.76 7.06 60.0 7.06 338.67 4.70 225.78 0.00 29,000 4-Mar 05:00 300.0 50.0 12.24 6_12 60.0 6.12 293.78 6.12 293.78 0.00 27,500 4-Mar 05:30 300.0 30.0 15.00 10.50 60.0 10.50 504.00 4.50 216.00 0.00 27,500 4-Mar 06:00 300.0 25.0 13.50 10.13 60.0 10.13 48600 3.38 162.00 0.00 27,500 4-Mar 06:30 300.0 20.0 15,00 12.00 60.0 12.00 576.00 3.00 144.00 0.00 27,500 4-Mar 07:00 400.0 17.0 20.00 16.60 60.0 16.60 796.80 3.40 163.20 0.00 25,000 4-Mar 07'30 450.0 22.0 16.00 12.48 60.0 12.48 599.04 3.52 16896 0.00 24,000 Page 3.2 Final_Reports / Separator Reading Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Date/Time ~ Wellhead Data II Separator Readings Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-rmmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORI[ (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) 4-Mar 08:00 450.0 22.0 16.80 13.10 60.0 1310 628.99 3.70 177.41 0.00 24,000 4-Mar 08:30 450.0 16.0 16.20 13.61 60.0 13.61 653.19 2.59 124.42 0.00 29,000 4-Mar 09:00 450.0 17.0 20.80 17.26 60.0 17.26 828.68 3.54 169.73 0.00 25,000 4-Mar 09:30 360.0 30.0 25.00 17.50 60.0 17.50 840.00 7.50 360.00 0.00 26,000 4-Mar 10:00 370.0 30.0 21.50 15.05 60.0 15.05 722.40 6.45 309.60 0.00 25,000 4-Mar 10:30 225.0 25.0 32.00 24.00 60.0 24.00 1152.00 8.00 384.00 0.00 25,000 4-Mar 11:00 220.0 36.0 52.10 33.34 60.0 33.34 1600.52 18.76 900.29 0.00 26,000 4-Mar 11:30 220.0 22.0 21.10 16.46 60.0 16.46 789.99 4.64 222.82 0.00 26,000 4-Mar 12:00 450.0 22.0 7.53 5.88 60.0 5.88 282.05 1.66 79.55 0.00 28,000 4-Mar 12:30 475.0 22.0 20.77 16.20 60.0 16.20 777.51 4.57 219.30 0.00 29,0f' 4-Mar 13:00 450.0 22.0 15.00 11.70 60.0 11.70 561.60 3.30 158.40 0.00 27,000 4-Mar 13:30 400.0 17.0 34.60 28.72 60.0 28.72 1378.47 5.88 282.34 0.00 25,000 4-Mar 14:00 500.0 22.0 56.00 43.68 60.0 43.68 2096.65 12.32 591.36 0.00 26,000 4-Mar 14:30 650.0 20 Adj. 11.0 3.75 3.34 60.0 3.34 160.20 0.41 19.80 0.00 26,000 4-Mar 15:00 650.0 20 Adj. 18.0 10.83 8.88 60.0 8.88 426.27 1.95 93.57 0.00 27,000 4-Mar 15:30 640.0 28 Adj. 14.0 1.25 1.08 0.772 0.772 150.0 100.0 60.0 60.0 1.08 51.60 0.18 8.40 8.12 390.00 7.558 27,000 4-Mar 16:00 450.0 40Adj. 40.0 21.25 12.75 0.772 0.772 1250 60.0 60.0 60.0 12.75 61200 8.50 408.00 14.21 68200 1.114 27,000 4~Mar 16:30 440.0 54 Adj. 22.0 35.00 27.30 0.772 0.772 100.0 62.0 62.0 68.0 27.22 1306.73 7.70 369.60 12.92 620.00 0. z174 29,000 Page 3.3 Final_Reports / Separator Reading Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Steve Tyburski 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 CHLORIE (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (~L~oOF) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 4-Mar 17:00 490.0 28 Adj. 22.0 31.67 24.70 39.30 0.772 0.772 100.0 60.0 68.0 73.0 24.54 1178.02 6.97 334.44 11.42 548.00 0.465 27,000 4-Mar 17:30 480.0 38Adj. 14.0 27.08 23.29 0.772 0.772 95.0 55.0 72.0 76.0 23.16 1111.61 3.79 181.98 9.10 437.00 0.393 25,000 4-Mar 18:00 445.0 38 Adj. 15.0 34.58 29.39 0.772 0.772 100.0 60.0 76.0 76.0 29.23 1402.97 5.19 248.98 8.94 429.00 0.306 28,000 4-Mar 18:30 450.0 38 Adj. 11.0 30.42 27.07 0.775 0.775 120.0 28.0 76.0 76.0 26.92 1292.27 3.35 160.62 6.69 321.00 0.248 27,000 4-Mar 19:00 500.0 38 Adj. 12.0 27.50 24.20 39.50 0.775 0.775 120.0 24.0 78.0 80.0 23.96 1149.99 3.30 158.40 6.17 296.00 0.257 28,000 4-Mar 19:30 510.0 38 Adj. 13.0 27.92 24.29 0.775 0.775 125.0 38.0 78.0 80.0 24.12 1157.78 3.63 174.22 7.94 381.00 0.329 28,000 4-Mar 20:00 520.0 38 Adj. 14.0 21.67 18.64 39.30 0.775 0.775 130.0 38.0 77.0 82.0 18.43 884.70 3.03 145.62 8.10 389.00 0.440 25,000 4-Mar 20:30 525.0 38 Adj. 15.0 31.25 26.56 0.775 0.775 120.0 122.0 80.0 82.0 26.36 1265.19 4.69 225.00 13.96 670.00 0.530 27,500 4-Mar 21:00 525.0 38 Adj. 15.0 33.75 28.69 0.775 0.775 120.0 120.0 80.0 81.0 28.48 1366.88 5.06 243.00 12.62 606.00 0.443 27,500 4-Mar 21:30 5,,-,-,-,-,-,-,-,-,~).0 38Adj. 5.0 17.92 17.02 0.775 0.775 120.0 122.0 80.0 80.0 16.90 811.43 0.90 43.01 13.98 671.00 0.827 29,0(' 4-Mar 22:00 510.0 38 Adj. 5.0 26.67 25.34 0.773 0.773 120.0 122.0 77.0 80.0 25.16 1207.64 1.33 64.01 14.04 674.00 0.558 27,500 4-Mar 22:30 500.0 34 Adj. 5.0 41.67 39.59 0.773 0.773 160.0 110.0 75.0 82.0 39.28 1885.53 2.08 100.01 15.44 741.00 0.393 28,500 4-Mar 23:00 500.0 34Adj. 5.0 35.42 33.65 0.773 0.773 180.0 112.0 75.0 82.0 33.39 1602.72 1.77 85.01 15.96 766.00 0.478 27,500 4-Mar 23:30 510.0 34Adj. 5.0 24.58 23.35 0.775 0.775 180.0 110.0 82.0 83.0 23.16 1111.83 1.23 58.99 16.29 782.00 0.703 27,500 5-Mar 00:00 510.0 37Adj. 5.0 26.67 25.34 0.775 0.775 170.0 152.0 83.0 83.0 25.13 1206.37 1.33 64.01 18.60 893.00 0.740 28,500 5-Mar 00:30 500.0 37Adj. 5.0 44.17 41.96 0.775 0.775 160.0 56.0 82.0 83.0 41.62 1997.94 2.21 106.01 17.15 823.00 0.412 30,000 5-Mar 01:00 4.90.0 37Adj. 5.0 34.17 32.46 39.10 0.771 0.771 160.0 58.0 82.0 82.0 32.10 1541.02 1.71 82.01 17.48 839.00 0.544 27,500 5-Mar 01:30 490.0 37Adj. 5.0 33.75 32.06 0.771 0.771 160.0 60.0 80.0 81.0 31.83 1527.69 1.69 81.00 17.81 855.00 0.560 Page 3.4 Final_Reports / Separator Reading Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 150C)~ X 200" WC H.E.S. Rep: Steve Tyburski 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 i TEMP Inc. Rate Inc. Rate Inc, Rate GOR CHLORID (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (~:~3F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 5-Mar 02:00 490.0 39 Adj. 10.0 28.33 25.50 40.00 0,771 0.771 160.0 68.0 79.0 81.0 25.23 1211.01 2.83 135.98 19.00 912.00 0.753 5-Mar 02:30 475.0 39 Adj. 5.0 44.17 41.96 0.771 0.771 180.0 56.0 79.0 80.0 41.67 2000,06 2.21 106.01 18.31 879,00 0.439 5-Mar 03:00 470.0 39 Adj. 8.0 35.83 32.96 38.20 0.771 0.771 170.0 56.0 80.0 81.0 32.62 1565.64 2.87 137.59 17.77 853.00 0.545 27,500 5-Mar 03:30 475.0 39 Adj. 5.0 29.58 28.10 0.771 0,771 180.0 60.0 80.0 81.0 27.89 1338.94 1.48 70.99 18.94 909.00 0.679 5-Mar 04:00 475.0 39 Adj. 5.0 32.08 30.48 39.10 0.771 0.771 170.0 64.0 79.0 81.0 30.16 1447.49 1.60 76.99 19.00 912.00 0.630 27,500 5-Mar 04:30 475.0 39 Adj. 5.0 47.92 45.52 0.773 0.773 170.0 58.0 82.0 80.0 45,21 2169.86 2.40 115.01 18.02 865.00 0.399 5-Mar 05:00 450.0 39 Adj. 5.0 34.58 32.85 38.20 0.773 0.773 175.0 56.0 81.0 81.0 32.51 1560,30 1.73 82.99 18.00 864.00 0.554 27,500 5-Mar 05:30 475.0 39 Adj. 5.0 34.58 32.85 0.758 0.758 175.0 56.0 83.0 84.0 32.58 1563.61 1.73 82.99 18.12 870.00 0.556 5-Mar 06:00 475.0 39 Adj. 5.0 44.58 42.35 38.50 0.758 0.758 175.0 60.0 81.0 83.0 41.86 2009.48 2.23 106.99 18.79 902.00 0.449 27,500 5-Mar 06:30 475.0 39 Adj. 5.0 34.58 32.85 0.758 0.758 165.0 64.0 79.0 85.0 32.56 1563.05 1.73 82.99 18.87 906.00 0.580 5-Mar 07:00 410.0 43Adj. 5.0 40.83 38.79 39.00 0.758 0.758 170.0 88.0 80.0 82.0 38.36 1841.37 2.04 97.99 22.48 1079.00 0,586 28,500 5-Mar 07:30 405.0 43Adj. 5.0 44.17 41.96 0.753 0.753 175.0 80.0 82.0 83.0 41.62 1997.95 2.21 106.01 21.77 1045.00 0.523 5-Mar 08:00 400.0 43Adj. 6.0 37.50 35.25 39.30 0.753 0.753 170.0 84,0 82.0 83.0 34.84 1672,31 2.25 107.99 21.98 1055.00 0.631 27,000 5-Mar 08:30 405.0 43Adj. 6.0 38.33 36.03 0.753 0.753 175.0 90.0 82.0 84.0 35.73 1715.17 2.30 110.41 23.08 1108.00 0.646 5-Mar 09:00 405.0 43Adj. 6.0 42.50 39.95 238.80 0.753 0.753 165.0 92.0 82.0 83.0 39.12 1877.91 2.55 122.40 22.65 1087.00 0.579 27,000 5-Mar 09:30 410.0 43 Adj. 6.0 45.83 43.08 0.753 0.753 160.0 94.0 82.0 84.0 42.72 2050.49 2.75 131.99 22.73 1091.00 0.532 5-Mar 10:00 415.0 43Adj. 6.0 40.42 37.99 39.10 0.753 0.753 160.0 96.0 82.0 84.0 37.54 1801.87 2.43 116.41 22.77 1093.00 0.607 27,000 5-Mar 10:30 4150 43Adj. 6.0 43.33 40.73 0.755 0.755 160.0 980 83.0 830 40.40 ~1939.32 2.60 124.79 22.92 110000 0,567 Page 3.5 Final_Reports / Separator Reading Customer: ARCO Alaska, INC. Well: AJpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Date/Time ~ Wellhead Data It Separator Readings Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (~mm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIC (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (~c~0F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 5-Mar 11:00 415.0 43Adj. 5.0 44.17 41.96 40.00 0.755 0.755 160.0 102.0 83.0 83.0 41.48 1990,99 2,21 10601 23.42 1124.00 0.565 27,000 5-Mar 11:30 415.0 48Adj. 5.0 33.33 31.66 0.755 0.755 160.0 46.0 83.0 83.0 31.41 1507,62 1.67 79.99 23.29 1118.00 0,742 5-Mar 12:00 390.0 48 Adj. 5.0 49.58 47.10 39.40 0.755 0.755 160.0 108.0 84.0 84.0 46.54 2233.72 2.48 118.99 24.08 1156.00 0.518 27,000 5-Mar 12:30 390.0 48 Adj. 8.0 42.50 39.10 0.755 0.755 175.0 96.0 68.0 68.0 38.99 1871.55 3.40 163.20 20.31 975.00 0.521 5-Mar 13:00 370.0 48 Adj. 6.0 45.00 42.30 39.70 0.755 0.755 180.0 90.0 75.0 75.0 41.98 2015.18 2,70 129.60 23.58 1132.00 0.562 28,000 5-Mar 13:30 330.0 56 Adj. 5.0 50.42 47.90 0.755 0.755 180.0 119.0 80.0 80.0 47,56 2283,06 2.52 121.01 27.00 1296,00 0.568 5-Mar 14:00 330.0 56Adj. 5.0 46.25 43.94 39.10 0.755 0.755 180.0 112.0 80.0 80.0 43.50 2087.92 2.31 111.00 26.19 1257.00 0.602 28,000 5-Mar 14:30 330.0 56Adj. 16.0 49.58 41.65 0.755 0.755 185.0 102.0 83.0 85.0 41.28 1981.58 7.93 380.78 25.25 1212.00 0.612 5-Mar 15:00 330.0 56 Adj. 5.0 50.00 47.50 39.80 0.755 0.755 180.0 107.0 80.0 85.0 46.91 2251.51 2.50 120.00 25.58 1228.00 0.545 27,000 5-Mar 15:30 300.0 64 Adj. 5.0 87.50 83.13 0.755 0.755 175.0 122.0 79.0 84.0 82.43 3956.49 4.38 210.00 26.98 1295.00 0.327 5-Mar 16:00 300.0 64 Adj. 5.0 18.33 17.41 38.80 0.759 0.759 180.0 108.0 80.0 85.0 17.20 825.40 0.92 43.99 25.65 1231.00 1.491 28,000 5-Mar 16:30 300.0 64Adj. 5.0 40.00 38.00 0.759 0.759 180.0 112.0 80.0 85.0 37.67 1808.05 2.00 96.00 26.12 1254.00 0.694 5-Mar 17:00 300.0 64Adj. 5.0 56.67 53.84 39.50 0.759 0.759 185.0 107.0 80.0 85.0 53.16 2551,86 2.83 136.01 25.90 1243.00 0.487 28,000 5--Mar 17:30 300.0 64Adj. 5.0 49.58 47.10 0.759 0.759 190.0 96.0 82.0 83.0 46.72 2242.65 2.48 118.99 24.79 1190.00 0.531 5-Mar 18:00 300.0 64 Adj. 5.0 38.33 36.41 39.70 0.759 0.759 190.0 103.0 86.0 84.0 35.98 1726.88 1.92 91.99 25.58 1228.00 0.711 28,000 5-Mar 18:30 300.0 64 Adj. 5.0 55.83 53.04 0.759 0.759 190.0 104.0 83.0 86.0 52.56 2522.69 2.79 133.99 25.83 1240.00 0.492 5-Mar 19:00 300.0 64 Adj. 5.0 51.67 49.09 39.20 0.759 0.759 190.0 100.0 84.0 96.0 48.20 2313.75 2.58 124.01 25.75 1236.00 0.534 27,000 5-Mar 19:30 300.0 64Adj. 5.0 42.08 39.98 0.759 0.759 190.0 104.0 85.0 88.0 39.58 1900,05 2.10 100.99 25.23 1211,00 0.637 Page 3.6 Final_Reports/Separator Reading Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Steve Tyburski 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 CHLORIE (hh:mm) (psig) (64ths) (%) (bbls) (bbls) ({~::~OF) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 5-Mar 20:00 300.0 72Adj. 5.0 53.75 51.06 41.70 0.759 0.759 180.0 112.0 86.0 89.0 50.32 2415.47 2.69 129.00 25.94 1245.00 0.515 28,000 5-Mar 20:30 300.0 72 Adj. 5.0 62.08 58.98 0.759 0.759 180.0 120.0 88.0 88.0 58.40 2803.11 3.10 148.99 26.81 1287001 0.459 5-Mar 21:00 300.0 72Adj. 5.0 40.83 38.79 40.20 0.759 0.759 180.0 112.0 86.0 89.0 38.23 1834.86 2.04 97.99 25.94 1245.00' 0.679 27,500 5-Mar 21:30 290.0 72 Adj. 5.0 40.83 38.79 0.759 0.759 180.0 116.0 87.0 89.0 38.39 1842.55 2.04 97.97 26,38 1266.00 0.687 5-Mar 22:00 290.0 72 Adj. 5.0 48.75 46.31 40.50 0.759 0,759 180.0 96.0 82.0 89.0 45.64 2190.77 2.44 117.00 24.10 i1157.00 0.528 28,000 5-Mar 22:30 290.0 72Adj. 5.0 49.58 47.10 0,759 0,759 190.0 40.0 85.0 88.0 46.64 2238.69 2.48 118.99 23.15 1111.00: 0.496 5-Mar 23:00 290.0 72 Adj. 5.0 49.17 46.71 40.50 0.759 0.759 160.0 68.0 85.0 89.0 46.03 2209,64 2.46 118.01 27.63 1326.00 0.600 28,000 5-Mar 23:30 290.0 72Adj. 5.0 53.33 50.66 0.759 0.759 160.0 60.0 80.0 88.0 50.17 2408.02 2.67 127.99 26.06 1251.00 0.520 6-Mar 00:00 290.0 80 Adj. 2.0 47.20 46.26 40.50 0.759 0.759 180.0 76.0 82.0 88.0 45.61 2189.20 0.94 45.31 31.15 1495.00 0,683 28,000 6-Mar 00:30 275.0 80Adj. 2.0 45.42 44.51 0,759 0.759 150.0 72.0 85.0 88.0 44.08 2115.62 0.91 43.60 27,50 1320.00 0.624 6-Mar 01:00 270.0 80Adj. 2.0 49.17 48.19 40.50 0.759 0.759 150.0 84.0 83.0 87.0 47.54 2281.73 0.98 47.20 29.77 1429.00 0.626 28,000 6-Mar 01:30 265.0 80Adj. 2.0 45.42 44.51 0.798 0.798 150.0 80.0 90.0 91.0 44.03 2113.38 0.91 43.60 28.19 1353.00 0.640 6-Mar 02:00 265.0 80Adj. 2.0 50.83 49.81 40.50 0.798 0.798 150.0 92.0 90.0 91.0 49.04 2353.98 1.02 48.80 30.25 1452.00 0.617 28,000 6-Mar 02:30 265.0 80Adj. 2.0 48.75 47.78 0,798 0,798 120.0 88.0 90.0 92.0 47.24 2267.521 0.98 46.80 26.37 1266.00 0.558 6-Mar 03:00 265.0 80Adj. 2.0 42.92 42.06 39.90 0.798 0.798 125.0 92.0 91.0 92.0 41.39 1986.65 0.86 41.20 27.52 1321.00 0.665 6-Mar 03:30 270.0 80Adj. 2.0 42.50 41.65 0.798 0.798 135,0 90.0 90.0 92.0 41.18 1976.81 0.85 40.80 28.33 1360.00! 0.688 6-Mar 04:00 265.0 80Adj. 2.5 60.00 58.50 39.30 0.801 0.801 135.0 82.0 89.0 91.0 57.59 2764.48 1.50 72.00 27.02 ,1297.00! 0.469 27,500 6-Mar 04:30 265.0 80Adj. 2.0 49.58 48.59 0.801 0.801 130.0 92.0 91.0 92.0 48.04 2306.121 0199 47.60 28.02 1345.00, 0.583 Page 3.7 Final_Reports / Separator Reading Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Steve Tyburski 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 I TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDr (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) 6-Mar 05:00 260.0 80Adj. 2.0 41.25 40.43 39.70 0.801 0,801 125.0 96.0 91.0 92.0 39.78 1909.35 0.83 39.60 28.06 1347.00 0.705 28,000 6-Mar 05:30 260.0 80 Adj. 2.0 56.25 55.13 0.801 0.801 140.0 88.0 89.0 93.0 54.49 2615.44 1.13 54.00 28.52 ;1369.00 0.523 6-Mar 06:00 260.0 80 Adj. 2.0 51.25 50.23 41.00 0.801 0.801 145.0 80.0 92.0 93.0 49.40 2371.02 1.03 49.20 27.58 1324.00 0,558 27,500 6-Mar 06:30 260.0 80Adj. 2.0 44.58 43.69 0.801 0.801 135.0 86.0 91.0 93.0 43.18 2072.82 0.89 42.80 27.60 1325.00 0.639 6-Mar 07:00 250.0 80 Adj. 2.0 6.67 6.54 40.20 0.789 0.789 135.0 91.0 91.0 93.0 6.43 308.58 0.13 6.40 28.75 1380.00 4.472 27,000 6-Mar 07:30 2¢-:-:-:-:-----~).0 80 Adj. 2.0 48.75 47.78 0.789 0.789 135.0 96.0 91.0 93.0 47.22 2266.71 0.98 46.80 29.54 1418.001 0.626 6-Mar 08:00 250.0 80 Adj. 2.0 50.00 49.00 39.50 0.771 0.771 135.0 97.0 91.0 93.0 48.19 2313.19 1.00 48.00 29.88 1434.00 0.620 27,000 6-Mar 09:00 250.0 80 Adj. 2.0 96.67 94.74 0.772 0.772 130.0 99.0 92.0 94.0 93.61 2246.62 1.93 46.40 59.17 1420.00 0.632 27,000 6-Mar 10:00 250.0 80Adj. 2.0 101.67 99.64 39.90 0.772 0.772 130.0 99.0 92.0 94.0 97.94 2350.63 2.03 48.80 59.17 1420.00 0,604 23,000 6-Mar 11:00 250.0 80Adj. 2.0 97.09 95.15 0.772 0.772 130.0 96.0 92.0 94.0 94.02 2256.38 1.94 46.60 58.21 1397.00 0.619 27,00r ' 6-Mar 12:00 250.0 80Adj. 2.0 90.42 88.61 0.772 0.772 135.0 104.0 92.0 94.0 87.56 2101.37 1.81 43.40 61.79 1483.00 0.706 27,000 6-Mar 13:00 250.0 80Adj. 1.0 101.67 100.65 40.10 0.782 0.782 140.0 96.0 92.0 94.0 98.94 2374.61 1.02 24.40 60.08 1442.00 0.607 6-Mar 14:00 250.0 80 Adj. 1.5 95.42 93.99 0.782 0,782 125.0 104.0 92.0 94.0 92.87 2228,88 1.43 34.35 59.04 1417.00 0.636 6-Mar 15:00 250.0 80 Adj. 1.5 94,59 93.17 39.90 0.782 0.782 130,0 112.0 92.0 94.0 91.59 2198.09 1.42 34.05 62.54 1501,00 0,683 6-Mar 16:00 250.0 80 Adj. 1.5 103.75 102.19 40.00 0.782 0.782 110.0 118.0 92.0 94.0 100.46 2410.95 1.56 37.35 59.00 1416,00 0.587 6-Mar 17:00 250.0 80 Adj. 1.5 95.00 93.58 0.782 0.782 130.0 102.0 92.0 94.0 92.46 2219,07 1.43 34.20 59.67 1432.00 0.645 6-Mar 18:00 250.0 80Adj. 1.5 95.00 93.58 39.80 0.788 0.788 125.0 102.0 92.0 94.0 91.98 2207.62 1.43 34.20 58.29 1399.00 0.634 6-Mar 19:00 250.0 80Adj. 1.5 108.75 107.12 0.788 0.788 130.0 90.0 90.0 94.0 t05.84 2540,26 1.63 39.15 55.92 1342.00 0.528 Page 3.8 Final_Reports / Separator Reading Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mrnm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff !Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORI[- (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (~:)OF) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 6-Mar 20:00 250.0 80 Adj. 1.5 89.59 88.25 39.20 0.782 0.782 130.0 83.0 93.0 94.0 86.75 2081.90 1.34 32.25 53.71 128900 0.619 6-Mar 21:00 250.0 80 Adj, 1.5 97.09 95,63 0.782 0.782 125.0 88.0 92.0 94.0 94.50 2267.89 1.46 34.95 54.25 1302.00 0.574 6-Mar 22:00 250.0 80Adj. 1.5 84.17 82.91 39.50 0.788 0.788 150.0 76.0 92.0 94.0 81.50 1955.95 1.26 30.30 55.12 1323.00 0.676 6-Mar 23:00 250.0 80Adj. 1.5 102.92 101.38 0.788 0.788 150.0 80.0 93,0 94.0 100.17 2404.08 1.54 37.05 56,54 1357.00 0.564 7-Mar 00:00 250.0 80 Adj. 0.5 98.34 97.85 39.70 0.787 0.787 150.0 80.0 93.0 94.0 96.18 2308.44 0.49 11.80 56.54 1357.00 0.588 7-Mar 01:00 250.0 80Adj. 0.5 83.75 83.33 0.787 0.787 150.0 82.0 93.0 94.0 82.34 1976.15 0.42 10.05 57.25 1374.00 0.695 7-Mar 02:00 250.0 80 Adj. 0.5 95.84 95.36 39.80 0.787 0.787 140.0 84.0 90.0 94.0 93.74 2249.75 0.48 11.50 56.12 1347.00 0.599 7oMar 03:00 250.0 80 Adj. 0.5 101.67 101.16 0.787 0,787 135.0 96.0 94.0 94.0 99.96 2398.99 0.51 12.20 58.67 1408.00 0.587 7-Mar 04:00 250.0 80Adj. 0.5 92.50 92.04 39.20 0.787 0.787 130.0 100.0 92.0 95.0 90.43 2170.24 0.46 11.10 58.87 1413.00 0.651 7-Mar 05:00 265.0 80Adj. 0.5 90.42 89.97 0.787 0.787 120.0 96.0 93.0 95.0 88.87 2132.78 0.45 10.85 55.29 1327,00 0.622 7-Mar 06:00 265.0 80 Adj. 1.0 99.17 98.18 39.80 0.780 0.780 135.0 90.0 90.0 95.0 96.46 !2315.04 0,99 23.80 57.25 1374.00 0.594 7-Mar 07:00 260.0 80Adj. 1.0 85.42 84.57 0.780 0.780 145.0 84.0 92.0 95.0 83.53 2004.72 0.85 20.50 57.37 1377.00 0.687 7-Mar 08:00 260.0 80 Adj. 1.0 89.17 88,28 39.70 0.776 0.776 140.0 100.0 92.0 95.0 86.73 ~2081.60 0.89 21.40 61.54 1477.00 0.710 7-Mar 09:00 250.0 80Adj. 1.0 107.09 106.02 0.776 0.776 140.0 108.0 92.0 95.0 104.72 2513.29 1.07 25.70 64.00 1536.00 0.611 7oMar 10:00 255.0 80 Adj. 1.3 92.50 91.34 39.50 0.776 0.776 140.0 107.0 92.0 95.0 89.75 2153.89 1.16 27.75 63.71 1529.00 0.710 7oMar 11:00 240.0 80Adj. 1.3 98.34 97.11 0.776 0.776 140.0 114.0 92.0 95.0 95.92 2302.11 1.23 29.50 64.58 1550.00 0.673 7-Mar 12:00 245.0 80 Adj. 1.3 96.67 95.46 39.40 0.776 0.776 140.0 114.0 92.0 95.0 93.79 2250.99 1.21 29.00 65.79 1579.00 0.701 7-Mar 13:00 245.0 80Adj. 1.0 89.17 88.28 0.776 0.776 135.0 104.0 92.0 95.0 87.20 2092,73 0.89 21.40 61.67 1480.00 0,707 Page 3.9 Final_Reports / Separator Reading Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Date/'rime ~ Wellhead Data I Separator 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 CHLORIC (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) 7-Mar 14:00 245.0 80Adj. 1.0 9000 89.10 39.50 0.776 0.776 120.0 121.0 92.0 95.0 87.54 2100.98 0.90 21.60 62.67 1504.00 0.716 7-Mar 15:00 245.0 80Adj. 1.0 95.00 94.05 0.776 0.776 125.0 110.0 92.0 95.0 92.90 2229.55 0.95 22.80 61.00 1464.00 0.657 7-Mar 16:00 245.0 80 Adj. 1.0 93.75 92.81 39.40 0.776 0.776 130.0 108.0 92.0 95.0 91.19 2188.52 0.94 22.50 61.62 ;1479.00 0.676 7-Mar 17:00 245.0 80Adj. 1.0 95.84 94.88 0.776 0.776 130.0 112.0 92.0 95.0 93.72 2249.26 0.96 23.00 62.79 1507.00' 0.670 7-Mar 18:00 245.0 80 Adj. 1.0 92.92 91.99 39.60 0.776 0.776 130.0 106.0 92.0 950 90.38 2169.14 0.93 22.30 61.04 1465.00 0.675 7-Mar 19:00 245.0 80Adj. 1.0 90.84 89.93 0.776 0.776 130.0 1040 92.0 95.0 88.83 2131.92 0.91 21.80 60.46 1451.00 0,681 7-Mar 20:00 240.0 80Adj. 1.0 97.09 96.12 39.90 0.776 0.776 115.0 116.0 91.0 94.0 94.49 2267.64 0.97 23.30 60.08 144200 0.636 7-Mar 21:00 245.0 80Adj. 1.0 90.42 89.52 0.776 0.776 110.0 125.0 92.0 94.0 88.45 2122.81 0.90 21.70 60.96 1463.00 0,689 7-Mar 22:00 240.0 80 Adj. 1.0 95.42 94.47 39.70 0.776 0.776 110.0 128.0 920 94.0 92.86 2228.64 0.95 22.90 61.71 1481.00 0.665 7-Mar 23:00 240.0 80 Adj. 1.0 97.92 96.94 0.792 0.792 110.0 120.0 92.0 94.0 95.79 2298.89 0.98 23.50 59.21 1421.00 0.618 8-Mar 00:00 240.0 80 Adj. 1.0 93.34 92.41 39.30 0.790 0.790 110.0 135.0 92.0 94.0 90.84 2180.06 0.93 22.40 62.83 1508.00 0.692 8-Mar 01:00 240.0 80Adj. 1.0 86.67 85.80 0.790 0.790 110.0 132.0 92.0 94.0 83.18 1996.27 0.87 20.80 62.12 1491100 0.747 8-Mar 02:00 240.0 80 Adj. 1.0 102.50 101.48 39.60 0.790 0.790 100.0 1320 92.0 94.0 99.75 2394.00 1.03 24.60 59.21 1421.00 0.594 8-Mar 03:00 240.0 80Adj. 1.0 91.67 90.75 0.790 0.790 100.0 132.0 92.0 94.0 89.67 2152.16 0.92 22.00 59.21 1421.00 0.660 8-Mar 04:00 240.0 80Adj. 1.0 98.34 97.36 39.40 0.790 0.790 105.0 128.0 93.0 94.0 95.70 2296.84 0.98 23.60 59.71 1433.00 0.624 8-Mar 05:00 240.0 80Adj. 1.0 90.42 89.52 0.790 0.790 110.0 120.0 93.0 94.0 88.45 2122.81 0.90 21.70 59.12 1419.00 0.668 8-Mar 06:00 235.0 80 Adj. 1.0 86.67 85.80 39.40 0.794 0.794 125.0 96.0 94.0 95.0 84.30 2023.24 0.87 20.80 56.17 1348.00 0.666 8-Mar 07:00 :240.0 80Adj. 1.0 95.84 94.88 0.794 0.794 130.0 1080 92.0 94.0 93.75 12250.06 0.96 23.00 60.96 1463.00 0.650 Page 3.10 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Post Frac Flow Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Date/Time ~ Wellhead Data Jl Separator Readings Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-rnmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORID (hhmm) (psig) (64ths) (%) (bbls) (bbls) (~6oOF) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 8-Mar 08:00 240.0 80 Adj. 1.0 90.00 89.10 39.40 0.794 0.794 120.0 114.0 92.0 95.0 87.54 2100.98 0.90 21.60 60.12 1443.00 0.687 8-Mar 09:00 240.0 80Adj. 1.0 89.17 88.28 0.794 0.794 125.0 111.0 92.0 95.0 87.20 2092.73 0.89 21.40 6Q58 1454.00 0.695 8-Mar 09:11 240.0 80 Adj. 1.0 23.33 23.10 0.794 0.794 125.0 111.0 92.0 95.0 22.81 2986.69 0.23 30.54 11.11 1454.00 0.487 8-Mar 09:15 ,., Page 3.11 Final_Reports / Separator Reading Company: ARCO Alaska, INC. Test Number: Post Frac Flow Halliburton Energy Services Wellhead Readings vs Time Well: Alpine lB Date: 3-Mar-96 1600 1400 1200 'E '$1000 o~ ~ 800 :~ 'F~ 600 4OO 200 0 12:00 0:00 12:00 0:00 12:00 0:00 12:00 0:00 Time 12:00 0:00 t128 112 96 80 64 48 32 16 0 12:00 --e-- Tubing -a- Casing --e-. Temperature -e- Choke Size Alpinlb2 / Current Wellhead Plot Page no: 4.1 Plot Start Time: 3-Mar-96 12:00:00 Plot End Time: 8-Mar-96 12:00:00 Company: ARCO Alaska, INC. Test Number: Post Frac Flow Halliburton Energy Services Fluid Rate History Plot Well: Alpine lB Date: 3-Mar-96 4OO0 2000 3000 '" ~ 2000 1000 0 12:00 0:00 12:00 0:00 12:00 0:00 12:00 Time 0:00 12:00 0:00 1500 500 0 12:00 Oil ~ Water/Diesel ~ Gas Alpnlb2/Current Rate Plot Page no: 4.2 Plot Start Time: 3-Mar-96 12:00:00 Plot End Time: 4-Mar-96 12:00:00 Company: ARCO Alaska, INC. Test Number: Post Frac Flow Halliburton Energy Services Fluid Cums vs Time Well: Alpine lB Date: 3-Mar-96 9000 8O0O 8000 7000 6000 .a '--' 5000 ,,= .e 4000 300O 2O00 1000 0 12:00 0:00 12:00 0:00 12:00 0:00 Time 12:00 0:00 12:00 0 0:00 12:00 7000 6000 5OO0 ~..-. ~ . 4000 3000 2000 1000 --e-- Oil --e- WatedDiesel -~=~ Gas Alpnl b21 Current Total Cum Plot Page no: 4.3 Plot Start Time: 3-Mar-96 12:00:00 Plot End Time: 8-Mar-96 12:00:00 Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: 1.667 Date / Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 (dd-mmm) Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (b Pre-Flow Strap 15.00 25.00 7.00 11.67 5.75 9.58 4.00 6.67 4.00 6.u~ 04-Mar 14:00 0.00 0.00 5.75 0.00 4.00 0.00 0.00 04-Mar 15:00 0.00 0.00 8.00 3.75 3.75 10.50 10.83 10.83 0.00 _ 04-Mar 15:15 0.00 0.00 0.00 10.50 0.00 10.83 0.00 04-Mar 15:30 0.00 0.00 0.00 11.25 1.25 12.08 0.00 04-Mar 15:45 0.00 0.00 0.00 1.00 0.00 1.25 13.33 0.00 04-Mar 16:00 0.00 0.00 0.00 2.00 0.00 20.00 33.33 0.00 04~Mar 16:15 0.00 0.00 0.00 2.00 11.00 18.33 51.67 0.00 04-Mar 16:30 0.00 0.00 0.00 3.00 9.00 16.67 68.33 0.on ,, 04-Mar 16:45 0.00 0.00 0.00 4.00 9.00 20.00 88.34 0.,,,, 04-Mar 17:00 0.00 0.00 0.00 5.00 4.00 11.67 100.00 0.00 04-Mar 17:15i 0.00 0.00 0.00 5.00 10.50 10.83 110.84 0.00 04-Mar 17:30 0_00 0.00 0.00 6.00 8.25 16.25 127.09 0.00 04-Mar 17:45 0.00 0.00 0.00 7.00 6.75 17.50 144.59 0.00 04-Mar 18:00 0.00 0.00 0.00 8.00 5.00 17.08 161.67 0.00 04-Mar 18:15 0.00 0.00 0.00 9.00 3.50 17.50 179.17 0.00 04-Mar 18:30 0.00 0.00 0.00 9.00 11.25 12.92 192.09 0.00 Page no: 6.1.1 Alpnlb2 / Tank Farm 1 thru 5 Company: ARCO Alaska. INC. Well Number: Alpine #lB Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: 1.667 Date / Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 (dd-mmm) Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc, Cum Tot Inc. Cum Tot (hh:mm) (fl.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ff.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bh~ 04-Mar 19:00 0.00 0.00 0.00 11.00 3.75 27.50 219.59 0.,,,, 04-Mar 19:30 0.00 0.00 8.00 0.00 12.00 8.50 27.92 247.50 0.00 04-Mar 20:00 0.00 0.00 1.00 9.00 21.67 21.67 0.00 0.00 04oMar 20:30 0.00 0.00 3.00 3.75 31.25 52.92 0.00 0.00 04-Mar 21:00 0.00 0.00 5.00 0.00 33.75 86.67 0.00 0.00 04-Mar 21:30 0.00 7.00 0.00 5.00 10,75 17.92 104.59 0.00 0.00 04-Mar 22:00 0.00 1.00 11.00 26.67 26.67 0.00 0.00 0.00 04-Mar 22:15 0.00 3.00 3.00 26.67 53.33 0.00 0.00 0.00 04-Mar 22:30 0.00 4.00 0.00 15.00 68.33 0.00 0.00 0.00 04-Mar 22:45 0.00 5.00 0.00 20.00 88.34 0.00 0.00 0 0r~ -- 04-Mar 23:00 0.00 5.00 9.25 15.42 103.75 0.00 0.00 0 .... 04-Mar 23:30 0,00 7.00 0.00 24.58 128.34 0,00 0.00 0.00 05-Mar 0:00 0.00 8.00 4.00 26.67 155.00 0.00 0.00 0.00 05-Mar 0:30 0.00 10.00 6.50 44.17 199.17 0.00 0.00 0.00 05-Mar 1:00 0.00 12.00 3 00 34.17 233.34 0.00 0.00 0.00 05-Mar 1~30 0.00 13.00 11.25 33.75 267.09 0.00 0.00 0.00 05-Mar 2:00 0.00 15.00 4.25 28.33 295.42 3.00 10.75 0.00 0.00 0,00 05-Mar 2:30 0.00 0.00 6.00 1.25 44.17 44.17 0.00 0.00 Page no: 6.1.2 Alpnlb2 / Tank Farm 1 thru 5 Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: 1~667 Date/Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 (dd-rnmm) Inc. Cum To1 Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl~ 05-Mar 3:00 0.00 0.00 7.00 10.75 35.83 80.00 0.00 0.,-,, 05~Mar 3:30 0.00 0.00 9.00 4.50 29.58 109.59 0.00 0.00 05-Mar 4:00 0.00 0.00 10.00 11.75 32.08 141.67 0.00 0.00 05-Mar 4:30 0.00 0.00 13.00 4.50 47.92 189.59 0.00 0.00 ., 05-Mar 5:00 0.00 0.00 15.00 1.25 34.58 224.17 0.00 0.00 05-Mar 5:30 0.00 1.00 2.00 0.00 16.00 10.00 34.58 258.76 0.00 0.00 05--Mar 6:00 0.00 3.00 4.75 44.58 44.58 0.00 0.00 0.00 05-Mar 6:30 0.00 5.00 1.50 34.58 79.17 0.00 0 O0 0.00 05-Mar 7:00 0.00 7.00 2.00 40.83 120.00 0.00 0.00 0.00 05-Mar 7:30 0.00 9.00 4.50 44.17 164.17 0.00 0.00 O.On 05-Mar 8:00 0.00 11.00 3.00 37.50 201.67 0.00 0.00 0.,,_ 05-Mar 8:30 0.00 13.00 2.00 38.33 240.00 0.00 6.00 0.00 0.00 05-Mar 9:00 0.00 0.00 0.00 2.00 7.50 42.50 42.50 0.00 05-Mar 9:30 0.00 0.00 0.00 4.00 11.00 45.83 88.34 0.00 05-Mar 10:00 0.00 000 0.00 6.00 11.25 40.42 128.75 0.00 05-Mar 10:30 0.00 0.00 0.00 9.00 1.25 43.33 172.09 0.00 , 05-Mar 11:00 0.00 0.00 0.00 11.00 3.75 44.17 216.25 0.00 05-Mar 11:30 0.00 0.00 3.00 6.50 0.00 12.00 11.75 33.33 249.59 0.00 Page no: 6.1.3 Alpnlb2 / Tank Farm 1 thru 5 Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: 1.667 Date / Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 (dd-mmm) Inc. Cum Tot Inc. Cum Tot Inc. Cum Tol lnc. Cum Tot Inc. Cum Tot (hh:mm) (ff.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in,) (bbls) (~-'" 05-Mar 12:00 0.00 0.00 6.00 0.25 49.58 49.58 0.00 0.UL) 05-Mar 12:30 0.00 0.00 8.00 1.75 42.50 92.09 0.00 0.00 05-Mar 13:00 0.00 0.00 10.00 4.75 45.00 137.09 0.00 0.00 05-Mar 13:30 0.00 0.00 12.00 11,00 50.42 187.50 0.00 0.00 05-Mar 14:00 0.00 0.00 15.00 2.75 46.25 233.75 7.00 0.00 0.00 05-Mar 14:30 0.00 0.00 0.00 3.00 0.75 49.58 49.58 0.00 05-Mar 15:00 0.00 0.00 0.00 5.00 6.75 50.00 99.59 0.00 05-Mar 15:30 0.00 0.00 0.00 9.00 11,25 87.50 187,09 0.00 05-Mar 16:00 0.00 0.00 0.00 10.00 10.25 18.33 205.42 0.00 05-Mar 16:30 0.00 0.00 11.00 0.00 12.00 10.25 40.00 245.42 O.nr~ 05-Mar 17:00 0.00 0.00 3.00 9.00 56.67 56.67 0,00 O. u,., , 05-Mar 17:30 0.00 0.00 6.00 2.75 49.58 106.25 0.00 0.00 05-Mar 18:00 0.00 0.00 8.00 1.75 38.33 144.59 0.00 0.00 05oMar 18:30 0.00 0.00 10.00 11.25 55.83 200.42 0.00 0.00 05-Mar 19:00 0.00 0.00 13.00 6.25 51.67 252.09 0.00 0.00 05-Mar 19:30 0.00 0.00 15.00 7.50 42.08 294.17 7.00 0.00 0.00 05-Mar 20:00 0.00 0.00 0.00 3.00 3.25 53.75 53.75 0.00 05-Mar 20:30! 0.00 0.00 0.00 6.00 4.50 62.08 115.84 0.00 Page no: 6.1.4 Alpnlb2 / Tank Farm 1 thru 5 Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: 1.667 Date / Time Tank No. I Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 (dd-mmm) Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (~-'" 05-Mar 21:00 0.00 0.00 0.00 8.00 5.00 40,83 156.67 0.uu 05-Mar 21:30 0.00 0.00 0.00 1000 5.50 40.83 197.50 0,00 05-Mar 22:00 0.00 0.00 0.00 12.00 10.75 48.75 246.25 0.00 05-Mar 22:30; 0.00 0.00 1.00 6.50 0.00 15,00 4.50 49.58 295.84 0.00 05-Mar 23:00 0.00 0.00 4.00 0.00 49.17 49.17 0.00 0.00 05-Mar 23:30 0,00 0.00 6.00 8.00 53.33 102.50 0.00 0.00 06-Mar 0:00 0.00 0.00 9.00 0,25 47.08 149.59 0.00 0.00 06-Mar 0:30 0.00 0.00 11.00 3.50 45.42 195.00 0.00 0.00 06-Mar 1:00 0.00 0.00 13.00 9.00 49.17 244.17 2.00 2.50 0.00 0.00 06-Mar 1:30 0.00 0.00 0.00 4.00 5.75 45.42 45.42 0.0n 06-Mar 2:00 0.00 0.00 0.00 7.00 0.25 50.83 96.25 0. ~,,, O6-Mar 2:30 0.00 0.00 0.00 9.00 5.50 48.75 145.00 0.00 06-Mar 3:00 0.00 0.00 0.00 11.00 7.25 42.92 187.92 0.00 06-Mar 3:30 0.00 0.00 7.50 0.00 13.00 8.75 42.50 230.42 0.00 06-Mar 4:00 0.00 0.00 3.00 7.50 60.00 60.00 0.00 0.00 06-Mar 4:30 0.00 0.00 6.00 1.25 49.58 109.59 0.00 0.00 06-Mar 5:00 0.00 0.00 8.00 200 41.25 150.84 0.00 0,00 06-Mar 5:30 0.00 0.00 10.00 11.75 56.25 207.09 0.00 0 00 Page no: 6.1.5 Alpnlb2 / Tank Farm 1 thru 5 Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: 1.667 Date / Time Tank No. I Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 (dd-mmm) Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (hh:mm) (ff.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (hr" 06-Mar 6:00 0.00 0.00 13.00 6.50 51.25 258.34 0.00 Quo 06-Mar 6:30 0.00 0.00 15.00 925 44.58 302.92 2.00 7.00 0.00 0.00 06-Mar 7:00 0.00 0.00 0.00 2.00 11.00 6.67 6.67 0.00 06-Mar 7:30 0.00 0.00 0.00 5.00 4.25 48.75 55.42 0.00 06-Mar 8:00 0.00 0.00 0.00 7.00 10.25 50.00 105.42 0.00 06-Mar 9:00 0.00 7.50 0.00 0.00 12,00 8.25 96.67 202.09 0.00 06-Mar 10:00 0.00 5.00 8.50 101.67 101.67 0.00 0.00 0.00 06-Mar 11:00 0.00 10.00 6.75 97.09 198.75 0.00 0.00 0.00 06-Mar 12:00 0.00 15.00 1 00 90.42 289.17 1.00 5.00 0.00 0.00 0.00 06-Mar 13:00 0.00 0.00 6,00 6.00 101.67 101.67 0.00 0.0n 06-Mar 14:00' 0.00 0.00 11.00 3.25 95.42 197.09 0.00 0.~v 06-Mar 15:00 0.00 0.00 16.00 0.00 94.59 291.67 6.00 0.00 0.00 06-Mar 16:00 0.00 0.00 0.00 5.00 8.25 103.75 103.75 0.00 06-Mar 17:00 Q00 0.00 0.00 10.00 5.25 95.00 198.75 0.00 06-Mar 18:00 0.00 0.00 2.00 7.00 0.00 15.00 2.25 95.00 293.76 0.00 06-Mar 19:00 0.00 0.00 8.00 0.25 108.75 108.75 0.00 0.00 06-Mar 20:00 0.00 0.00 12.00 6.00 89.59 198.34 1.00 4.25 0.00 0.00 06-Mar 21:00 0.00 0.00 0.00 6.00 2.50 97.09 97.09 0.00 Page no: 6.1.6 Alpnlb2 / Tank Farm 1 thru 5 Company: ARCO Alaska, INC. Well Number: Alpine #113 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: 1.667 Date / Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 (dd-mmm) Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (b~'~ 06-Mar 22:00 0.00 0.00 7.50 0.00 10.00 5.00 84.17 181.25 06-Mar 23:00 0.00 0.00 5.00 9.25 102.92 102.92 10.00 5.00 0.00 181.25 0.00 07-Mar 0:00 0.00 0.00 10.00 8.25 98.34 201.25 10.00 5.00 0.00 181.25 0.00 07-Mar 1:00 0.00 0.00 14.00 10.50 83.75 285.01 10.00 5.00 0.00 181.25 0.00 07-Mar 2:00 0.00 1.00 1.75 0.00 0.00 15.00 2.50 95.84 277.09 0.00 07-Mar 3:00 0.00 6.00 2.75 101.67 101.67 0.00 0.00 0.00 07-Mar 4:00 0.00 10.00 10.25 92.50 194.17 0.00 0.00 0.00 07-Mar 5:00 0.00 15.00 4.50 90.42 284.59 1.00 4.25 0.00 0.00 0.00 07-Mar 6:00 0.00 0.00 6.00 3.75 99.17 99.17 Q00 0.00 07-Mar 7:00 0.00 0.00 10.00 7.00 85.42 184.59 0.00 Q00 07-Mar 8:00 0.00 0.00 15.00 0.50 89.17 273.76 1,00 10.25 0.00 6. 07-Mar 9:00 0.00 0.00 0.00 7.00 2.50 107.09 107.09 0.00 07-Mar 10:00 0.00 0.00 2.00 0.00 0.00 11.00 10.00 92.50 199.59 0.00 07-Mar 11'00 0.00 0.00 6.00 11.00 98.34 98.34 0.00 0.00 07-Mar 12:00 0.00 0.00 11.00 9.00 96.67 195.00 0.00 0.00 07-Mar 13:00 0.00 0.00 16.00 2.50 89.17 284.17 1.00 0.00 0.00 0.00 07-Mar 14:00 0.00 0.00 0.00 5.00 6.00 90.00 90.00 0.00 07-Mar 15:00 0.00 0.00 0.00 10.00 3.00 95.00 185 00 000 Page no: 6.1.7 Alpnlb2 / Tank Farm 1 thru 5 Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: 1.667 Date / Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 (dd-mmm) Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bh~ 07-Mar 16:00 0.00 0.00 9.00 0.00 14.00 11.25 93.75 278.76 0.~,, 07-Mar 17:00 0.00 0.00 5.00 6.50 95.84 95.84 0.00 0.00 07-Mar 18:00 0,00 0.00 10.00 2.25 92.92 188.75 0.00 0.00 07-Mar 19:00 0.00 0.00 14.00 8.75 90.84 279.59 7.00 0.00 0.00 07-Mar 20:00 0.00 0.00 0.00 5.00 5.25 97.09 97.09 0.00 07-Mar 21:00 0.00 0.00 0.00 9.00 11.50 90.42 187.50 0.00 07-Mar 22:00 0.00 6.50 0.00 0.00 14.00 8.75 95.42 282.92 0.00 07-Mar 23:00 Q00 5.00 5.25 97.92 97.92 0.00 0.00 0.00 08-Mar O00 0.00 10.00 1.25 93.34 191.25 0.00 0.00 0.00 08-Mar 1:00 0.00 14.00 5.25 86.67 277.92 0.00 5.00 5.00 0.00 0.00 08-Mar 2:00 0.00 0.00 0.00 10.00 6.50 102.50 102.50 0.. 08-Mar 3:00 0.00 0.00 6.00 0.00 15.00 1.50 91.67 194.17 0.00 08-Mar 4:00 0.00 0.00 5.00 5.00 98.34 98.34 0.00 0.00 08-Mar 5:00 0.00 0.00 9.00 11.25 90.42 188.75 0.00 0.00 08-Mar 6:00 0.00 0.00 14.00 3.25 86.67 275.42 1.00 0.50 0.00 0.00 08-Mar 7:00 0.00 0.00 0.00 5.00 10.00 95.84 95.84 0.00 08-Mar 8:00 0.00 0.00 0.00 10.00 4.00 90.00 185.84 0.00 , 08-Mar 9:00 0.00 0.00 11.50 0.00 14.00 9.50 89.17 275.01 0.00 Page no: 6.1.8 Alpnlb2 / Tank Farm 1 thru 5 Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: 1.667 Date / Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 (dd-mmm) Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbll 08-Mar 9:15 0.00 0.00 2.00 1.50 23.33 23.33 0.00 0.._ Post-Flow Strap 7.50 12.50 4.25 7.08 7.00 11.67 5.00 8.33 4.00 6.67 -- Page no' 6.1.9 Alpnlb2 / Tank Farm 1 thru 5 This Section Left Intentionally Blank. Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: N/A Date/Time Frac I Frac 2 Frac 3 Inc. Inc Tot Inc. Inc Tot Inc. Inc Tot (mm/dd/yy hh:mm) (bbls) (bbl) (bbls) (bbl) (bbls) (bbl) Pre-Flow Strap 35.00 0.00 0.00 03-Mar-96 14:26 0.00 0.00 0.00 0.00 03-Mar-96 15:20 10.00 10.00 0.00 0.00 03oMar-96 15:50 15.00 25.00 0.00 0.00 03-Mar-96 16:30 10.00 35.00 0.00 0.00 03-Mar-96 17:00 5.00 40.00 0.00 0.00 03-Mar-96 17:30 5.00 45.00 0.00 0.00 03-Mar-96 18:30 10.00 55.00 0.00 0.00 03-Mar-96 19:00 10.00 65.00 0.00 0.00 03-Mar-96 19:30 10.00 75.00 0.00 0.00 03-Mar-96 19:55 10.00 85.00 0.00 0.00 03-Mar-96 20:15 10.00 95.00 0.00 0.00 03-Mar-96 20:30 10.00 105.00 0.00 0.00 03-Mar-96 20:45 10.00 115.00 0.00 0.00 03-Mar-96 21:05 10.00 125.00 0.00 0.00 03-Mar-96 21:25 10.00 135.00 0.00 0.00 Page no: 6.3.1 Alpnlb2/Tank Farm Frac 1 thru 3 Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: N/A Date/Time Frac 1 Frac 2 Frac 3 Inc. Inc Tot Inc. Inc Tot Inc. Inc Tot (mm/dd/yy hh:mm) (bbls) (bbl) (bbls) (bbl) (bbls) (bbl) 03-Mar-96 22:10 10.00 145.00 0.00 0.00 03-Mar-96 22:45 10.00 155.00 0.00 0.00 03-Mar-96 23:15 10.00 165.00 0.00 0.00 03-Mar-96 23:42 10.00 175.00 0.00 0.00 04-Mar-96 0:10 10.00 185.00 0.00 0.00 04-Mar-96 0:37 10.00 195.00 0.00 0.00 04-Mar-96 1:05 10.00 205.00 0.00 0.00 04-Mar-96 1:25 10.00 215.00 0.00 0.00 04-Mar-96 1:45 10.00 225.00 0.00 0.00 04-Mar-96 2:05 10.00 235.00 0.00 0.00 04-Mar-96 2:35 10.00 245.00 0.00 0.00 04-Mar-96 2:52 10.00 255.00 0.00 0.00 04-Mar-96 3:15 10.00 265.00 0.00 0.00 04-Mar-96 3:45 10.00 275.00 0.00 0.00 04-Mar-96 4:05 10.00 285.00 0.00 0.00 04-Mar-96 4:32 10.00 295.00 0.00 0.00 04-Mar-96 4:57 10.00 305.00 0.00 0.00 Page no: 6.3.2 Alpnlb2 / Tank Farm Frac 1 thru 3 Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: N/A Date/Time Frac 1 Frac 2 Frac 3 Inc. Inc Tot Inc. Inc Tot Inc. Inc Tot (mm/dd/yy hh:mm) (bbls) (bbl) (bbls) (bbl) (bbls) (bbl) 04-Mar-96 5:17 1000 315.00 0.00 0.00 04-Mar-96 5:37 10.00 325.00 0.00 0.00 04-Mar-96 6:00 10.00 335.00 0.00 0 00 04-Mar-96 6:20 10.00 345.00 0.00 0.00 04-Mar-96 6:40 10.00 355.00 0.00 0.00 04-Mar-96 7:00 15.00 370.00 0.00 0.00 04-Mar-96 7:15 10.00 380.00 0.00 0.00 0.00 04-Mar-96 7:30 0.00 0.00 6.00 6.00 04-Mar-96 7:45 0.00 0.00 9.00 15.00 04-Mar-96 8:00 0.00 0.00 7.80 22.80 04-Mar-96 8:15 0.00 0.00 4.20 27.00 04-Mar-96 8:30 0.00 0.00 12.00 39.00 04-Mar-96 8:45 0.00 0.00 11.30 50.30 04-Mar-96 9:00 0.00 0.00 9.50 59.80 04-Mar-96 9:15 0.00 0.00 10.00 69.80 04-Mar-96 9:30 0.00 0.00 15.00 84.80 04-Mar-96 9:45 0.00 0.00 12.00 96.80 Page no: 6.3.3 Alpnlb2 / Tank Farm Frac 1 thru 3 Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: N/A Date/Time Frac 1 Frac 2 Frac 3 Inc. Inc Tot Inc. Inc Tot Inc. Inc Tot (mm/dd/yy hh:mm) (bbls) (bbl) (bbls) (bbl) (bbls) (bbl) 04-Mar-96 10:00 0.00 0.00 9.50 106.30 04-Mar-96 10:15 0.00 0.00 10.00 116.30 04-Mar-96 10:30 0.00 0,00 22.00 138.30 04-Mar-96 10:45 0.00 0.00 15.10 153.40 04-Maro96 11:00 0.00 0.00 37.00 190.40 04-Mar-96 11:15 0.00 0.00 14.00 204.40 04-Mar-96 11:30 0.00 0.00 7.10 211.50 04-Mar-96 12:15 0.00 0.00 11.30 222.80 04-Mar-96 12:30 0.00 0.00 17.00 239.80 04-Mar-96 12:45 0.00 0.00 10.00 249.80 04-Mar-96 13:00 0.00 0.00 5.00 254.80 04-Mar-96 13:15 0.00 0.00 19.00 273.80 04-Mar-96 13:30 0.00 0.00 15.60 289.40 04-Mar-96 13:45 0.00 0.00 29.00 318.40 04-Mar-96 14:00 0.00 0.00 27.00 345,40 Post-Flow Strap 35.00 0.00 3.00 Page no: 6.3.4 Alpnlb2 / Tank Farm Frac 1 thru 3 Halliburton Energy Services Tank Farm Transfer Sheet Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: Post Frac Flow HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: 1.6667 Date/Time Truck Tank Starting Strap Ending Strap Vol Cum Number Number Transferred Volumn (mm/dd/yy hh:mm) (ft) (in) (bbls) (ft) (in) (bbls) (bbl) (bbl) 04-Mar-96 0:10 Fracl 260.00 260.00 04-Mar-96 6:20 Fracl 105.00 365.00 04-Mar-96 6:20 Frac3 133.00 498.00 04-Mar-96 15:42 Frac3 233.00 731.00 04-Mar-96 21:20 239-002 4 12.00 8.50 254.17 6.00 10.00 244.17 975.17 04-Mar-96 21:20 239-002 3 5.00 10.00 116.67 4.00 10.00 96.67 20.00 995.17 05-Mar-96 3:35 142-018 2 15.00 4.25 307.09 1.00 2.00 23.33 283.76 1278.93 05-Mar-96 6:00 142-019 3 16.00 10.00 336.67 3.00 6.50 70.83 265.84 1544.77 05-Mar-96 8:55 142018 2 13.00 2.00 263.34 7.50 12.50 250.84 1795.60 05-Mar-96 12:30 142-005 4 12.00 11.75 259.59 7.00 11.67 247.92 2043.53 05-Mar-96 14:15 142-018 3 15.00 2.75 304.59 11.00 18.33 286.26 2329.78 05-Mar-96 17:40 142-005 4 12.00 10.25 257.09 7.00 11.67 245.42 2575.20 05-Mar-96 19:30 142-018 3 15.00 7.50 312.51 1.00 6.50 30.83 281.67 2856.88 05-Mar-96 23:55 142-005 4 15.00 4.50 307.51 2.00 2.50 44.17 263.34 3120.21 06-Mar-96 1:30 142-018 3 13.00 9.00 275.01 7.50 12.50 262.51 3382.72 06-Mar-96 4:50 142-005 1 1.00 3.00 25.00 7.50 12.50 12.50 3395.22 06-Mar-96 4:50 142-005 4 13.00 8.75 274.59 2.00 7.00 51.67 222.92 3618.14 06-rvlar-96 8:25 142-018 3 15.00 9.25 315.42 1.00 5.00 28.33 287.09 3905.23 06-Mar-96 10:34 142-005 4 12.00 8.25 253.76 6.00 10.00 243.75 4148.99 06-Mar-96 13:48 142-018 2 15.00 1.00 301.67 1.00 1.75 22.92 278.76 4427.74 06-Mar-96 15:12 142-005 3 16.00 320.01 2.00 7.00 51.67 268.34 4696.08 06-Mar-96 18:35 142-018 4 15.00 2.25 303.76 1.00 4.25 27.08 276.67 4972.75 06-Mar-96 20:40 142-005 3 12.00 6.00 250.01 7.50 12.50 237.50 5210.26 07-Mar-96 1:40 142-018 3 14.00 10.50 297.51 1.00 4.25 27.08 270.42 5480.68 07-Mar-96 3:15 142-005 4 15.00 2.50 304.17 2.00 0.25 40.42 263.76 5744.43 07-Mar-96 5:50 142-018 2 15.00 4.50 307.51 1.00 5.25 28.75 278.76 6023.19 07-Mar-96 8:24 142-005 3 15.00 0.50 300.84 2.00 40.00 260.84 6284.03 07-Mar-96 10:15 142-018 4 11.00 10.00 236.67 1.00 20.00 216.67 6500.70 07-Mar-96 13:00 142-005 3 16.00 2.50 324.17 3.00 2.50 64.17 260.01 6760.70 07-Mar-96 15:00 142-018 3 3.00 2.50 64.17 9.00 15.00 49.17 6809.87 Page 7.1 Alpinl b2 / Tank Transfer Data Halliburton Energy Services Tank Farm Transfer Sheet Company: ARCO Alaska, INC. Well Number: Alpine #1B Test Number: Post Frac Flow HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: 1.6667 Date/Time Truck Tank Starting Strap Ending Strap Vol Cum Number Number Transferred Volumn (mm/dd/yy hh:mm) (ft) (in) (bbls) (ft) (in) (bbls) (bbl) (bbl) 07-Mar-96 15:00 142-018 4 14.00 11.25 298.76 3.00 3.75 66.25 232.50 7042.38 07-Mar-96 17:30 142-005 4 3.00 3.75 66.25 7.00 11.67 54.58 7096.96 07-Mar-96 17:30 142-005 3 14.00 8.75 294.59 4.00 3.00 85.00 209.59 7306.55 07-Mar-96 20:10 142-018 2 1.00 5.25 28.75 6.50 10.83 17.92 7324.47 07-Mar-96 20:10 142-018 3 4.00 3.00 85.00 6.00 10.00 75.00 7399.47 07-Mar-96 20:10 142-018 4 14.00 8.75 294.59 5.00 5.00 108.34 186.25 7585.72 08-Mar-96 0:20 142-005 2 14.00 5.25 288.76 1.00 5.00 28.33 260.42 7846.14 08-Mar-96 3:20 142-018 4 15.00 1.50 302.51 1.00 0.50 20.83 281.67 8127.81 08-Mar-96 7:20 142-005 3 14.00 3.25 285.42 11.50 19.17 266.26 8394.07 08-Mar-96 8:50 142-018 4 14.00 9.50 295.84 10.50 17.50 278.34 8672.41 08-Mar-96 12:45 142-005 3 2.00 1.50 42.50 7.00 11.67 30.83 8703.24 08-Mar-96 12:45 142-005 2 1.00 5.00 28.33 4.25 7.08 21.25 8724.49 08-Mar-96 12:45 142-005 4 10.50 17.50 5.00 8.33 9.17 8733.66 ,, , .... Page 7.2 Alpinlb2 / Tank Transfer Data Halliburton Energy Services Tank Farm Totals Summary Company: ARCO Alaska. INC. Well Number: Alpine #lB Test Number: Post Frac Flow H.E.S, Rep: Steve Tyburski 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 25.00 0.00 12.50 12.50 0.00 08-Mar-96 10:00 2 11.67 1387.11 1391.69 7.08 0.00 08-Mar-96 10:00 3 9.58 3353.40 3331.32 11.67 20.00 08-Mar-96 10:00 4 6.67 3272.15 3267.15 8.33 3.33 08-Mar-96 10:00 5 6.67 0.00 0.00 6.67 0.00 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 35.00 380.00 365.00 35.00 15.00 Frac2 0.00 Q00 0.00 0.00 0.00 Frac3 0.00 345.40 366.00 3.00 (23.60) Totals 94.58 8738.06 8733.66 84.25 14.73 Fluid Split Fluid Splits At Recorded Conditions To Correlate To Tank Volumes. Oil 8113.18 Water2 (bbl) 577.98 Diesel~ (bbl) 47.00 Notes' ~ Estimated By Customer. 2 Includes solids and gel fluids.(BS&W) 3 Volume Difference Due To Measurments, Expansion or Contraction. Page 8.1 Alpnlb2 / Tank Farm Summary ARCO ALASKA, INC. Alpine No. lB Surface Well Test March 3 - March 10, 1996 Clean Up Flow HALLIBURTON HALLIBURTON ENERGY SERVICES REPORT TICKET NO: MEMORY GAUGE TICKET NO: DATE: HALLIBURTON CAMP: TESTER: WITNESS: 030896 08-Mar-96 Kenai Steve Tyburski Tim Scarbrough DRILLING CONTRACTOR: LEGAL LOCATION: Wellhead Land OPERATOR: LEASE NAME: WELL NO: TESTED INTERVAL: ARCO Alaska, INC, Coleville River Alpine No. lB 8406 to 8493 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 t: SECTION 2: 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 SECTION 3: ASCII FILE DATA Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Flow #3 Company Rep: Tim Scarbrough Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# X 200" WC HES Rep: Steve Tyburski Storage Tank Coeff: 1,6667 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hfs) (psig) (Deg. F.) (psig) (64ths) 08-Mar 19:37 0.000 Open Schlumberger downhole shut-in tool 08-Mar 20:00 0.383 610 0 24 Adj. 19:45 Change choke to 24/64 08-Mar 20:30 0.883 680 48 24 Adj. 08-Mar 21:00 1.383 780 20 24 Adj. 08-Mar 21:30 1.883 780 50 20 24 Adj. 08-Mar 22:00 2.383 780 51 20 24 Adj. 08-Mar 22:30 2.883 780 51 24 Adj. 08-Mar 23:00 3.383 780 51 20 24 Adj. Go to hourly readings 09-Mar 0:00 4.383 780 53 20 24 Adj. 09-Mar 1:00 5.383 780 51 20 24 Adj. Rock choke 09-Mar 2:00 6.383 760 54 24 Adj. 09-Mar 3:00 7.383 760 54 20 24 Adj. Rock choke 09-Mar 4:00 8.383 750 54 20 24 Adj. 09-Mar 5:00 9.383 755 54 20 24 Adj. 09-Mar 6:00 10.383 750 54 20 24 Adj. 09-Mar 7:00 11.383 745 52 20 24 Adj. 09-Mar 8:00 12.383 745 52 20 24 Adj. Start methanol injection 09-Mar 8:30 12.883 740 52 20 20 Pos. 08:11 Change choke to 16/64 adjustable, change plate to .750" 09-Mar 9:00 13.383 745 52 20 20 Pos. 08:41 Change choke to 20/64 positive, change plate to 1.00" 09-Mar 9:30 13.883 745 50 20 20 Pos. 09-Mar 10:00 14.383 745 50 20 20 Pos. 09-Mar 10:30 14.883 745 52 20 20 Pos. 09-Mar 11:00 15.383 770 55 20 20 Pos. 11:02 Change choke to 16/64 positive Page no: 1.1 Final_Reports / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Flow #3 Company Rep: Tim Scarbrough Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# X 200" WC HES Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature 'Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 09-Mar 11:30 15.883 780 55 20 16 Pos Less than .1% BS&W 09-Mar 12:00 16.383 780 55 20 16 Pos. Less than .1% BS&W 09-Mar 12:30 16.883 780 54 20 16 Pos. Less than .1% BS&W 09-Mar 13:00 17.383 780 54 20 16 Pos Less than .1% BS&W 09-Mar 13:30 17.883 780 54 20 16 Pos. Less than .1% BS&W 09-Mar 14:00 18.383 780 54 20 16 Pos. 14:05 Change choke to 12/64 positive 09-Mar 14:30 18.883 795 55 20 12 Pos Less than .1% BS&W 09-Mar 15:00 19.383 805 54 20 12 Pos Less than .1% BS&W 09-Mar 15:30 19.883 805 54 20 12 Pos Less than .1% BS&W 09-Mar 16:00 20.383 805 54 20 12 Pos Less than .1% BS&W 09-Mar 16:30 20.883 805 54 20 12 Pos. Less than .1% BS&W 09-Mar 17:00 21.383 805 52 20 12 Pos. Less than .1% BS&W 09-Mar 17:30 21.883 805 52 20 12 Pos. Less than .1% BS&W 09-Mar 18:00 22.383 805 52 20 12 Pos. Less than .1% BS&W 09-Mar 18:30 22.883 805 52 20 12 Pos. Less than .1% BS&W 09-Mar 19:00 23.383 805 48 20 12 Pos. Less than .1% BS&W 09-Mar 19:30 23.883 810 48 20 12 Pos. Less than .1% BS&W 09-Mar 20:00 24.383 810 48 20 12 Pos. Less than .1% BS&W 09-Mar 20:01 24.400 Shut in at choke manifold 09-Mar 20:15 24.633 852 09-Mar 20:30 24.883 863 09-Mar 20:45 25.133 870 09-Mar 21:00 25.383 876 Page no: 1.2 Final_Reports / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Flow #3 Company Rep: Tim Scarbrough Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# X 200" WC HES Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 09-Mar 21:15 25.633 877 Continue To Monitor Surface Equipment. 09-Mar 21:30 25.883 872 09-Mar 21:45 26.133 874 09-Mar 22:00 26.383 876 09-Mar 22:30 26.883 881 09-Mar 23:00 27.383 884 09-Mar 23:30 27.883 887 10-Mar 0:00 28.383 890 10-Mar 1:00 29.383 895 10-Mar 2:00 30.383 899 10-Mar 3:00 31.383 903 10-Mar 4:00 32.383 906 10-Mar 5:00 33.383 909 10-Mar 6:00 34.383 864 Page no: 1.3 Final_Reports / Job Log Customer: ARCO Alaska, INC. Well: Alpine #1B Stage: Flow #3 Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 I 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 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) 8-Mar 19:37 Open Schlumberger downhole shut-in tool 8-Mar 20:00 610.0 44.0 0.0 24 Adj. 0.3 9.16 573.70 0.02 1.44 5.85 366.00 0.638 19:45 Change choke to 24/64 8-Mar 20:30 680.0 48.0 20.0 24 Adj. 0.3 26.79 845.91 0.07 2.15 13.57 371.00 0.439 8-Mar 21:00 780.0 50.0 20.0 24 Adj. 0.3 36.99 489.99 0.09 1.25 21.57 384.00 0.784 8-Mar 21:30 780.0 50.0 20.0 24 Adj. 0.3 48.08 532.24 0.12 1.35 29.55 383.00 0.720 8-Mar 22:00 780.0 51.0 20.0 24 Adj. 0.3 58.29 489.96 0.15 1.25 37.60 386.00 0.788 8-Mar 22:30 780.0 51.0 20.0 24 Adj. 0.1 70.23 573.32 0.16 0.58 44.93 352.00 0.614 8-Mar 23:00 780.0 51.0 20.0 24 Adj. 0.1 80.46 490.71 0.17 0.50 52.60 368.00 0.750 Go to hourly readings 9-Mar 00:00 780.0 53.0 20.0 24 Adj. 0.1 102.30 524.31 0.19 0.53 67.60 360.00 0.687 9-Mar 01:00 780.0 51.0 20.0 24 Adj. 0.1 122.93 495.08 0.21 0.51 82.72 363.00 0.733 Rock choke 9-Mar 02:00 760.0 54.0 20.0 24 Adj. 0.1 153.63 736.79 0.24 0.75 106.26 565.00 0.767 9-Mar 03:00 760.0 54.0 20.0 24 Adj. 0.1 185.78 771.46 0.28 0.79 128.30 529.00 0.686 Rock choke 9-Mar 04:00 750.0 54.0 20.0 24 Adj. 0.1 216.96 748.33 0.31 0.76 151.93 567.00 0.758 9-Mar 05:00 755.0 54.0 20.0 24 Adj. 0.1 251.54 830.08 0.34 0.85 175.18 558.00 0.672 9-Mar 06:00 750.0 54.0 20.0 24 Adj. 0.1 281.44 717.65 0.38 0.73 198.14 551.00 0.768 9-Mar 07:00 745.0 52.0 20.0 24 Adj. 0.1 311.15 712.84 0.41 0.73 221.85 569.00 0.798 9-Mar 08:00 745.0 52.0 20.0 24 Adj. 0.1 340.65 708.20 0.44 0.72 245.76 574.00 0.811 Start methanol injection 9-Mar 08:30 740.0 52.0 20.0 20 Pos. 0.1 346.81 295.50 0.44 0.30 248.89 150.00 0.508 :38:11 Change choke to 16/64 adjustable, change plate to .750" Page 2.1 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Alpine #lB Stage: Flow #3 Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 I Wellhead Data I Cumulative Volumes and Rates I 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) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 9-Mar 09:00 745.0 52.0 20.0 20 Pos. 0.1 359.85 625.65 0.46 0.64 259.37 503.00 0.804 08:41 Change choke to 20/64 positive, change plate to 1.00" 9-Mar 09:30 745.0 50.0 20.0 20 Pos. 0.1 374.63 709.46 0.47 0.72 269.55 489.00 0.689 9-Mar 10:00 745.0 50.0 20.0 20 Pos. 0.1 387.61 623.41 0.48 0.64 280.12 507.00 0.813 9-Mar 10:30 745.0 52.0 20.0 20 Pos. 0.1 405.21 844.82 0.50 0.86 290.87 516.00 0.611 9-Mar 11:00 770.0 55.0 20.0 20 Pos. 0.1 419.43 682.25 0.52 0.70 301.64 517.00 0.758 11:02 Change choke to 16/64 positive 9-Mar 11:30 780.0 55.0 20.0 16 Pos. 0.0 427.58 391.29 0.52 0.00 309.37 371.00 0.948 Lessthan .1% BS&W 9-Mar 12:00 780.0 55.0 20.0 16 Pos. 0.0 438.49 523.89 0.52 0.00 316.47 341.00 0.651 Less than .1% BS&W 9-Mar 12:30 780.0 54.0 20.0 16 Pos. 0.0 449.52 529.12 0.52 0.00 323.85 354.00 0.669 Less than .1% BS&W 9-Mar 13:00 780.0 54.0 20.0 16 Pos. 0.0 460.99 550.64 0.52 0.00 331.35 360.00 0.654 Less than .1% BS&W _ 9-Mar 13:30 780.0 54.0 20.0 16 Pos. 0.0 471.30 495.00 0.52 0.00 338.89 362.00 0.731 Less than .1% BS&W 9-Mar 14:00 780.0 54.0 20.0 16 Pos. 0.0 481.11 470.87 0.52 0.00 346.10 346,00 0.735 14:05 Change choke to 12/64 positive 9-Mar 14:30 795.0 55.0 20.0 12 Pos. 0.0 485.62 216.47 0.52 0.00 350.64 218.00 1.007 Less than .1% BS&W 9-Mar 15:00 805.0 54.0 20.0 12 Pos. 0.0 491.25 270.04 0.52 0.00 355.20 219.00 0.811 Less than .1% BS&W 9-Mar 15:30 805.0 54.0 20.0 12 Pos. 0.0 496.93 272.94 0.52 0.00 359.66 214.00 0.784 !Less than .1% BS&W 9-Mar 16:00 805.0 54.0 20.0 12 Pos. 0.0 501.02 196.35 0.52 0.00 363.80 199.00 1.013 'Less than .1% BS&W 9-Mar 16:30 805.0 54.0 20.0 12 Pos. 0.0 506.72 273.52 0.52 0.00 367.83 193.00 0.706 Less than .1% BS&W 9-Mar 17:00 805.0 52.0 20.0 12 Pos. 0.O 514.43 369.71 0.52 0.00 371.70 186.00 0.503 Less than .1% BS&W 9-Mar 17:30 805.0 52.0 20.0 12 Pos. 0.0 518.96 217.78 0.52 0.00 375.56 185.00 0.849 Lessthan .1% BS&W Page 2.2 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Alpine #lB Stage: Flow #3 Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Wellhead Data Jl Cumulative Volumes and Rates I Date/Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumin. 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) 9-Mar 18:00 805.0 52.0 20.0 12 Pos. 0,0 525.97 336.19 0.52 0.00 379.28 179.00 0.532 Less than .1% BS&W 9-Mar 18:30 805.0 52.0 20.0 12 Pos. 0.0 532.19 298.80 0.52 0.00 383.16 186.00 0.622 Less than .1% BS&W 9-Mar 19:00 805.0 48.0 20.0 12 Pos. 0.0 538.41 298.61 0.52 0.00 387.10 189.00 0,633 Less than .1% BS&W 9-Mar 19:30 810.0 48.0 20.0 12 Pos. 0.0 543.36 237.22 0.52 0.00 390.93 184.00 0,776 Less than .1% BS&W 9-Mar 20:00 810.0 48.0 20.0 12 Pos. 0.0 549.06 273.80 0.52 0.00 394.78 185.00 0.676 Less than .1% BS&W 9-Mar 20:01 Shut in at choke manifold 9oMar 20:15 852.0 9-Mar 20:30 863.0 9-Mar 20:45 870.0 -- 9-Mar 21:00 876.0 9-Mar 21:15 877.0 Continue To Monitor Surface Equipment. 9-Mar 21:30 872.0 9-Mar 21:45 874.0 9-Mar 22:00 876.0 9-Mar 22:30 881.0 9-Mar 23:00 884.0 9-Mar 23:30 887.0 lO-Mar 00:00 890.0 Page 2.3 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Alpine #1B Stage: Flow #3 Company Rep: Tim Scarbrough Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 II I Wellhead Data II Cumulative Volumes and Rates J 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) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 10-Mar 01:00 895.0 10-Mar 02:00 899.0 10-Mar 03:00 903.0 10-Mar 04:00 906.0 10-Mar 05:00 909.0 10-Mar 06:00 864.0 Page 2.4 Final_Reports / Results Summary Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Flow #3 Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Steve Tyburski 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,~_o (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-Mar 19:37 8-Mar 20:00 610.0 24 Adj. 0.3 9.20 9.18 39.90 0.790 0.790 120.0 36.0 63.0 63.0 9.16 573.70 0.02 1.44 5.85 366.00 0.638 8-Mar 20:30 680.0 24 Adj. 0.3 17.90 17.86 39.60 0.790 0.790 120.0 38.0 76.0 86.0 17.62 845.91 0.04 2.15 7.73 371.00 0.439 8-Mar 21:00 780.0 24 Adj. 0.3 10.40 10.37 39.70 0.790 0.790 120.0 42.0 91.0 92.0 10.21 489.99 0.03 1.25 8.00 384.00 0.784 8-Mar 21:30 780.0 24 Adj. 0.3 11.25 11.22 0.790 0.790 100.0 51.0 96.0 94.0 11.09 532.24 0.03 1.35 7.98 383.00 0.720 8-Mar 22:00 780.0 24 Adj. 0.3 10.41 10.38 39.60 0.790 0.790 105.0 48.0 84.0 94.0 10.21 489.96 0.03 1.25 8.04 386.00 0.788 8-Mar 22:30 780.0 24 Adj. 0.1 12.10 12.09 0.790 0.790 105.0 40.0 86.0 94.0 11.94 573.32 0.01 0.58 7.33 352.00 0.614 8-Mar 23:00 780.0 24 Adj. 0.1 10.40 10.39 39.40 0.790 0.790 105.0 45.0 100.0 92.0 10.22 490.71 0.01 0.50 7.67 368.00 0.750 9-Mar 00:00 780.0 24 Adj. 0.1 22.10 22.08 0.790 0.790 100.0 44.0 86.0 90.0 21.85 524.31 0.02 0.53 15.00 360.00 0.687 9-Mar 01:00 780.0 24Adj. 0.1 21.20 21.18 39.50 0.790 0.790 115.0 40.0 100.0 112.0 20.63 495.08 0.02 0.51 15.12 363.00 0.733 9-Mar 02:00 760.0 24 Adj. 0.1 31.20 31.17 0.790 0.790 115.0 96.0 98.0 103.0 30.70 736.79 0.03 0.75 23.54 565.00 0.767 9-Mar 03:00 760.0 24 Adj. 0.1 32.90 32.87 39.50 0.790 0.790 110.0 88.0 98.0 104.0 32.14 771.46 0.03 0.79 22.04 529.00 0.686 9-Mar 04:00 750.0 24Adj. 0.1 31.70 31.67 0.790 0.790 115.0 96.0 98.0 104.0 31.18 748.33 0.03 0.76 23.62 567.00 0.758 9-Mar 05:00 755.0 24Adj. 0.1 35.40 35.36 39.50 0.790 0.790 110.0 98.0 99.0 104.0 34.59 830.08 0.04 0.85 23.25 558.00 0.672 9-Mar 06:00 750.0 24 Adj. 0.1 30.40 30.37 0.760 0.760 105.0 100.0 99.0 104.0 29.90 717.65 0.03 0.73 22.96 551.00 0.768 9-Mar 07:00 745.0 24Adj. 0.1 30.40 30.37 39.40 0.760 0.760 105.0 100.0 99.0 104.0 29.70 712.84 0.03 0.73 23.71 569.00 0.798 9-Mar 08:00 745.0 24 Adj. 0.1 30.00 29.97 0.760 0.760 110.0 99.0 99.0 104.0 29.51 708.20 0.03 0.72 23.92 574.00 0.811 9-Mar 08:30 740.0 20 Pos. 0.1 6.25 6.24 0.764 0.764 400 60.0 99.0 100.0 6.16 295.50 0.01 0.3O 3.12 150.00 0.508 Page 3.1 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Alpine #1B Test Number: Flow #3 Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Steve Tyburski Storage Tank Coeff: 1.6667 Date/Time I Wellhead Data [I Separator 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 G©R CHLOR,~.~c (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-Mar 09:00 745.0 20 Pos. 0.1 13.30 13.29 39.30 0.764 0.764 130.0 64.0 88.0 98.0 13.03 625.65 0.01 0.64 10.48 503.00 0.804 9-Mar 09:30 745.0 20 Pos. 0.1 15.00 14.99 0.764 0.764 130.0 61.0 92.0 99.0 14.78 709.46 0.02 0.72 10.19 489.00 0.689 9-Mar 10:00 745.0 20 Pos 0.1 13.30 13.29 39.50 0.764 0.764 130.0 66.0 96.0 105.0 12.99 623.41 0.01 0.64 10.56 507.00 0.813 9-Mar 10:30 745.0 20 Pos. 0.1 17.90 17.88 0.764 0.764 130.0 68.0 97.0 105.0 17.60 844.82 0.02 0.86 10.75 516.00 0.611 9-Mar 11:00 770.0 20 Pos 0.1 14.60 14.59 39.60 0,776 0.776 130.0 70.0 98.0 111.0 14.21 682.25 0.01 0.70 10.77 517.00 0.758 9-Mar 11:30 780.0 16 Pos. 0.0 8.30 8.30 0,776 0,776 125.0 118.0 98.0 111.0 8.15 391.29 0.00 0.00 7.73 371.00 0,948 9-Mar 12:00 780.0 16 Pos. 0.0 11.20 11.20 39.40 0.776 0.776 125.0 100.0 100.0 111.0 10.91 523.89 0.00 0.00 7.10 341.00 0.651 9-Mar 12:30 780.0 16 Pos. 0.0 11.20 11.20 0.776 0.776 125.0 108.0 100.0 105.0 11.02 529.12 0.00 0.00 7.38 354.00 0.669 9-Mar 13:00 780.0 16 Pos. 0.0 11.70 11.70 39.70 0,776 0.776 130.0 106.0 90.0 99.0 11.47 550.64 0.00 0.00 7.50 360.00 0.654 9-Mar 13:30 780.0 16 Pos. 0.0 10.40 10.40 0.776 0,776 130.0 108.0 96.0 84.0 10.31 495.00 0.00 0.00 7.54 362.00 0.731 9-Mar 14:00 780.0 16 Pos. 0.0 10.00 10.00 39.40 0.776 0.776 130.0 100.0 98.0 98.0 9.81 470.87 0.00 0.00 7.21 346.00 0.735 9-Mar 14:30 795.0 12 Pos. 0.0 4.60 4.60 0.782 0.782 105.0 50.0 102.0 116.0 4.51 216.47 0.00 0.00 4.54 218.00 1.007 9-Mar 15:00 805.0 12Pos. 0.0 5.80 5.80 39.60 0.782 0.782 100.0 53.0 102.0 120.0 5.63 270.04 0.00 0.00 4.56 219.00 0,811 9-Mar 15:30 805.0 12Pos. 0.0 5.80 5.80 0.782 0,782 100.0 51.0 104.0 116.0 5.69 272.94 0.00 0.00 4.46 214.00 0.784 9-Mar 16:00 805,0 12 Pos. 0.0 4.20 4.20 39.60 0.782 0.782 100.0 44.0 106.0 112.0 4.09 196.35 0.00 0.00 4.15 199.00 1.013 9-Mar 16:30 805.0 12Pos. 0.0 5.80 5.80 0.782 0.782 100.0 41.0 100.0 110.0 5.70 273.52 0.00 0.00 4.02 193.00 0.706 9-Mar 17:00 805.0 12Pos. 0.0 7.90 7.90 39.50 0.782 0.782 90.0 41.0 100.0 110.0 7.70 369.71 0.00 0.00 3.88 186.00 0.503 9-Mar 17:30 805.0 12 Pos. 0.0 4.80 4.60 0.782 0.782 90.0 42.0 98.0 99.0 4.54 217.78 0.00 0.00 3.85 185.00 0.849 Page 3.2 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Gas Meter Run ID: 3.826 Well: Alpine #lB Barton Recorder Range: 1500# X 200" WC Test Number: Flow #3 H.E.S. Rep: Steve Tyburski Company Rep: Tim Scarbrough 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 CHLOE,~S (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-Mar 18:00 805.0 12 Pos 0.0 7.10 7.10 39.40 0.771 0.771 85.0 40.0 89.0 87.0 7.00 336.19 0.00 0.00 3.73 179.00 0.532 9-Mar 18:30 805.0 12 Pos. 0.0 6.30 6.30 0.771 0.771 90.0 41.0 89.0 94.0 6.23 298.80 0.00 0.00 3.88 186.00 0.622 9-Mar 19:00 805.0 12 Pos. 0.0 6.30 6.30 39.60 0.771 0.771 90.0 42.0 88.0 85.0 6.22 298.61 0.00 0.00 3.94 189.00 0.633 9-Mar 19:30 810.0 12 Pos. 0.0 5.00 5.00 0.771 0.771 90.0 40.0 86.0 93.0 4.94 237.22 0.00 0.00 3.83 184.00 0.776 9-Mar 20:00 810.0 12 Pos. 0.0 5.80 5.80 39.30 0.771 0.771 90.0 40.0 84.0 93.0 5.70 273.80 0.00 0.00 3.85 185.00 0.676 9-Mar 20:01 9-Mar 20:15 852.0 9-Mar 20:30 863.0 9-Mar 20:45 870.0 9-Mar 21:00 876.0 9-Mar 21:15 877.0 9-Mar 21:30 872.0 9-Mar 21:45 874.0 9-Mar 22:00 876.0 9-Mar 22:30 881.0 9-Mar 23:00 884.0 9-Mar 23:30 887.0 10-Mar 00:00 890.0 Page 3.3 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Alpine #lB Test Number: Flow #3 Company Rep: Tim Scarbrough Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Steve Tyburski 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 (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) 10-Mar 01:00 895.0 10-Mar 02:00 899.0 10-Mar 03:00 903.0 10-Mar 04:00 906.0 10-Mar 05:00 909.0 10-Mar 06:00 864.0 Page 3.4 Final_Reports / Separator Reading Company: ARCO Alaska, INC. Test Number: Flow #3 Halliburton Energy Services Wellhead Reading vs Time Well: Alpine lB Date: 8-Mar-96 1000 800 600 400 200 0 18:00 22:00 2:00 6:00 10:00 14:00 18:00 22:00 2:00 128 0 6:00 Time 112 96 80 u. ~- 64 ~ ._N Q- 0 48 ~0"' 32 16 -e-Tubing -e-Casing --e-Temperature -e-Choke Size Alpinlb3 / Current Wellhead Plot Page no: 4.1 Plot Start Time: 8-Mar-,96 18:00:00 Plot End Time: lO-Mar-g6 6:00:00 Company: ARCO Alaska, INC. Test Number: Flow ~3 Halliburton Energy Services Fluid Rate History Plot Well: Alpine lB Date: 8-Mar-96 9OO 600 8OO 7OO 6OO 500 400 300 200 100 0 ' 18:00 22:00 2:00 6:00 10:00 14:00 18:00 Time 5OO 400 · . ,~ - · 300 ~ .~., 200 100 22:00 2:00 6:00 --e-- Oil --e-- WatedDiesel + Gas Alpnl B31 Current Rate Plot Page no: 4.2 Plot Start Time: 8-Mar-96 18:00:00 Plot End Time: lO-Mar-9606:00:00 Company: ARCO Alaska, INC. Test Number: Flow #3 Halliburton Energy Services Fluid Cums vs Time Well: Alpine #lB Date: 8-Mar-96 6OO 600 500 400 300 200 100 0 18:00 22:00 2:00 6:00 10:00 14:00 18:00 22:00 2:00 Time 500 400 200 100 0 6:00 Oil --e--- WateflDiesel + Gas Alpnl B3 t Current Total Cum Plot Page no: 4.3 Plot Start Time: 8-Mar-96 18:00:00 Plot End Time: 10-Mar-96 06:00:00 Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: Flow #3 Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Tybursk~ Company Rep: Tim Scarbrough Tank Coefficient: 1.667 Date / Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 (dd-mmm) Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbl$) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) ) Pre-Flow Strap 7.50 12.50 4.25 7.08 7.00 11.67 5.00 8.33 4.00 6.67 08-Mar 19:30 0.00 0.00 7.00 0.00 0.00 0.00 08-Mar 20:00 0.00 0.00 1.00 0.50 9.17 9.17 0.00 0.00 08-Mar 20:30 0.00 0.00 1.00 11.25 17.92 27.08 0.00 0.00 08-Mar 21:00 0.00 0.00 2.00 5.50 10.42 37.50 0.00 0.00 08-Mar 21:30 0.00 0.00 3.00 0.25 11.25 48.75 0.00 0.00 08-Mar 22:00 0.00 0.00 3.00 6.50 10.42 59.17 0.00 0.00 08-Mar 22:30 0.00 0.00 4.00 1.75 1208 71.25 0.00 0.00 08-Mar 23:00 0.00 0.00 4.00 8.00 10.42 81.67 0.00 ~ 09-Mar 0:00 0.00 0.00 5.00 9.25 22.08 103.75 0.00 0.00 09-Mar 1:00 0.00 0.00 6.00 10.90 22.75 126.50 0.00 0.00 09-Mar 2:00 0.00 0.00 8.00 4.75 29.75 156.25 0.00 0.00 09-Mar 3:00 0.00 0.00 10.00 5.00 40,42 196.67 0.00 0.00 09-Mar 4:00 0.00 0.00 11.00 7.50 24.17 220.84 0.00 0 00 09-Mar 5:00 0.00 0.00 13.00 4.75 35.42 256.26 0.00 0.00 09-Mar 6:00 0.00 0.00 14.00 11.00 30.42 286.67 5.00 0.00 0.00 09-Mar 7:00 0.00 0.00 0.00 1.00 11.25 30.42 30.42 0.00 Page no: 6.1.1 AlpnlB3 / Tank Farm 1 thru 5 Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: Flow #3 Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: 1.667 Date/Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 (dd-mmm) Inc. Cum Tot Inc. Cum Tot Inc. Cum To1 Inc. Cum Tot Inc Cum Tot (hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) ) 09-Mar 8:00 0.00 0.00 0.00 3.00 5.25 30.00 60.42 0.00 09-Mar 8:30 0.00 0.00 0.00 3.00 9.00 6.25 66.67 0.00 09-Mar 9:00 Q00 0.00 0.00 4.00 5.00 13.33 80.00 0.00 09-Mar 9:30 0.00 0.00 0.00 5.00 2.00 15.00 95.00 0.00 09-Mar 10:00 0.00 0.00 0.00 5.00 10.00 13.33 108.34 0.00 09-Mar 10:30 0.00 0.00 0.00 6.00 8.75 17.92 126.25 0.00 09-Mar 11:00 0.00 0.00 0_00 7.00 5.50 14.58 140.84 0.00 09-Mar 11:30 0.00 0.00 0.00 7.00 10.50 8.33 149.17 0.00 09-Mar 12:00 0.00 0.00 0.00 8.00 5.25 11.25 160.42 0.00 09-Mar 12:30 0.00 0.00 0.00 9.00 11.25 171.67 09-Mar 13:00 0.00 0.00 0.00 9.00 7.00 11.67 183.34 0 00 09-Mar 13:30 0.00 0.00 0.00 10.00 1.25 10.42 193.75 0.00 09-Mar 14:00 0.00 0.00 0.00 10.00 7.25 10.00 203.75 0.00 09-Mar 14:30 0.00 0.00 0.00 10.00 10.00 4.58 208.34 0.00 09-Mar 15:00 0.00 0.00 0.00 11.00 1.50 5.83 214.17 0.00 09-Mar 15:30 0.00 0.00 0.00 11.00 5.00 5.83 220.00 0.00 09-Mar 16:00 0.00 0.00 0.00 11.00 7.50 4.17 224.17 0.00 09-Mar 16:30 0.00 0.00 0.00 11.00 11.00 5.83 230,00 0.00 Page no: 6.1.2 Alpnl B3 / Tank Farm 1 thru 5 Halliburton Energy Services Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: Flow #3 Tank Farm Strap Sheet HES Rep: Steve Tyburski Company Rep TimScarbrough Tank Coefficient: 1 667 Date ! Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 (dd-mmm) Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc Cum Tot (hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ff.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) ', 09-Mar 17:00 0.00 0.00 0.00 12.00 3.75 7.92 237.92 0.00 09-Mar 17:30 0.00 0.00 0.00 12.00 6.25 4.17 242.09 0.00 09-Mar 18:00 0.00 0.00 0.00 12.00 10.50 7.08 249.17 0.00 09-Mar 18:30 0.00 0.00 0.00 13.00 6.00 12.50 261.67 0.00 09-Mar 19:00 0.00 0.00 Q00 13.00 9.00 5.00 266.67 0.00 09-Mar 19:30 0.00 0.00 0.00 14.00 0.50 5.83 272.51 0.00 09-Mar 20:00 0.00 0.00 0.00 0.00 0 00 ~ost-Flow Straps 7.50 12.50 4.25 7.08 1.00 7.25 32.08 1.00 3.25 25.42 4.00 6.67 Page no: 6.1.3 AlpnlB3 / Tank Farm 1 thru 5 Halliburton Energy Services Tank Farm Transfer Sheet Company: ARCO Alaska, INC. Well Number: Alpine #1B Test Number: Flow #3 HES Rep: Steve Tyburski Company Rep: Tim Scarbrough Tank Coefficient: 1.667 Date/Time Truck Tank Starting Strap Ending Strap Vol Cum Number Number Transferred Volumn (mm/dd/yy hh:mm) (ft) (in) (bbls) (ft) (in) (bbls) (bbl) (bbl) 09-Mar-96 15:51 142-005 3 14.00 11.00 298.34 1.00 7.25 32.08 266.26 266.26 09-Mar-96 21:30 142-005 4 14.00 0.50 280.84 1.00 3.25 25.42 255.42 521.68 Page 7.1 Alpinlb3 / Tank Transfer Data Halliburton Energy Services Tank Farm Totals Summary Company: ARCO Alaska, INC. Well Number: Alpine #lB Test Number: Flow #3 H.E.S. Rep: Steve Tyburski 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 12.50 0.00 0.00 12.50 0.00 08-Mar-96 10:00 2 7.08 0.00 0.00 7.08 0.00 08-Mar-96 10:00 3 11.67 286.67 266.26 32.08 0.00 08-Mar-96 10:00 4 8.33 272.51 255.42 25.42 0.00 08-Mar-96 10:00 5 6.67 0.00 0.00 6,67 0.00 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 g 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 Split Fluid Splits At Recorded Conditions To Correlate To Tank Volumes. Oil (bbl) 558.79 Water2 (bbl) 0.52 Diesel1 (bbl) 0.00 Notes: ~ Estimated By Customer. 2 Includes solids and gel fluids.(BS&W) 3 Volume Difference Due To Measurments, Expansion or Contraction. Page 8.1 AlpnlB3 / Tank Farm Summary STATE OF ALASKA ALAo,~A OIL AND GAS CONSERVATION COM~,,,,..,,.'.ICN WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [] GAS E~] SUSPENDED r~ ABANDONED [] SERVICE [-""] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-20 3 Address 8 APl Number P.O. Box 100360, Anchoracje, AK 99510-0360. ,, 50-103-20211-02 ~ '4~ I N/A 1465'FSL, 2250'FVVL, SEC1,T11N, R4E, UM ! t;'r'~- i 10 WellNumber At Top Producing Interval 2002' FNL, 1617' FEL, Sec 12, T11 N, R4E, UM. : ALPINE #1B At Total Depth 11 Field and Pool 2207' FNL, 1522' FEL, SEC 12, TllN, R4E, U WILDCAT 5 ElevationRKB 38'in feet (indicate KB, DF, etc.) 6 LeaseADLDesignation380075 and Serial No. 12 DateSpuddec~ ~m13 Date~d~ '~114 DateComp.,Susp. orAband. 15 WaterDepth, ifoffshore [16 Nc. of Completions -1.1i~-¢e-98" ) /~,~ ~j'" /~,~,, ~/,¢' 3-23-96 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 8850' MD, 7531'TVD 8248' MD, 7014'TVD YES ~ NO [~I NA feetMD NA 22 Type Electric or Other Logs Run 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT GRADE TOP BTM HOLE SIZE CEMENT RECORD 20" 94# B SURF 110' 26" 350 SX ASl 13.375" 68# L-80 SURF 1765' 16" 350 SX ASlII & 650 SX ASl 7" 29.0# L-80 SURF 8839' 8.5" 235 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) 3.5" 8200' 8179' 8406'-8493'MD 7150'-7225'TVD 6 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production ]Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of Iithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. TO BE SENT UNDER SEPARATE COVER BY EXPLORATION GEOLOGY Alat~ka 011 & i~a¢ Con;, Commission Anchorage Form 10-407 Submit in duplicate 30. GEOLOGIC MARKERS 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 ATTACHMENTS AS-BUILT SURVEY, P&A DIAGRAM AND DAILY DRILLING REPORTS 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed ~~~7~ Title DATE ~"~-?L~"',----~, _ , 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 imsitu 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 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RECEIVED Thomas W. McKay, P.E. MA.F{ 2 6 1996; Senior Drilling Engineer Kuparuk Drill Site DevelopmentAlaska 0i[ & Gas Oorls. Commission ATO 1202 Anchorage Phone 265-6890 Fax 265-6224 March 25, 1996 Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1 433 (907) 276-7542 (fax) Re: Weekly Operations Report Summary Alpine #1B Completion & Production Well Test APl #50-103-20211-02, Permit No. 95-20 "TIGHT HOLE" Gentlemen: Please find attached the weekly operations summary for the ARCO Alpine No. 1B for the period of March 18 through March 23, 1996. This week's operations included well suspension operations. A sand plug had been placed across the test perforations, with a cement plug being placed and tagged above the sand plug to suspend the well. Final suspension operations were concluded with a blanking plug set in the tubing tailpipe, and a back pressure valve set in the tubing hanger at surface. The tubing and tubing annulus was pressure tested prior to securing the well. The 7" by 13-3/8" annulus was then cemented and pressure tested satisfactorily. All kill weight fluids remain in the wellbore. 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 265-6890. Thomas W. McKay, P.E. Senior Drilling Engineer Kuparuk Drill Site Development ARCO Alaska, Inc. ARCO Alaska, Inc. is a Subsidiary of AtlandcRichfieldCompany ARCO ALASKA INC. Alpine No. lB Section 1-T11N-R4E UM Wildcat Coivillo Dolta North Slope, Alaska Epoch WelJ Logging, Inc. RECEIVED MAY 2 6 1995 Alaska Oil & Gas O0ns. Anchorage ARCO ALASKA INC. Alpine No. lB Section 1-T11N-R4E UM Wildcat Colvillo Dolta North Slope, Alaska Epoch We!J Logging, Inc. TAlkIE OF CONTENTS 1. Well Resume Daily Chronology $. Mud Record 4. Deviation Survey Record 5. Morning Reports 6. Drilling Curve 7. Formation Log 8. MWD Combo Log WELL RESUME OPERATOR: WELL NAME: LOCATION: FIELD: COORDINATES: ELEVATIONS: COUNTY: STATE: APl INDEX: SPUD DATE: TOTAL DEPTH: COMPLETION DATE CONTRACTOR: RIG RIG TYPE: MUD PUMPS: COMPANY GEOLOGISTS: COMPANY ENGINEERS: TOOLPUSHERS: MUD COMPANY: MUD ENGINEERS: MUD TYPES: HOLE SIZES: CASING DATA: MUOLOOGING SERVICES: TYPE UNIT: UNIT J: LOGGING GEOLOGISTS: SAMPLE TECHNICIANS: ELECTRIC LOGS BY: LOG INTERVALS: DST INTERVALS: CORED INTERVALS: CORING COMPANY: WELL STATUS: ARCO ALASKA INC. ALPINE NO. 1B SEC. 1 T11 N R4E, UM COLVILLE DELTA 146~ FSL, 2250' FWL R.K.B. -- 40' NORTH SLOPE BOROUGH ALASKA 50-103-20211 -Ct2 MARCH 1,1995 MARCH 9, 1995 POOL ARCTIC ALASKA, INC. NO. 6 SCR DIESEL-ELECTRIC (2) NATIONAL A1700 (6" X 1 JERRY VELDHUIS, RENEE HANNAN GREG WILSON, PAUL DECKER DON MCKELVEY / DAVE BAUMGARNER GARY GOERLITCH ! DARRELL GREEN BAROID DRILLING FLUIDS, INC. GARY MARTIN / SAM WILLIS GEL/WATER TO 1785' / BLAND TO 8850' TD 26" TO 120', 16" TO 1785', 8 1/2" TO 8850' 20" AT 1 20', 13 3/8" AT 1765' EPOCH WELL LOGGING, INC. (FID) GAS DETECTION, DML J RIGWATCH 14 CRAig SILVA, JOHN DIVINE ROBERT ANDERSON, LARRY SHIELDS SCHLUMBERGER 1800' TO 8850' NONE NONE NONE NO DOPE. TIGHT HOLE DAILY CHRONOLOGY ALPINE NO. lB 3-01-95 3-02-95: 3-03-95 3-04-95: 3-05-95: 3-06-95 3-07-95: 3-08-95: 3-09-95: 3-10-95: Replace brake pads on drawworks. Cut drilling line and RIH. Tag cement at 4060'. Circulate out and condition mud. Trip out to 2450' and spot high vis pill. POOH. Rig up tubing tools and run 143 joints 3" tubing to 2200'. Lay cement plug from 2200' to 1660'. Trip out of hole to 1274' and reverse out. POOH. Lay down tubing and test BOP"s. Lay down drill pipe. Lay down drill pipe and pick up BHA. Wait on cement. RIH with 12.25" bit and tag cement at 1645". Drill cement to 1672'. Circulate bottoms up and pressure test casing. Drill cement to 1800'. Circulate out and POOH> Change BHA and lay down 8.5" drill collars. Pick up mudmotor and 8.5" bit. RIH and tag plug at 1800' and start kick off plug. Drill from 1800' to 2177'. Circulate bottoms up and displace old drilling mud with new drilling mud. Displace old drilling with new drilling mud. Run back to bottom and drill from 2177' to 2239'. MWD tool failure. Circulate bottoms up and POOH. Change out MWD tool and RIH. Drill from 2239' to 3321' Drill from 3321' to 3550'. Make 19 stand wiper trip. Drill from 3350' to 4594'. Drill from 4594 to 5059'. POOH. RIH with NB No. 2 and a mudmotor. Drill from 5059' to 5156'. Drill from 5156' to 5957'. Circulate out and POOH. RIH with RRB No. 3. Drill from 5997' to 6120' Drill from 6120' to 7800'. Circulate out and POOH. POOH. Change BHA. Pick up Sperry Sun LWD tool. Rih with RRB No. 3. Drill from 7804' to 7892'. Note high pump pressure while drilling. Mudmotor failure, unable to stall out mudmotor despite increasing WOB to 30 klb. Circulate out and POOH. Pick up new mudmotor and RIH. Pickup new mudmotor and RIH with RRB No. 3. Drill from 7892' to 8768'. Drill from 8768' to 8850' (T.D.). Spot high vis pill and circualte all the way around. POOH. Unload neutron source and download LWD tool. Lay down PDC bit, mudmotor and Sperry Sun LWD tool. Rig up wireline and start running E-logs (DSI,LDT, GR,AM). Hung up at 7342'. Work free and POOH. Rig down wireline. Pick up drill bit and RIH to bottom. Circulate and clean hole. MUD RECORD ARCO ALASICA INC. ALPINE NO. lB DATE DEPTH MW FV PM YP GELS FL SOL SD pH Cl- 3-02-95 2200 9.9 40 9 9 4/10 8.4 10.0% 1/8 11.8 600 3-02-95 2363 9.8 44 16 21 5/10 7.6 6.0% 1/8 10.0 550 3-03-95 3274 10.2 44 18 15 3/8 7.0 10.0% 1/8 9.9 500 3-03-95 3867 10 42 14 16 5/12 6.6 10.0% 1/8 9.9 550 3-04-95 4580 10.2 42 14 16 4/12 6.2 12.0% 1/8 9.6 350 ..... 3-05-95 4993 10 42 15 16 4/15 6.0 11.0% TRC 9.0. 350 3-05-95 5158 10.2 44 15 22 6/20 6.0 12.0% TRC 8.9 350 .... 3-06-95 5784 10.1 42 14 17 6/21 6.0 12.0% TRC 9.1 300 3-06-95 6118 10.1 44 15 18 5/24 6.0 12.0% TRC 9.0 300 3-07-95 6942 10.0 41 15 16 4/21 6.0 12.0% TRC 9.2 350 .... 3-07-95 7770 10.1 41 15 15 4/16 5.6 12.0% TRC 9.0 300 3-08-95 7850 10.2 40 17 21 6/28 5.6 13.0% TRC 9.0 300 3-09-95 8230 10.0 41 14 1/15 4/15 4.6 12.0% TRC 9.1 300 3-09-95 8765 10.0 41 15 14 4/12 4.4 12.0% 1/8 8.9 300 3-10-95 8850 10.0 40 13 14 3/14 : 4.6 12.0% TRC 8.9 300 ii i I ARCO ALASKA INC. SURVEY RECORD ALPINE NO. lB MEASURED INCLINATION AZIMUTH DEPTH (FEET) (DEGREE} (DEGREE) 140.86 0.31 89.36 185.51 0.21 180.99 277.18 0.27 203.35 368.00 0.24 137.55 458.73 0.19 188.10 548.36 0.23 107.31 638.48 0.14 22.89 722.74 0.22 4.54 816.56 0.29 25.14 900.14 0.19 84.39 992.99 0.54 101.81 1084.37 0.73 105.38 1179.92 0.86 113.46 1274.18 O. 89 118.92 1367.04 1.01 125.45 1460.05 1.08 128.64 1564.64 1.21 116.07 1659.44 1.1 129.31 1752.44 1.24 124.48 1867.83 3.81 136.20 1899.34 5.04 140.74 1994.38 7.83 140.35 2088.65 10.13 148.59 2181.01 12.09 156.41 2273.84 14.70 159.11 2367.27 17.70 158.59 2460.35 20.57 156.85 2553.04 23.28 156.73 2646.05 26.16 157.12 2739.41 29.63 158.07 2835.13 33.00 159.51 VERTICAL DEPTH (FEET} 140.86 185.51 277.18 368.00 458.73 548.36 638.48 722.74 816.55 900.13 992.98 I O84.36 1179.9 1274.15 1366.99 1459.99 1564.56 1659.34 1752.32 1867.59 1899.00 1993.43 2086.55 2177.18 2267.48 2357.18 2445.11 2531.09 2615.57 3698.07 2779.84 LATITUDE DEPARTURE VERTICAL N/S, +1- E/W, +i- SECTION (FEET) (FEET} (FEET} 0.00 0.39 0.14 -0.08 0.51 0.26 -0.44 0.42 0.57 -0.78 0.46 0.89 -1.07 0.57 1.2 -1.27 0.72 1.44 -1.22 0.94 1.48 -0.97 0.99 1.26 -0.57 1.10 0.94 -0.37 1.33 0.83 -0.44 1.91 1.11 -0.68 2.89 1.69 -1.13 4.13 2.56 -1.76 5.42 3.62 -2.59 6.72 4.86 -3.61 8.07 6.31 -4.71 9.93 7.98 -5.72 11.43 9.51 -6.86 12.95 11.12 -10.34 16.64 15.71 -12.16 18.24 17.99 -20.38 25.01 28.12 -32.40 33.43 42.39 -48.20 41.54 60.05 -68.12 49.63 81.55 -92.42 59.04 107.61 -120.64 70.64 138.11 -152.44 84.27 172.70 -188.22 99.51 211.58 -228.61 116.13 255.25 -274.99 134.10 304.98 i i i .... i i i ARCO ALASKA INC. SURVEY RECORD ALPINE NO. MEASURED INCLINATION AZIMUTH DEPTH (FEET) {DEGREE) IDEGREE) 2990.90 35.46 160.26 3023.81 27.87 159.82 3117.56 39.32 158.68 3211.15 39.67 157.58 3305.35 39.'97 158.48 3397,73 40.16 158.39 3492.68 40.42 157.49 3579.91 40.16 159.05 3673.04 40.09 158.79 3767.94 40.00 158.91 3862.44 40,13 159.82 3955.08 39.96 159.77 4048.37 39.97 159.61 4150.02 39.91 160.91 4235.18 39.73 160.24 4337.65 39.42 160.00 4430.50 39.14 160.43 4525.83 38.82 161.04 4618.94 37.12 159.45 4713.42 35.22 159.99 4799.33 34.20 160.48 4901.22 35.06 161.07 4994.85 36.85 159.78 5087.61 37.90 158.92 5182.14 37.90 158.92 5276.53 38.07 158.69 5370.88 38.09 158.45 5462.35 38.06 158.31 5557.11 38.04 158.80 5648.10 38.97 158.59 5734.81 40.46 158.70 VERTICAL DEPTH {FEET) 2858.19 2933.51 3006.78 3079.01 3151.36 3222.06 3294.48 3361.02 3432.23 3504.88 3577.2O 3648.12 3719.62 3797.55 3862.96 3941.94 4013.81 4087.92 4161.32 4237.59 4308.21 4392.04 4467.83 4616.29 4616.29 469O.68 4764.95 4836.95 4911.57 4982.78 5049.48 i i i lB LATITUDE N/S, +I- {FEET) -325.04 -377.75 -432.43 -487.66 -543.61 -598.91 -655.81 -708.21 -764.21 -821.16 -878.O8 -934.02 -990.22 -1051.64 -1103.07 -1164.46 -' 219.77 -' 276.38 -' 330.28 -' 382.59 -' 428.62 -' 483.29 -' 535.09 -' 641.99 -' 641.99 -' 696.15 -' 750.33 -' 802.77 -' 857.13 -' 909.91 -' 961.51 DEPARTURE E/W, +I- (FEET) 152.42 171.56 192.29 214.46 237.O2 258.88 281.94 302.82 324.41 346.44 367.88 388.46 409.26 431.31 449.45 471.65 491.54 511.33 530.67 550.00 566.54 585.60 604.03 644.09 644.09 665.10 686.36 707.14 728.49 749.07 769.24 VERTICAL SECTION [FEET) 358.27 414.32 472.80 532.32 592.64 652.10 713.49 769.90 829.91 890.97 951.79 1011.39 1071.30 1136.53 1191.03 1256.28 1315.04 1374.96 1432.21 1487.96 1536.85 1594.71 1649.65 1763.8O 1763.80 1821.89 1880.09 1936.50 1994.90 2051.55 21 O6, 95 ARCO ALASKA INC. SURVEY RECORD ALPINE NO. lA MEASURED INCLINATION AZIMUTH VERTICAL LATITUDE DEPARTURE VERTICAL DEPTH DEPTH N/S, +1- E/W, +i- SECTION {FEET) (DEGREE) {DEGREE} {FEET) {FEET) (FEET) {FEET) 5835.91 43.06 157.83 5124.89 -2024.04 794.19 2174.28 5930.11 43.14 159.12 5193.67 -2083.92 817.80 2238.64 6022.35 43.14 159.12 5260.97 -2142.85 840.28 2301.71 6116.12 43.12 158.52 5329.41 -2202.63 863.45 2365.82 6209.25 42.99 158.87 5397.45 ~2261.86 886.55 2429.40 6300.86 42.54 158.04 5464.70 -2319.72 909.38 2491.60 6394.72 41.91 157.22 5534.21 -2378.05 933.38 2554.66 6488.64 41.52 156.69 5604.32 -2435.55 957.84 2617.13 6582.26 40.77 158.18 5674.82 -2492.43 981.48 2678.71 6676.58 40.15 157.94 5746.59 -2549.20 1004.35 2739.91 6766.20 39.65 157.00 5815.34 -2602.29 1026.38 2797.39 6861.97 39.01 156.78 5889.42 -2658.12 1050.20 2858.06 6949.66 38.46 156.77 5957.42 -2708.54 1071.83 2912.90 7046.73 38.04 156.22 6034.06 -2763.65 1095.80 2972.95 7137.98 37.90 156.48 6106.00 -2815.07 1118.32 3029.05 7230.10 37.22 156.41 6179.02 -2866.55 1140.76 3085.17 7325.43 36.47 155.41 6255.31 -2918.73 1164.09 3142.27 7424.69 36.04 156.01 6335.35 -2972.24 1188.24 3200.90 7517.65 35.71 155.78 6410.68 -3021.96 1210.48 3255.32 7611.49 35.51 155.65 6486.97 -3071.77 1232.95 3309.89 7704.88 35.10 155.18 6563.19 -3120.84 1255.40 3363.78 7803.85 34.81 155.82 6644.31 -3172.44 1278.92 3240.40 7890.68 34.89 155.68 6715.56 -3217.68 1299.30 3469.96 7984.39 33.70 155.54 6792.98 -3265.77 1321.10 3522.69 8071.77 32.98 155.19 6865.98 ~3309.42 1341.12 3570.64 8163.64 32.25 155.44 6943.36 -3354.42 1361.80 3620.08 8256.71 31.81 155.26 7022.25 -3399.28 1382.39 3669.37 8349.20 31.01 154.58 7101.19 -3442.93 1402.82 3717.47 8442.62 31.06 155.20 7181.24 -3486.54 1423.26 3765.53 8534.37 31.22 156.35 7259.77 -3529.80 1442.73 3860.67 8725.76 30.34 153.98 7424.36 -3618.53 1483.52 3910.41 ARCO ALASKA INC. SURVEY RECORD ALPINE NO. lA MEASURED INCLINATION AZIMUTH VERTICAL LATITUDE DEPARTURE VERTICAL' DEPTH DEPTH N/S, +1- E/W, +1- SECTION (FEET) (DEGREE) (DEGREEi {FEET) {FEET) (FEETI {FEET} 8761.68 30.36 155.19 7455.36 -3634.92 1491.30 3928.52 8850.00 30.36 155.19 7531.57 -3675.44 1510.03 3973.08 )CH WELL LOGGING, MORNING REPORT ARCO ALASKA, INC. Date: 3-01-95 Time: 04:00 04:00 Depth: 1660'(Est) YESTERDAY: 1645' Estimated Pore Pressure: N/A DC Exponent: N/A ROP Sand: x fi/hr ROP Shale: x fi/hr BIT INFORMATION: No. Size Type SIN Jets Interval 1 12.25" x x x x DRH,LING PARAMETERS: H IG H Rate of Penetration at Torque at Weight on Bit at Rotary RPM at Pump Pressure at DRII,LING MUD REPORT: Report Depth: 1660' MW 10.2 VIS 43 PV 14 YP 15 GELS SOL 13.0 OIL 0 SD Tr MBT 30.0 pH GAS SUMMARY: HIGH Total Ditch Gas (units) 150.0 Total Cuttings Gas (units) Methane (C-1) (ppm) Ethane (C-2) Propane (C-3) Butane (C-4's) Pentane(C-5's) Background Gas: 10 units Connection Gas: units ALPINE if 1 B OIL SHOWS: N/A Last Casing: 13 3/8" at 1765' 24 Hour Progress: ! Ftg. Hours Condition x x x LOW at at at at at 5/14 FL 9.7 Cl- AVERAGE fi/hr amp Klbs rpm psi 6.4 FC 2 400 Ca+ 40 LOW AVERAGE at 4040' 10.0 at 9940' 35.0 units at at units at at ppm at at ppm at at ppm at at ppm at at ppm Trip Gas: 150 units at 4040" at Wiper Gas: units at LITHOLOGY: DAILY ACTIVITY SUMMARY: Replace brake pads on draw works; cut drill line; trip in hole; tag cement at 4060'; circulate out and condition mud; trip out to 2450'; spot hi vis pill; POOH; rig up tubing tools; run 143 jts 3"2 tubing to 2200'; lay cement plug from 2200' to 1645'; trip out of hole to 1274'; reverse out; POOH; lay down tubing; test BOP's; lay down pipe. SERVICES PROVIDED: DML MUDL~ING and RIGWATCH MONITORING SYSTEM Epoch Personnel on site: 4 Arco Alaska Reps: Don McKelvey/Dave Bumgarner Report By: Craig Silva )CH WELL LOGGING, MORNING REPORT ARCO ALASKA, INC. ALPINE # 1 B Date: 3-02-95 Time: 04:00 04:00 Depth: 2177' YESTERDAY: 1645' Last Casing: 13 3/8" at 1765' 24 Hour Progress: 432' Estimated Pore Pressure: 9.1 DC Exponent: 0.85 ROP Sand: 164 fi/hr ROP Shale: 163 fi/hr BIT INFORMATION: No. Size Type S/N Jets Interval RR 12.25" HTC FDGH NC09046 3-14's 1645'-1800' 1 8.50" HTC AT J-P05 T92WH 3-13's 1800'- DRILLING PARAMETERS: HIGH LOW Rate of Penetration 600.0 at 2064' 18.9 at Torque 127 at 2118' 0 at Weight on Bit 20 at 1870' 0.4 at Rotary RPM 275 at 1900' 199 at Pump Pressure 2248 at 1994' 1763 at DRILLING MUD REPORT: Report Depth: 2177' MW 9.9 VIS 40 PV 9 YP 9 GELS SOL 10.0 OIL 0 SD 0.125 MBT 0 pH Ftg. Hours Condition 155' 1.21 NR In Hole AVERAGE 1870' 163.3 flJhr 67 amp 2095' 9 Klbs 1882' 242 rpm 1801' 2071 psi 4/10 FL 8.4 FC 2 11.8 CI- 600 Ca+ 40 GAS SUMMARY: HIGH LOW AVERAGE Total Ditch Gas (units) 29.5 at 2045' 1.0 at 1842' 12.6 units Total Cuttings Gas (units) 48 at 2040' 1 at 1860' 22.8 units Methane (C-1) (ppm) 5390 at 2043' 199 at 1830' 2545 ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4's) at at ppm Pentane(C-5's) at at ppm Background Gas: 2 units Trip Gas: units at ' Connection Gas: units at Wiper Gas: units at OIL SHOWS: None LITHOLOGY: Mudstone/claystone 30% Tuff/Bentonite 15% Shale 55% DAILY ACTMTY SUMMARY: Lay down drill pipe; pick up BHA; wait on cement; run in hole with 12.25" bit and tag cement at 1645'; drill cement to 1672'; circulate bottoms up and pressure test casing; drill cement to 1800'; circulate out and POOH; change BHA; lay down 8.5" DC's; pick up mudmotor and 8.50" bit; RIH; tag plug at 1800' and start drilling get kicked off; drill from 1800' to 2177'; circulate bottoms up; displace old drilling mud with new drilling mud. SERVICES PROVIDED: DML MUDLOC~ING and RIGWATCH MONITORING SYSTEM Epoch Personnel on site: 4 Arco Alaska Reps: Don McKelvey/Dave Bumgarner Report By: Craig Silva EPOCH WELL LOGGING, INC. MORNffNG REPORT ARCO ALASKA, INC. Date: 3-03-95 Ti me: 04:00 04:00 Depth: 3321' YESTERDAY: 2177' Estimated Pore Pre.qsure: 9.1 DC Exponent: 0.90 ROP Sand- 202 fi/hr ROP Shale: 136 fi/hr ALPINE #lB Last Casing: 13 3/8" at 1765' 24 Hour Progress: 1144' BIT INFORMATION: No. Size Type SIN Jets Interval 1 8.50" HTC ATJ-P05 T92WH 3-13's 1800'- DRII,I,INC~ PARAMETERS: HIGH Rate of Penetration 402.1 at 2434' 28.8 Torque 178 at 3164' 0 Weight on Bit 17 at Rotary RPM 321 at 2724' 189 Pump Pressure ~,~ at 2710' 1¢5,~ DRII,I,ING MI JD REPORT: MW 10.2 VIS 44 PV SOL 10.0 OIL 0 SD GAS SI ~fMARY: Total Ditch Gas (units) Totsl Cuttings Gas (units) Methane (C-1) (ppm) Ethane (C-2) Propane (C-3) Butane (C-4's) Pentane(C-5's) Background Gas: 6 units Connection Gas: units at Ftg. Hours Condition In Hole LOW AVERAGE at 2921' 146.8 fi/hr at 99 amp at 2474' 9 Klbs at 2644' '~ ~ ,~7,~ rpm at 2645' 1966 psi Report Depth' 2177' 18 YP 15 GELS 3/8 FL 7.0 FC 2 0.125 MBT 16.0 pH 9.9 CI- 550 Ca+ 20 HIGH LOW AVERAGE 162.0 at 3166' 3.0 at '~'~'~'~' '~ ~-~-,-'- --5.,. units 130 at 2640' 5 at '~'~' ~-~-~, 62.1 u n its 30472 at 3096' 565 at 2471' 4233 ppm 1502 at 3157' 0 at ~_~_~o 177 ppm 819 at 3157' 0 at '~'~ ~ ~-~-,~,~ 72 ppm 428 at 3157' 0 at 2910' 28 ppm 83 at 3159' 0 at 3086' 4 pprn Trip Gas: 30 units at Wiper Gas: 6 units at 2177' O11, SIIOWS: Trace to poor shows in the more massive sandstones of this interval, occasional very very' light brown visible oil staining after 3090', poor visible porosity; trace to 60% very dull yellow sample fluorescence; very.' pale to occasionally moderately bright yellow to whitish yellow cut fluorescence with some wispy slow milkier streaming; dull to moderately bright yellow residual ring fluorescence; predominantly no visible cuts, rare very. faint straw visible cut. I,TTIIOI,OGY: Mudstonelclaystone 61% Tuff/Bentonite/Tufffaceous claystone 10% Shale 17% Sandstone 12% DAII,Y ACTIVITY SITM-MARY- Displace old drilling mud with new drilling mud; run back to bottom and drill from 2177' to drill from ~'~n' --,:,~, MWD tool failure; circulate bottoms up; POOH; change out MWD tool; RIH; ~,~,~, to report depth. REMARKS:.. SERVICES PROVIDED: DML MLrDLOGGING and RIGWATCH MONITORING SYSTE-%4 Epoch Personnel on site: 4 Arco Alaska Reps: Don McKelvey/Dave Bumgarner Report By: Craig Silva EPOCH WELL LOGGING, 1Nc. MORNING REPORT ARCO ALASKA, INC. ALPINE #lB Date: 3-04-95 Time: 04:00 04:00 Depth: 4594' YESTERDAY: 3321' Last Casing: 13 3/8" at 1765' 24 Hour Progress: 1273' Estimated Pore Pressure: 9.1 DC Exponent: 1.00 ROP Sand: 153 fi]hr ROP Shale: 93 fi]hr BIT INFORMATION: No. Size Type SIN Jets Interval 1 8.50" HTC AT J-P05 T92WH 3-13's 1800'- DRILLING PARAMETERS: HIGH Rate of Penetration 225.0 at 4271' 8.3 Torque 224 at 4519' 103 Weight on Bit 14 at 4311' 2 Rotary RPM 317 at 4542' 193 Pump Pressure 2760 at 4335' 856 DRILLING MUD REPORT: Report Depth: 4580' MW 10.2 ViS 42 PV 14 YP 16 GELS SQL 12.0 OIL 0 SD 0.125 MBT 26.0 pH GAS SUMMARY: HIGH Total Ditch Gas (units) 387.0 at Total CuRings Gas (units) 325 at Methane (C-1) (ppm) 52404 at Ethane (C-2) 4822 at Propane (C-3) 3325 at Butane (C-4's) 1444 at Pentane(C-5's) 861 at Background Gas: 44 units Connection Gas: units at Ftg. Hours Condition In Hole LOW at 3586' at 4559 at 3564' at 3586' at 3586' AVERAGE 94.3 fi]hr 165 amp 7 Klbs 301 rpm 2314 psi 4/12 FL 6.2 FC 2 9.6 Cl- 350 Ca+ 20 LOW 4474' 2.9 at 3836' 4500' 18 at 3539' 4474' 487 at 3836' 4474' 33 at 3836' 4474' 8 at 3836' 4474' 0 at 3877' 4474' 0 at 3988' Trip Gas: Wiper Gas: AVERAGE 41.1 units 78.5 units 4838 ppm 319 ppm 177 ppm 87 ppm 26 pprn 30 units at 2239' 120 units at 3550' OIL SHOWS: Trace to poor shows in the many very thin sandstones of this interval, very good to fair show. at 4425' to 4525'; light brown visible oil staining; poor to good visible porosity; trace to 80% dull to bright yellow sample fluorescence; instant to slow very pale to locally very bright yellow to whitish yellow cut fluorescence with some slow to fast slightly milkier streaming; dull to bright yellow residual ring fluorescence; predominantly no visible cuts, faint straw visible cut in zone with good show; visible pops in the mud and pervasive fluorescence in zone from 4425-4500; also strong petroleum odor; good sheen when water added to the mud; greasy, oily to the touch. LITHOLOGY: Mudstone/claystone 71% Calcareous Tuff/Tufffaceous claystone 3% Shale 17% Sandstone 9% DAILY ACTIVITY SUMMARY: Drill from 3321' to 3550'; do 19 std wiper trip; drill from 3550' to report depth. REMARKS:.. SERVICES PROVIDED: DML ML~LOGGING and RIGWATCH MONITORING SYSTEM Epoch Personnel on site: 4 Arco Alaska Reps: Don McKelvey/Dave Bumgarner Report By: Craig Silva EPOCH WELL LOGGING, INC. MORNING REPORT ARCO ALASKA, INC. ALPINE #lB Date: 3-05-95 Time: 04:00 04:00 Depth: 5156' YESTERDAY: 4594' Last Casing: 13 3/8" at 1765' 24 Hour Progress: 562' Estimated Pore Pressure: 9.1 DC Exponent: 1.44 ROP Sand: 105 fi/hr ROP Shale: 48 fi/hr BIT INFORMATION: No. Size Type SIN Jets Interval I 8.50" HTC AT J-P05 T92WH 3-13's 1800'-5059' 2 8.50" STC MFDSSHL LC7420 3-13's 5059'- DRILLING PARAMETERS: HIGH Rate of Penetration 171.0 at 5031' 6.2 Torque 254 at 5031' 0 Weight on Bit 29 at 4777' 9 Rotary RPM 319 at 4707' 241 Pump Pressure 2866 at 4960' 2254 DRILLING MUD REPORT: Report Depth: 4580' MW 10.0 VIS 42 PV 15 YP 16 GELS SOL 11.0 OIL 0 SD Tr MBT 27.0 pH GAS SUMMARY: HIGH Total Ditch Gas (units) 189.0 at Total Cuttings Gas (units) 130 at Methane (C-1) (ppm) 35233 at Ethane (C-2) 966 at Propane (C-3) 521 at Butane (C-4's) 387 at Pentane(C-5's) 120 at Background Gas: 44 units Connection Gas: units at Ftg. Hours Condition 3259' 40.20 8-8-CC,BT-ALL-F-7-4C-WT-TQ In Hole LOW AVERAGE at 4776' 54.4 ft/hr at 156 amp at 4596' 14 KI bs at 4802' 297 rpm at 4775' 2567 psi 4/15 FL 6.0 FC 2 9.0 CI- 350 Ca+ 20 LOW AVERAGE 4725' 19.0 at 5040' 46.4 units 4680' 15 at 4920' 55.2 units 4725' 3442 at 4884' 8299 ppm 4725' 77 at 5040' 290 ppm 4574' 25 at 5041' 116 ppm 4574' 7 at 5050' 61 ppm 4575' 0 at 17 ppm Trip Gas: 225 units at 5059' Wiper Gas: units at OIL SHOWS: Poor to fair show. at 4720' to 4760'; very light brown visible oil staining; poor to good visible porosity; spotty to 80% dull to bright yellow sample fluorescence; instant to slow pale to locally very bright yellow to whitish yellow cut fluorescence with some slow to fast slightly milkier streaming; dull to bright yellow residual ring fluorescence; predominantly no visible cut, very faint straw visible cut; no visible pops in the mud but spotty immobile splotchy fluorescence; also mild petroleum odor; very light sheen when being washed. LITHOLOGY: M udstone/claystone/siltstone 36% Calcareous Tuff/tuffaceous claystone 3% Shale 48% Sandstone 13% DAILY ACTIVITY S~Y. Drill from 4594' to 5059'; POOH; RIH with NB #2 and mudmotor; drill from 5059' to report depth. REMARKS:.. SERVICES PROVIDED: DML MUDLOGGING and RIGWATCH MONITORING SYSTEM Epoch Personnel on site: 4 Arco Alaska Reps: Don McKelvey/Dave Bumgarner Report By: Craig Silva Date: 3-06-95 Time: 04:00 Depth: 6120' YESTERDAY: Estimated Pore Pressure: 9.1 ROP Sand: 100 fi/hr ,, OCH WELL LOGG/NG,/NC. MORN/NG REPORT ARCO ALASKA, 04:00 5156' DC Exponent: 1.39 ROP Shale: 69 fi/hr BIT INFORMATioN: No. Size Type 2 8.50" STC MFDSSHL 3 8.50" HYCALOG DS40HF DRILLING PARAMETERs: Rate of Penetration HIGH Torque 124.1 at Weight on Bit 280 at Rotary RPM 26 at Pump Pressure 325 at 2518 at DRILLING MUD REPORT: MW 10.1 VIS 42 PV SOL 12. o 0 SD GAS St v V: Total Ditch Gas (units) HIGH 78.5 at ]"'+al Cuttings Gas (units) 38 ':?i' ~ane (C- 1) (Ppm) at L=mane(c.2) 15252 at Propane (C-3) 270 at Butane (C-4's) 136 at Pentane(C.5,s) 77 at 12 at Background Gas: 6 Connection Gas: units un/ts at OIL SHOWs: None. LITHOLOGy: Jets 3-13's Interval 5059'-5997 2-12's, 2-11's 5997'_ S/N LC7420 Last Casing: 13 3/8" at 1765, 24 Hour Progress: 964' 16095 5098' LOW 5716' 4.0 at 5811' 0 at 5876' 3 at 5897' 219 at 1228 at Report Depth: 5784' 14 yp 17 GELS Tr MBT 25.0 pH 5975' LOW 5070' 3.0 at 5975' 6 at 5113' 538 at 5113' 16 at 5128' 4 at 5130' 0 at 0 at Fig Hours Condition 938' 15.51 4'4-WT-A-E-/_NO_HR In Hole 5061' AVERAGE 69.5 fi/hr 5062' 207 amp 5062' 17 KIbs 5063' 310 rpm 2393 ps/ 6/21 FL 6.0 FC 2 9.1 CI- 300 Ca+ 40 5627' AVERAGE 5520' 13.8 units 5618' 14.0 units 5336' 2543 PPm 5779' 60 PPm 5893' 24 PPm 8 PPm 1 PPm Trip Gas: 157 units Wiper Gas: at 5997' units at Mudstone/claystone/siltstone 54% Calcareous Tuff/tuffaceous claystone 2% Shale 42% )AlLy ACTIVITY SUMsca~y: Drill from 5156' to 5957'. · . . Sandstone 2% om 5997' to report depth. , clrcutate out; POOH; RIH with RRB #3; drill EMARKS: . . SERVICEs PROVIDED: DM[. MUDLOOGING and RIGWATcH MONITORING SYSTEM :poch Personnel on site: 4 Arco Alaska Reps: Don McKelvey/Dave BUmgarner Report By: Craig S//va EI-OCH WELL LOGGING, INC. MORNING REPORT ARCO ALASKA, INC. ALPINE #lB Date: 3-07-95 Time: 04:00 04:00 Depth: 7800' YESTERDAY: 6120' Last Casing: 13 3/8" at 1765' 24 Hour Progress: 1680' Estimated Pore Pressure: 9.1 DC Exponent: 0.90 ROP Sand- 187 fi/hr ROP Shale: 103 fi/hr BIT INFORMATION: No. Size Type SIN Jets Interval 3RE 8.50" HYCALOG DS40HF 16095 2-12's, 2-11's 5997'-7800' DRILLING PARAMETERS: HIGH LOW Rate of Penetration 300.1 at 6167' 11.7 at Torque 361 at 6915' 0 at Weight on Bit 20 at 6620' 2 at Rotary RPM 405 at 6231' 249 at Pump Pressure 2914 at 7080' 1400 at DRILLING MUD REPORT: Report Depth: 7770' MW 10.1 VIS 41 PV 15 YP 15 GELS SOL 12.0 OIL 0 SD Tr MBT 27.0 pH GAS SUMMARY: HIGH Total Ditch Gas (units) 57.5 at Total Cuttings Gas (units) 62 at Methane (C-1) (ppm) 10997 at Ethane (C-2) 399 at Propane (C-3) 322 at Butane (C-4's) 139 at Pentane(C-5's) 16 at Ftg Hours Condition 1803' 18.38 In Hole AVERAGE 6501' 129.7 fi/hr 6502 293 amp 6001' 7 Klbs 6502' 312 rpm 5998' 2527 psi 4/16 F L 5.6 FC 2 9.0 CI- 300 Ca+ 40 LOW AVERAGE 6122' 6.0 at 6820' 18.1 u n its 7560' 12 at 6960' 31.5 units 6131' 1015 at 6820' 3119 ppm 7367' 42 at 6705' 139 ppm 7369' 10 at 6278' 67 ppm 7367' I at 6718' 20 ppm 7369' 0 at 6938 2 ppm Background Gas: 11 units Trip Gas: 157 units at 5997' Connection Gas: units at Wiper Gas: units at OIL SHOWS: Nearly continuous minimum trace show in sandstone through the entire report interval;' in thin local sandstone sections the show improves to poor to fair; in general, the better the visible porosity of the sandstone being inspected, the better the show; almost none of the sandstone appears to be very massive, and is often visibly very thinly interbedded with the shale and claystone, and also separated from adjacent sandstone by carbonaceous/organic partings; locally the porosi~/appears good, but very often there is smome clay or silt in the supporting matrix and the porosity appears poor; 1) the less porous looking sandstones have trace to 60% very dull yellow to yellowish orange sample fluorescence, slow dull yellow to greenish yellow cut fluorescence with spotty very slow streaming, and a very dull yellowish gold to orangish yellow residual ring; 2) the friable more porous looking sandstones often have a light brown oil staining, up to 70% bright yellow sample fluorescence, pale to bright yellowish white to greenish yellow cut fluorescence with slow to occasionally fast slightly milkier streaming that is also rarely very light straw in plain light, and a residual ring with dull to moderately bright yellow to whitish yellow fluorescence that is colorless in plain light. LITHOLOGY: Mudstone/claystone/siltstone 39% Calcareous Tuff/tuffaceous claystone 1% Shale 32% Sandstone 28% DAILY ACTIVITY SUMMARY: Drill from 6120' to 7800'; circulate out; POOH. REMARKS:.. SERVICES PROVIDED: DMI. MUDLOGGING and RIGWATCH MONITORING SYSTEM Epoch Personnel on site: 4 Arco Alaska Reps: Don McKelvey/Dave BuIngarner Report By: Craig Silva E -OCH WELL LOGGING, h, c. MORNING REPORT ARCO ALASKA, INC. ALPINE #lB Date: 3-08-95 Ti me: 04:00 04:00 Depth: 7892' YESTERDAY: 7804' Last Casing: 13 3/8" at 1765' 24 Hour Progress: 88' Estimated Pore Pressure: 9.1 DC Exponent: 0.91 ROP Sand: N/A ROP Shale: 103 ftIhr BIT INFORMATION: No. Size Type SIN Jets 3RR 8.50" HYCALOG DS40HF 16095 2-12's, 2-11's 3RR 8.50" HYCALOG DS40HF 16095 2-12's, 2-11's 3RR 8.50" HYCALOG DS40HF 16095 2-12's, 2-11's DRILLING PARAMETERS: HIGH Rate of Penetration 185.7 at 7773' Torque 363 at 7892' Weight on Bit 12 at 7883' Rotary RPM 331 at 7835' Pump Pressure 3234 at 7882' Interval Ftg Hours Condition 5997'-7804' 1807' 18.38 1-1-NO-A-X-1-N0-BHA 7804'-7892' 88' 1.33 1-1-NO-A-X-1-N0-BHA 7892'- In Hole LOW AVERAGE 14.6 at 7886' 102.8 ft/h r 289 at 7809' 318 am p 3 at 7746' 5 Klbs 299 at 7885' 314 rpm 2280 at 7764' 2546 psi DRILLING MUD REPORT: Report Depth: 7892' MW 10.1 VIS 40 PV 13 YP 15 GELS 4/14 FL 5.6 FC 2 SOL 12.0 OIL 0 SD Tr MBT 28.0 pH 9.0 CI- 300 Ca+ 40 GAS SUM]VLA~Y: HIGH LOW AVERAGE Total Ditch Gas (units) 21.0 at 7720' 4.5 at 7812' 13.5 units Total Cuttings Gas (units) 46 at 7680' 18 at 77400' 32.7 units Methane (C-1) (ppm) 3301 at 7716' 707 at 7812' 2113 ppm Ethane (C-2) 218 at 7717' 49 at 7812' 140 ppm Propane (C-3) 136 at 7718' 21 at 7812' 85 ppm Butane (C-4's) 58 at 7688' 6 at 7890' 30 ppm Pentane(C-5's) 8 at 7690' 0 at 4 ppm Background Gas: 5 units Trip Gas: 13 units at 7804' Connection Gas: units at Wiper Gas: units at OIL SHOWS: None LITHOLOGY: Mudstone/claystone/siltstone 2% Bentonite/calcareous tuff 1% Shale 95% Sandstone 2% DAILY ACTIVITY SUMMARY: POOH; change BHA; pick up Sperry LWD tool; RIH with RRB #3; drill from 7804' to 7892'; note high pump pressure while drilling; mudmotor failure, unable to stall out mudmotor despite increasing WOB to 30klb; circulate out; POOH; test BOP's; pickup new mudmotor and RIH. REMARKS:.. SERVICES PROVIDED: DML MIYDLOGGING and RIGWATCH MONITORING SYSTEM Epoch Personnel on site: 4 Arco Alaska Reps: Don McKelvey/Dave Bumgamer Report By: Craig Silva ,,, EPOCH WELL LOGGING, INC. MORNING REPORT ARCO ALASKA, INC. ALPINE giB Date: 3-09-95 Time: 04:00 Last Casing: 13 3/8" at 1765' 04:00 Depth: 8768' YESTERDAY: 7892' 24 Hour Progress: 876' Estimated Pore Pressure: 9.2 DC Exponent: 0.83 ROP Sand: 53 fi/hr (partly controlled through target zone) ROP Shale: 68 fi/hr BIT INFORMATION: No. Size Type SIN Jets Interval Ftg Hours Condition 3RR 8.50" HYCALOG DS40HF 16095 2-12's, 2-11's 7892'- In Hole DRILLING PARAMETERS: HIGH LOW AVERAGE Rate of Penetration 180.0 at 7967' 1.7 at 7950' 67.4 fi/hr Torque 466 at 8509' 304 at 8060' 374 amp Weight on Bit 11 at 7977' 0.4 at 8569' 4 Klbs Rotary RPM 256 at 8510' 207 at 7959' 247 rpm Pump Pressure 3051 at 8076' 1927 at 7966' 2521 psi DRILLING MUD REPORT: Report Depth: 8765' MW 10.0 VIS 41 PV 15 YP 14 GELS 4/12 FL 4.4 FC 2 SOL 12.0 OIL 0 SD 0.125 MBT 28.0 pH 8.9 CI- 300 Ca+ 40 GAS SLrMMARY: HIGH Total Ditch Gas (units) 605.0 at Total Cuttings Gas (units) 480 at Methane(C-I) (ppm) 63202 at Ethane (C-2) 8570 at Propane (C-3) 8922 at Butane (C-4's) 4330 at Pentane(C-5's) 1676 at LOW AVERAGE 8478' 17.0 at 7950' 71.3 units 8500' 12 at 7920' 98.4 units 8478' 2984 at 7950' 8934 pprn 8478' 192 at 7950' 870 ppm 8478' 109 at 7950' 764 ppm 8478' 42 at 7950' 389 ppm 8478' 6 at 7950' 137 ppm Background Gas: 24 units Trip Gas: 76 units at 7892' Connection Gas: units at Wiper Gas: units at OIL SHOWS: Very good to good show from 8400' to 8500'; well sorted very fine sandstone has good visible porosity and pervasive light brown oil staining; friable, bright yellowish white small to pinpoint pops in the raw mud; slight sheen whole washing samples; 99-100% bright yellow sample fluorescence; instant very bright bluish white to yellowish white cut flluorescence with fast strong streaming and blooming; very faint to light straw cut in plain light; the residual ring produces very bright yellowish white to white fluorescence that is colorless to very faint brown in plain light; slight petroleum odor; note that the sandstone has up to 5% glauconite grains. LITHOLOGY: Mudstone/claystone/siltstone 2% Shale 83% Bentonite/calcareous tuff 3% Sandstone 12% DAILY ACTIVITY SU~Y: Pickup new mudmotor and RIH with RRB #3; drill from 7892' to 8768'. REMARKS:.. SERVICES PROVIDED: DML MUDLOGGING and RIGWATCH MONITORING SYSTEM Epoch Personnel on site: 4 Arco Alaska Reps: Don McKelvey/Dave Bumgamer Report By: Craig Silva EPOCH WELL LOGGING, iNC. MORNING REPORT ARCO ALASKA, INC. ALPINE giB Date: 3-10-95 Time: 04:00 04:00 Depth' 8850' YESTERDAY: 8768' Last Casing: 13 3/8" at 1765' 24 Hour Progress: 82' Estimated Pore Pressure: 9.2 DC Exponent: 1.10 ROP Sand: N/A ROP Shale: 40 ft/hr BIT INFORMATION: No. Size Type SIN Jets Interval Ftg 3RR 8.50" HYCALOG DS40HF 16095 2-12's, 2-11's 7892'-8850' 958 DRILLING PARAMETERS: HIGH LOW Rate of Penetration 100.0 at 8837' 0.9 at 8769' To rq u e 454 at 8768' 354 at 8788' Weight on Bit 19 at 8832' 3 at 8821' Rotary RPM 255 at 8772' 216 at 8770' Pump Pressure 2569 at 8758' 1664 at 8770' DRILLING MUD REPORT: Report Depth: 8850' MW 10.0 ViS 40 PV 13 YP 14 GELS 3/14 FL SOL 12.0 OIL 0 SD Tr MBT 28.0 pH 8.9 CI- Hours Condition 22.95 2-2-NO-A-X-1-NO-TD AVERAGE 39.8 fi/hr 413 amp 7 Klbs 250 rpm 2377 psi 4.6 FC 2 300 Ca+ 40 GAS SUMMARY: HIGH LOW AVERAGE Total Ditch Gas (units) 31.5 at 8789' 7.0 at 8832' 19.3 units Total Cuttings Gas (units) 28 at 8790' 20 at 8850' 23.5 units Methane (C-1) (ppm) 4954 at 8789' 1003 at 8832' 2948 ppm Ethane (C-2) 267 at 8755' 62 at 8832' 167 ppm Propane (C-3) 191 at 8755' 45 at 8832' 119 ppm Butane (C-4's) 124 at 8738' 21 at 8823' 64 ppm Pentane(C-5's) 85 at 8732' 8 at 8850' 24 ppm Background Gas: 10 units Trip Gas: 505 units at 8850' Connection Gas: units at Wiper Gas: units at OIL SHOWS: None LITHOLOGY: Shale 84% Calcareous tuff 2% Mudstone/claystone/siltstone 12% Sandstone 2% DAILY ACTIVITY SUMMARY: Drill from 8768' to 8850'(T.D.); spot hi vis pill and circulate all the around; POOH; unload neutron source; download LWD tool; lay down PDC bit, mudmotor and Sperry LWD tool; rig up wireline; start running E-log (DSl, LDT,CNL,GR,AM); hung up at 7342'; work free; POOH; rig down; pick up drill bit and RIH to bottom; circulate and clean hole. REMARKS:.. SERVICES PROVIDED: DM[, MUDLOGGING and RIGWATCH MONITORING SYSTEM Epoch Personnel on site: 4 Arco Alaska Reps: Don McKelvey/Dave Bumgamer Report By: Craig Silva ARCO ALASKA INC. ALPINE NO. 113 DRILLING TIME SCHEDULE DEPTH VS TIME 0 -2 -4 -6 -8 -10 DEPTH (THOUSANDS) SET CEMENT KICK OFF PLUG, TOP PLUG AT 1645' .......... ~0C~i ................................. ......................... _'~_~ .... aU_N _E-_L06s _AT_ _TOT_A.L _DEPTH__. TOTAL DEPTH: 8850' 0 1 2 3 4 5 6 7 8 9 10 11 12 13 DAYS 3-01-95 to 3-10-95 EPOCH WELL LOGGING INC. ARCO ALASKA INC. ALPINE NO. lB FOOTAGE PER DAY FO0 TAG E 2,000 1,500 1,000 5OO 0 0 3-01-95 to 3-10-95 2 4 6 8 10 DAYS EPOCH WELL LOGGING INC. 06 i 2,,'" .,, ,::1 '"i 't c h :s a r'n I::' i e s r' e q u '1 r"ed? ~ no .,a, nd r'ece'i'ved? ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Thomas W. McKay, P.E. Senior Drilling Engineer R E C E IV Kuparuk Drill Site Development ATO 1202 Phone 265-6890 M~ ~ 9 ~9~ Fax 265-6224 Alaska 0il & Gas Cons. comrni~sio~ Anchorage March 18, 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: Weekly Operations Report Summary Alpine #1B Completion & Production Well Test APl #50-103-20211-02 Permit No. 95-20 "TIGHT HOLE" Gentlemen: Please find attached the weekly operations summary for the ARCO Alpine No. 1B for the period of March 11 through March 18, 1996. This well has been production flow tested off-rig the past couple of weeks. This week's operations included downhole fluid sampling operations followed by well suspension operations. A sand plug was placed across the test perforations, with a cement plug being placed above the sand plug to suspend the well. Test equipment was rigged down and demobilized. Final suspension operations are currently underway. 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 265-6890. Sincerely, Thomas W. McKay, P.E. Senior Drilling Engineer Kuparuk Drill Site Development ARCO Alaska, Inc. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Date' 3/18/96 .ECEIVED m~co ALASKA ZNCO~O~TED MAR 1 9 199t~ Page: 1 WELL SUMNLARY REPORT Alaska Oil & Gas Cons. Commission Anchorage WELL:Alpine %lB RIG'NO RIG WELL ID- AX9323 AFC' AX9323 -- STATE:ALASKA AREA/CNTY' NORTH SLOPE WEST FIELD' WILDCAT SPUD: START COMP' BLOCK: FINAL' TIGHT HOLE API NUMBER: 50-103-20211-02 03/11/96 (33) TD' 8850'( SUPV:MEE 03/12/96 (34) TD' 8850'( SUPV:MEE o) o) MW: PV/YP: APIWL: RIGGING DOWN TEST EQUIPMENT Ran GR-CCL-PTS-PFS. Obtained 3 bottom hole fluid samples in 3 runs w/well SI. POH w/Petredat. Tested tubing to 3500 psi -OK. Purged separatro w/N2. Flushed flowline and separ- ator w/20 bbls diesel followed by methanol. RD test equip- ment. MW: PV/YP: APIWL: RIGGING DOWN HES TEST EQUIPMENT Rigged down HES equipment. Disconnected hoses and manifold from flowback tanks. 03/13/96 (35) TD: 8850'( SUPV:SDB 03/14/96 (36) TD' 8850'( SUPV:SDB 03/15/96 (37) TD' 8850'( SUPV'SDB 03/16/96 (38) TD: 8850'( SUPV:SDB 03/17/96 (39) TD: 8850'( SUPV:SDB 03/18/96 (40) TD: 8850'( SUPV'SDB o) o) o) o) o) o) MW: PV/YP' APIWL' RIGGING DOWN HES TEST EQUIPMENT Rigged down HES equipment. Begin breaking down and racking up 3" hardline. MW: PV/YP- APIWL: RIGGING DOWN HES TEST EQUIPMENT Rigged down HES equipment. Cont. breaking down and racking up 3" hardline. Lay down flare. Lay down stairs on tanks. MW: PV/YP: APIWL: SUSPEND WELL Safety stand down meeting with all personnel. Pressure test lubricator to 3000%. RIH w/TEL and swage. Displace tubing with diesel. Tag fill at 8616' WLM (8622' MD-RKB). This is effective PBTD. Making preparations for upcoming coil tubing suspension operation.e MW: PV/YP: APIWL: SUSPEND WELL Held safety meeting. Test BOP's to 4000%. Open up well. SI well. Pump sand. Wait for sand to settle out. Secure well. MW: PV/YP' APIWL' SUSPEND WELL Weather below minimus for coil work. Standby for weather. MW' PV/YP' APIWL' WAIT ON CEMENT Held safety meeting. Lay in cement plug up to 8205' Secure well. WOC. Date' 5/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT ..... Page' 1 WELL:Alpine %lB RIG:NO RIG WELL ID' AX9323 AFC- AX9323 STATE:ALASKA AREA/CNTY- NORTH SLOPE WEST FIELD: WILDCAT SPUD: START COMP' BLOCK: FINAL' TIGHT HOLE API NUMBER: 50-103-20211-02 02/8/96 (1) TD' 8850'(0) SUPV:MEE 02/09/96 (2) TD: 8850'( 0) SUPV:MEE 02/10/96 (3) TD' 8850 ' ( 0) SUPV: FlEE 02/11/96 (4) TD: 8850'( 0) SUPV:MEE 02/12/96 (5) TD: 8850'( SUPV:MEE 0) 02/13/96 ( 6) TD' 8850'( 0) SUPV:MEE 02/14/96 (7) TD: 8850'( 0) SUPV:SDB 02/15/96 (8) TD: 8850'( 0) SUPV:SDB/GTG 02/16/9~i ( 9) TD' 8850 ' ( 0) SUPV: SDB/MBM MW- 10.6 PV/YP: 0/ 0 RU HES TEST EQUIPMENT HIRU Nabors 22E camp accommedatiens. APIWL: 0.0 MW: 10.6 RIGGING UP TEST EQUIPMENT Continuing to rig up. PV/YP- 0/ 0 APIWL: 0.0 MW' 10.6 PV/YP: 0/ 0 APIWL: 0.0 RIGGING UP TEST EQUIPMENT 7" SICP 0 psi. 7" x 13-3/8" SICP 850 psi. Bled off 7" x 13-3/8" SCIP from 850 to 250 psi. MW' 10.6 PV/YP' 0/ 0 APIWL' 0.0 RIGGING UP TEST EQUIPMENT ?" SICP 0 psi. 7" x 13-3/8" SICP 300 psi. Bled off 7" x 13-3/8" SICP from 300 to 90 psi. MW- 10.6 PV/YP- 0/ 0 APIWL' 0.0 RIGGING UP TEST EQUIPMENT Finished making up flow lines. Made up test tank manifold & hoses. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 RIGGING UP TEST EQUIPMENT Connected test tank outlet lines. Connected flare stack to hardline. MW' 10.6 PV/YP' 0/ 0 APIWL' 0.0 RIG UP TEST EQPT./NABORS 3S Nabors Rig 3S arrived on location. Spot rig over well. MW- 10.6 PV/YP: 0/ 0 APIWL: 0.0 NU BOPS Raise derrick. Accept rig at 1800 hrs. on 2/14/96. Hold environmental and safety orientation meeting. ND dry hole tree. Install test plug & RILDS. NU Nabors 13-5/8" 5M BOPs. MW' 10.6 PV/YP' 0/0 APIWL' 0.0 WAITING ON PARTS FOR BOP'S Continue to NU BOPs. Testing BOPs. Annular preventer will Date: 3/25/96 ARCO ALASKA INCORPORATED WELL SUPPLA/~Y REPORT Page' 1 WELL:Alpine %lB RIG:NO RIG WELL ID: AX9323 AFC' AX9323 -- STATE: ALASKA AREA/CNTY- NORTH SLOPE WEST FIELD' WILDCAT SPUD' START COMP' BLOCK' FINAL' TIGHT HOLE AP1 NUMBER' 50-103-20211-02 03/18/96 (40) TD: 8850'( SUPV:SDB 0) MW: PV/YP: APIWL: WAIT ON CEMENT Held safety meeting. Lay in cement plug up to 8205' Secure well. WOC. 03/19/96 (41) TD' 8850'( SUPV'SDB o) MW: PV/YP' APIWL' SUSPEND WELL Wait on cement. Held safety meeting. RIH w/1.75" coil. Pump seawater. Tag cement top at 8248'. Pump diesel. No flow from well. SI and secure well. 03/20/96 (42) TD' 8850'( SUPV'MEE 0) MW: PV/YP: APIWL: PREP TO CEMENT 7" X 13-3/8" ANN. Held safety meeting. RIH w/blanking plug and set in XN nipple @ 8141' WLM. POOH. Pressure tested 3.5" tubing to 3000 psi - OK. 03/21/96 (43) TD: 8850'( SUPV'MEE o) MW: PV/YP: APIWL: WOC Held safety meeting. Pressure tested lines to 4500 psi. Pressure tested 3.5" tubing to 4000 psi. Pressure tested 3.5" x 7" annulus to 4000 psi. Cemented 7" x 13-3/8" annulus. WOC. 03/22/96 (44) TD: 8850'( SUPV'MEE o) MW: PV/YP: WOC RD test equipment and mobilized. APIWL' 03/23/96 (45) MW: PV/YP: APIWL: TD: 8850' ( 0) FINAL REPORT SUPV:MEE RD test equipment & mobilized to move. Pressure tested 7" x 13-3/8" annulus to 1600 psi for 30 minutes. OK. Well suspended with all valves closed, BPV in tubing hanger, VR plugs in tubing head and casinghead. End of WellSummary for Well:AX9323 Date: 3/11/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 02/17/96 (10) TD: 8850'( SUPV:SDB/GTG 02/18/96 (11) TD: 8850'( SUPV:SDB/MBM 02/19/96 (12) TD: 8850'( SUPV:SDB/GTG 02/20/96 (13) TD: 8850'( SUPV:SDB/MBM 02/21/96 (14) TD: 8850'( SUPV:GTG 02/22/96 (15) TD: 8850'( SUPV:JLH/ACB 02/23/96 (16) TD: 8850'( SUPV:JLH/ACB 02/24/96 (17) TD: 8850'( SUPV:JLH/ACB 0) 0) 0) 0) 0) 0) 0) 0) not function test (leaking hydraulic fluid). MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 TEST BOPS Begin testing choke manifold and stack. Function test annular. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 WOW Annular element failed on high pressure test. Annular repaired and tested. Ail BOPE tested. Test 7" casing to 3500 psi for 30 minutes. RIH with junk basket. 2 small pieces of rubber retrieved. Suspect piece of rubber element wedged in casing. Wait on weather for slickline unit. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 STANDBY WHILE LINING UP COILED TUBING FISHING UNIT RIH with 3-prong spear & spangs. Stop at 805'. Spud and push junk to bottom. POOH. RIH w/5.95" CCL/GR/JB to bottom. RIH with perf guns. Guns hung up at 4833' Wait for fishing unit. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 N/U ANNULAR BAG Prepare site for coiled tubing unit. Cannot tighten flange on annular. Start nipple up annular bag. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 RD COIL RIH with coil BHA. Latch fish at 4834'. POOH. Getting stuck every 50' to 100'.Work fish to 8500'. Tag PBTD @ 8730' POOH. Stuck. Jar & work pipe. No movement. Pump slick brine to release from overshot. POOH. Freeze protect well from 1250' with diesel. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 RIH W/FISHING ASSY RD Coil unit. Loaded 4-3/4" DC's and fishing equipment. Held safety meeting. RIH w/overshot assy. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 RIH TO LD EXCESS TBG RIH w/overshot assembly. Latched perf guns @ 8430'. POH to 8220'. Guns dragging. Guns broke free @ 8820'. Maybe lost guns. RIH to PBTD @ 8747'. POH w/ gun assy. Tight thru casing collars @ 4600'. Fluid imbalance, circulate diesel to brine @ 1800' OOH w/fish, found 2 centralizer bolts backed out and 4 bolts missing. Left anchor assy on bttm. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 RIH w/TBG RIH 5 stands tbg. Circulated. POH & LD 5 stands 3-1/2" tbg. Run junk basket & 5.95" OD gauge ring. No tight spots. No recovery in JB. Tagged top of gun, Hanger assy @ 8721' RIH packer assy. Set top @ 8179' MD, tail @ 8200'. Load petredat gauge in GLM and test to 1000 psi. Function test Date: 3/11/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 3 02/25/96 (18) TD: 8850'( SUPV:OLH/ACB 02/26/96 (19) TD: 8850'( SUPV:JLH/ACB 02/27/96 (20) TD: 8850'( SUPV:MEE 02/28/96 (21) TD: 8850'( SUPV:SDB 02/29/96 (22) TD: 8850'( SUPV:SDB 03/1/96 (23) TD: 8850'( SUPV:SDB 03/2/96 (24) TD: 8850'( SUPV:SDB 03/3/96 (25) TD: 8850'( SUPV:SDB BOPE and RIH w/completion. 0) MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 ND STACK RIH w/3-1/2" completion. Tagged packer at 8163.57' Displaced tubing with diesel. Tested tbg to 3000 psi for 30 minutes. Tested annulus to 3000 psi for 15 min. Set BPV, ND stack. 0) MW: PV/YP: APIWL: RIG RELEASED ND BOP stack. NU tree. Tested adapter to 5000 psi. Release rig @ 1800 hrs. 2/25/96. 0) MW: PV/YP: APIWL: PERFORATING Safety meeting. Tested flowline, choke skid, heater & separator to 1000 psi. Tested flowline & choke manifold to 5000 psi. RU Schlumberger. Pressure tested lubricator to 3000 psi. Perf'd 8463-8493' (30') 6 spf w/2-1/8" enerjet. Ail shots fired. RIH to perf 2nd interval. 0) MW: PV/YP: APIWL: RIGGING UP COIL UNIT Perf'd interval %2: 8433-8463' 6 spf w/2-1/8" enerjet. Ail shots fired. RIH to perf 3rd interval. Fired perf guns to shoot interval 8406-8433' Ail shots fired. Open up well thru choke to tanks. Flow well. SI well. Rig up coil unit and N2. 0) MW: PV/YP: APIWL: FLOW WELL Held safety meeting. Pressure test coil, hardline, wellhead to 4000%. Pressure test N2 lines to 4000%. Pump N2. SD N2 pumping and continue to flow well. POH w/CT. Flow well. 0) MW: PV/YP: APIWL: RECORDING DOWNHOLE PRESSURE DATA Continue flowing well. Held safety meeting. RIH with well flowing w/PRST, GR, Temp, Press, Continuous Spinner. Sting PRST into 'X' profile at 8069' Flow well while recording downhole and surface pressures. 0) 0) MW: PV/YP: APIWL: PULL PLUG FROM 'XN' NIPPLE Continue to flow well while recording BHP and surface pressure. Shift PRST tool to shut in well downhole. Record and analyze PBU data. RIH w/1-7/8" tool string and 2.73" swedge. Displace tubing with diesel. RIH to set 2.81" positive plug in 'XN' nipple. RIH w/kickover tool. Latch Petradat. Pressure up tubing. Pull Petradat. Tbg pressure dropped to 1100%, 7" pressure came up from 50% to 250%. POOH. Dropped Petredat while POOH. RIH w/2.73" LIB. Set down at 8123' WLM. POOH. MW: PV/YP: APIWL: WAIT ON FRAC GEL TO BREAK RIH with pulling tool. Latch plug and release from 'XN' nipple. POOH w/plug. Prepare to frac well. Pump breakdown, 03/4/96 (26) TD: 8850'( SUPV:SDB 03/5/96 { 27) TD: 8850'( SUPV:SDB 03/6/96 (28) TD: 8850'( SUPV:MEE 03/7/96 (29) TD: 8850'( SUPV:MEE 03/8/96 (30) TD: 8850'( SUPV:MEE 03/9/96 (31) TD: 8850'( SUPV:MEE 03/10/96 ( 32) TD: 8850'( SUPV:MEE 03/11/96 (33) TD: 8850'( SUPV:HEE 03/12/96 (34) TD: 8850'( SUPV:MEE o) o) 0) 0) 0) 0) 0) 0) 0) step rate, conditioning and data frac. Pump frac. Flushed to completion. Sand in place at 0200 hrs. Secure well. MW: PV/YP: APIWL: POST FRAC FLOWBACK Leave well SI while waiting for frac gel to break in formation. Flow back well thru choke into flowback tanks to clean up well before sending flow thru test facilities. MW: PV/YP: APIWL: FLOW WELL TO TEST FACILITIES Continue to flow well to tanks in order to flowback frac fluids. Open up well to test facilities. Flow well and record data. MW: PV/YP: APIWL: FLOW TESTING WELL Flowed well through test separator 24 hours. MW: PV/YP: APIWL: FLOW TESTING WELL Flowed well through test separator 24 hours. MW: PV/YP: APIWL: FLOW TESTING WITH SRO Flowed tested well through test separator 15 hours. RIH w/i-ii/16" GR-CCL to 8600' while flowing to test separator. Continued to flow test well. RIH w/PRST tool while flowing well. Flowed well to test separator with surface readout of BHT and BHP via PRST. MW: PV/YP: APIWL: FLOW TESTING Flowed tested well through test separator 3 hours monitoring flowing BHP w/SRO. SI downhole w/PRST monitoring pressure buildup w/SRO. Opened PRST & flow tested 10 hours to test separator to condition for sampling. Monitored flowing BHP w/SRO. MW: PV/YP: APIWL: RIH W/E-LINE FLUID SAMPLER Flowed tested well through test separator hours to condition for downhole sampling. Monitored flowing BHP w/Schlumberger PRST SRO. Si well @ choke. POH w/PRST. Left well SI @ choke to condtion wellbore fluids for downhole samples. RIH w/GR-CCL-PTS-PFS. MW: PV/YP: APIWL: RIGGING DOWN TEST EQUIPMENT Ran GR-CCL-PTS-PFS. Obtained 3 bottom hole fluid samples in 3 runs w/well SI. POH w/Petredat. Tested tubing to 3500 psi -OK. Purged separatro w/N2. Flushed flowline and separ- ator w/20 bbls diesel followed by methanol. RD test equip- ment. MW: PV/YP: APIWL: RIGGING DOWN HES TEST EQUIPMENT Rigged down HFS equipment. Disconnected hoses and manifold from flowback tanks. 03/13/96 (35) TD: 8850'( SUPV:SDB o) MW: PV/YP: APIWL: RIGGING DO~ HES TEST EQUIPMENT ~ Rigged down HES equipment. Begin breaking down and racking up 3" hardline. 03/14/96 (36) TD: 8850'( SUPV:SDB o) MW: PV/YP: APIWL: RIGGING DOWN HES TEST EQUIPMENT Rigged down HES equipment. Cont. breaking down and racking up 3" hardline. Lay down flare. Lay down stairs on tanks. 03/15/96 (37) TD: 8850'( SUPV:SDB 0) MW: PV/YP: APIWL: SUSPEND WELL Safety stand down meeting with all personnel. Pressure test lubricator to 3000%. RIH w/TEL and swage. Displace tubing with diesel. Tag fill at 8616' WLM (8622' MD-RKB). This is effective PBTD. Making preparations for upcoming coil tubing suspension operation.e 03/16/96 (38) TD: 8850'( SUPV:SDB 0) MW: PV/YP: APIWL: SUSPEND WELL Held safety meeting. Test BOP's to 4000%. Open up well. SI well. Pump sand. Wait for sand to settle out. Secure well. 03/17/96 (39) TD: 8850'( SUPV:SDB o) MW: PV/YP: APIWL: SUSPEND WELL Weather below minimus for coil work. Standby for weather. 03/18/96 (40) TD: 8850'( SUPV:SDB o) MW: PV/YP: APIWL: WAIT ON CEMENT Held safety meeting. Lay in cement plug up to 8205' Secure well. WOC. 03/19/96 (41) TD: 8850'( SUPV:SDB 0) MW: PV/YP: APIWL: SUSPEND WELL Wait on cement. Held safety meeting. RIH w/1.75" coil. Pump seawater. Tag cement top at 8248'. Pump diesel. No flow from well. SI and secure well. 03/20/96 (42) TD: 8850'( SUPV:MEE 0) MW: PV/YP: APIWL: PREP TO CEMENT 7" X 13-3/8" ANN. Held safety meeting. RIH w/blanking plug and set in XN nipple @ 8141' WLM. POOH. Pressure tested 3.5" tubing to 3000 psi - OK. 03/21/96 (43) TD: 8850'( SUPV:MEE o) MW: PV/YP: APIWL: WOC Held safety meeting. Pressure tested lines to 4500 psi. Pressure tested 3.5" tubing to 4000 psi. Pressure tested 3.5" x 7" annulus to 4000 psi. Cemented 7" x 13-3/8" annulus. WOC. 03/22/96 (44) TD: 8850'( SUPV:MEE 0) MW: PV/YP: WOC RD test equipment and mobilized. APIWL: 03/23/96 (45) TD: 8850'( SUPV:MEE 0) MW: PV/YP: APIWL: FINAL REPORT RD test equipment & mobilized to move. Pressure tested 7" x 13-3/8" annulus to 1600 psi for 30 minutes. OK. Well suspended with all valves closed, BPV in tubing hanger, VR plugs in tubing head and casinghead. MEMORANDUM TO: David J~~,. Chairman State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 18, 1996 THRU: Blair Wondzell,-~~ P. I. Superv~ FROM: Bobby Fostei~/'" ~' SUBJECT: Petroleum Inspector FILE NO: P991CRDD.doc Well Operations Shut Down ARCO - Exploration PTD # 95-0020 Alpine # 1-B Monday, March 18, 1996: i traveled this date to ARCO's exploration well Alpine # I-B and witnessed the tagging of a cement plug set in the 7" casing to suspend operations of this well until a later date. I arrived at the location and the coil tubing was being rigged up to go in the hole to ,tag the cement. Steve Bradley, ARCO rep., informed me that the sand put in the wellbore to cover the perforations had been tagged at 8,399' giving 6' of sand above the top of the perforations. Steve said he picked the coil tubing up just above the sand and laid a cement plug which I witnessed being tagged with 2,500 pound of weight at 8,248'. The tubing tail is at 8,200' and a blanking plug will be set in the tubing at 8,124' which is 54' above the packer, the well will be circulated out with 10.6 LB/GAL. brine water. The top 1,000' of the tubing will be circulated out with diesel. The 13.375" X 7" casing will be cemented from surface to the casing shoe at 1,765'. Summary: I witnessed the tagging of the "operation shutdown" cement plug set in ARCO's exploration well Alpine #l-B, Attach: ARCO Well Schematic ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Thomas W. McKay. P.E. Senior Drilling Engineer Kuparuk Drill Site Development ATO 1202 Phone 265-6890 Fa.x 265-6224 March 13, 1996 Mr. Blair Wondzell Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1 433 (907) 276-7542 (fax) Re: Proposed Well Suspension Procedure Sundry Notice Form 10-403 Alpine #1 B APl #50-103-20211-02 Permit No. 95-20 "TIGHT HOLE" Gentlemen' Pursuant to your earlier conversation with our staff today, please find attached the Sundry Notice Form 10-403 regarding the suspension request for the above referenced well. For your information, ARCO hopes to begin the suspension operation on March 15, 1996. Please let us know if you have any questions regarding this request. This Form 10- 403 should accompany the information transmitted to your office under cover letter to David Johnston dated March 11, 1996. 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 265-6890. Sincerely, "~ff. ~¢ ~~~ Thomas W. McKay, P.E. Senior Drilling Engineer Kuparuk Drill Site Development ARCO Alaska, Inc. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend ._~ Operation Shutdown _ Re-enter suspended well_ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate Change approved program _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory X Stratigraphic _ Service 4. Location of well at surface 1465' FSL, 2250' FWL, Sec. 1, T11N, R4E, UM At top of productive interval 2002' FNL, 1617' FEL, At effective depth At total depth 2207' FNL, 1522' FEL, Sec 12, T11N, R4E, UM ORIGINAL Sec. 12, T11N, R4E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 6. Datum elevation (DF or KB) Casing Length Structural Conductor 8 0' Surface 1 7 3 5' Intermediate Production 8 8 0 9' Liner Perforation depth: RKB 8~' AbCv¢ SL 7. Unit or Property name N/A 8. Well number ALPINE #1B 9. Permit number 95-20 10. APl number 5o-103-2021 1-02 11. Field/Pool Wildcat %¢: ....... .~! ;~ 8850' feet 7531' feet Size Cemented Measured depth True vertical depth 20" 350 Sx AS I 1 1 0' 1 1 0' 1 3-3/8" 350 Sx AS III & 1 765' 1 765' 650 Sx AS I 7" 235 Sx Class G 8 8 3 9' 7 5 2 2' measured: 8406-8493' MD true vertical: 7150-7225' TVD feet 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# L80 EUE 8rd Modified, Tubing Tail at 8200' WLM RKB Packers and SSSV (type and measured depth): Baker FAB-1 set @ 8179' WLM RKB 13; Attachments Description summary of proposal Proposed suspension procedure and planned wellbore 14. Estimated date for commencing operation (Suspension Date) __ March 15,1996 16. If proposal was verbally approved--..-- Name of approver ~[~¢'£ ~q~r~~I Date approved 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~fned Detailed operation program status diagram BOP sketch 15. Status of well classification as: Oil __ Gas __ Suspended Service Title Senior Drillin~l Enc~ineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity~__ BOP Test Location clearance Mechanical Integrity Test_ --01~:~cl~le~r~-~equire David W, Johnston Approved by the order of the Commission Form 10-403 Rev 06/15/88 IApprov o. 10- 8 ,~,,~proved Copy ~., / ~ ,.--- · -- ' ' ate k.)// ~(~ SUBMIT IN TRIPLICATE 13-3/8" @ 1765' 7"@ 8839' Alpine #1 B 2.81"X nipple @ 1232' 2.81"X nipple @ 8069' 3-1/2" x 1-1/2" MMM Mandrel @ 8108' w/dummy valve 2.75" XN nipple @ 8124' w/blanking plug FAB Packer Tubing Tail @ 8a:Sz~ E'~,o ~/¢ $ Perfs 8406 - 8493' PBD ~ ~:..~¢~..'.~ ~, TCP Hanger @ PBD MEE 3/8/96 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Thomas W. McKay, P.E. Senior Drilling Engineer Kuparuk Drill Site Development ATO 1202 Phone 265-6890 Fax 265-6224 March 11, 1996 Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1 433 (907) 276-7542 (fax) Re: Weekly Operations Report Summary Alpine #1B Completion & Production Well Test APl #50-103-20211-02 Permit No. 95-20 "TIGHT HOLE" Gentlemen' Please find attached the weekly operations summary for the ARCO Alpine No. 1 B for the period of March 4 through March 11, 1996. This well has been production flow tested off-rig the past couple of weeks. This week's operations included flowing back the well following a fracture stimulation treatment, continued flow testing, pressure build up testing, and fluid sampling operations. 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 265-6890. Sincerely, Thomas W. McKay, P.E. Senior Drilling Engineer Kuparuk Drill Site Development ARCO Alaska, Inc. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Date' 3/11/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page' 1 WELL:Alpine %lB RIG:NO RIG WELL ID' AX9323 AFC- AX9323 -- STATE'ALASKA AREA/CNTY' NORTH SLOPE WEST FIELD' WILDCAT SPUD: START COMP' BLOCK' FINAL: TIGHT HOLE AP1 NUMBER: 50-103-20211-02 03/4/96 (26) TD' 8850'( SUPV'SDB 0) 03/5/96 (27) TD' 8850'( SUPV:SDB 0) 03/6/96 (28) TD: 8850'( SUPV'MEE 03/7/96 (29) TD: 8850'( SUPV:MEE 03/8/96 (30) TD: 8850'( SUPV:MEE 0) 0) 03/9/96 (31) TD- 8850'( SUPV:MEE 03/10/96 (32) TD: 8850'( SUPV'MEE 0) 0) 0) MW' PV/YP' APIWL' POST FRAC FLOWBACK Leave well SI while waiting for frac gel to break in formation. Flow back well thru choke into flowback tanks to clean up well before sending flow thru test facilities. MW: PV/YP: APIWL: FLOW WELL TO TEST FACILITIES Continue to flow well to tanks in order to flowback frac fluids. Open up well to test facilities. Flow well and record data. MW' PV/YP' APIWL' FLOW TESTING WELL Flowed well through test separator 24 hours. MW' PV/YP' APIWL: FLOW TESTING WELL Flowed well through test separator 24 hours. MW: PV/YP: APIWL: FLOW TESTING WITH SRO Flowed tested well through test separator 15 hours. RIH w/i-ii/16" GR-CCL to 8600' while flowing to test separator. Continued to flow test well. RIH w/PRST tool while flowing well. Flowed well to test separator with surface readout of BHT and BHP via PRST. MW: PV/YP: APIWL: FLOW TESTING Flowed tested well through test separator 3 hours monitoring flowing BHP w/SRO. SI downhole w/PRST monitoring pressure buildup w/SRO. Opened PRST & flow tested 10 hours to test separator to condition for sampling. Monitored flowing BHP w/SRO. MW: PV/YP: APIWL: RIH W/E-LINE FLUID SAMPLER Flowed tested well through test separator hours to condition for downhole sampling. Monitored flowing BHP w/Schlumberger PRST SRO. Si well @ choke. POH w/PRST. Left well SI @ choke to condtion wellbore fluids for downhole samples. RIH w/GR-CCL-PTS-PFS. Page 2 03/11/96 (33) TD: 8850 ' ( 0) MW: PV/YP' RIGGING DOWN TEST EQUIPMENT APIWL' SUPV:MEE Ran GR-CCL-PTS-PFS. Obtained 3 bettom hole fluid samples in 3 runs w/well SI. POH w/Petredat. Tested tubing to 3500 psi -OK. Purged separatre w/N2. Flushed flewline and separ- ator w/20 bbls diesel fellewed by methanel. RD test equip- ment. End of WellSummary fer Well:AX9323 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Thomas W. McKay, P.E. Senior Drilling Engineer Kuparuk Drill Site Development ATO 1202 Phone 265-6890 Fax 265-6224 March 11, 1996 Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1 433 (907) 276-7542 (fax) Re: Proposed Well Suspension Procedure Alpine #1 B APl #50-103-20211-02 Permit No. 95-20 "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 AAC 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 perfs on top of the sand plugs. This cement plug would be positioned below the packer. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 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 and hydraulic fracturing operations 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 7"x 13-3/8" annulus would be cemented using the downsqueeze method with cement being pumped of sufficient volume to fill the entire annulus down to the 13-3/8" 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 a 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 265-6890. Sincerely, Thomas W. McK . . Senior Drilling Engineer Kuparuk Drill Site Development ARCO Alaska, Inc. Alpine #1 B Proposed Suspension Procedure Procedure' , . . . Following off-rig well testing, and prior to Coiled Tubing Unit (CTU) arrival, 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 AOGCC 24 hours in advance of all pressure testing and well suspension operations. AOGCC has option to observe all 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' , . . . 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. RIH with coiled tubing with 2" or 2.25" cementing / jetting nozzle with no check valve. Circulate diesel at minimum rate while RIH to keep system from freezing at surface. Circulate seawater on choke at high rate. Clean out well to PBTD; if possible, correlating off plugback depth tag. Flag coil at PBTD. Circulate and condition for spotting of sand plug across perforations. Circulate bottoms up. 10. 11. 12. 13. 14. 15. 16. 17. 18. 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 50 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 150' 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 weiqht of kill weight brine to compensate for diesel placed at top of well for fr~eze 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 perfs 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. 19. Rig up Dowell on 7"x 13-3/8" annulus. Pressure test lines to 3000 psi. 20. 21. Pump into 7"x 13-3/8" annulus using kill weight brine. Establish injection rate into 7" annulus. Monitor wellhead guages. Batch mix and pump 15.8 ppg Arcticset I cement into 7" annulus to fill up from 13-3/8" shoe at 1765' to surface. Do not exceed 2000 psi injection pressure while placing cement. 22. 23. 24. 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 material and equipment for season. TWM, 3/11/96 1996 11' 14AM ARCO ALASKA INC tIo, 8009 P, 7/7 , .lpine #lb Proposed $ '.,pension M. 3-1/8" 5M FMC Gan IV-A tubing hanger with 3-1/2' Fox pir3 down & 3" iSA BPV Profile L. 3-1/2" 9.3#, L-a0 EUE 8rd Mod tbg to hanger 13-3/8" casing @ 1765' CONFIDENTIAL K. 3-1/2" OTIS 'X' Nipple 2.813" ID Selective Profile @ 1232' MD NOTES: 1. Plug will be set in 'XN' Nipple at 8124' MD RKB 2. Kill weight brine will be placed in tubing and tubing annulus, plus above cement plug below packer. 3. Non-'freezing diesel "caps" will be placed in top 1000' o! tubing and tubing annulus. Brine weight will be increased to compensate for diesel caps. 4. 7" x 13-3/8" annulus will be filled with cement, 7" 29# L-80 J, 3-1/;? OTIS 'X' Nipple 2.813" iD Selective ProtJ]e @ 8069' MD I. 1 jt 3-1/2" J-55 EUE 8rd MOD zbg H, 3-1/2" x 1-1/2" ,Damco MMM mandrell (GI_M #1) with 48/64" circ valve and TG latch. Handling pups installed on mandrel: 6' L-80 on top & 4' J-55 on bottom' MandreJ set @ 8108' MD G. 3-1/2" OTIS 'X.N' nipple 2,75" ID/2,75" NOGO profile @ B124' MD F, 3-1/2" Baker 'GBH-22' Locator seal assembly with 10' seals (4.0" OD) @ 8163' MD E. Baker °FAEI-I' permanent packer 3-1/2' X 7" @ 8164' MD RKB (8179' WLM) D. Baker Seal Bore Extension, 80-40, @ 8167' MO C. XO 5" LTC x 4.-1/2" EUE @ 8177' MD B. Pup jt 4-1/2" x 6,2' 12,6# LB0 EUE 8rd Mod @ 6178' MD A. Wireline Entry Guide 4.1/2" EUE @ 8184' MD 150' cement plug above sand plug Sand plug from PBTD up to 50' above top peal d..4 Sand Peris 8463-8493, 8433-8463, 8406-8433' MD PBTD @ 8721' WLM, top of fish (pad guns) TD @ 8850', 7" shoe @ 8839' TWM, 3/11/96 . lpine #lB Suspensi(-,, - Actual N. 3" 5M Master Valve CONFIDENTIAL M. 3-1/8" 5M FMC Gen IV-A tubing hanger with 3-1/2" Fox pin down & 3" ISA BPV Profile L. 3-1/2" 9.3#, L-80 EUE 8rd Mod tbg to hanger K. 3-1/2" OTIS 'X' Nipple 2.813" ID Selective Profile @ 1232' MD 13-3/8" casing @ 1765' NOTES: 1. Wireline blanking plug set in XN nipple at 8124' MD RKB 2.10.6 lb/gal kill weight brine placed in tubing and tubing annulus. 3. Non-freezing diesel "caps" placed in top 1000' of tubing and tubing annulus. 4.7" x 13-3/8" annulus was filled with cement. 5. Back pressure valve installed in tubing hanger. 6. VR plug installed in tubinghead annulus valve outlet. 7" 29# L-80 J. 3-1/2" OTIS 'X' Nipple 2.813" ID Selective Profile @ 8069' 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 @ 8108' MD G. 3-1/2" OTIS 'XN' nipple 2.75" ID/2.75" NOGO profile @ 8124' MD F. 3-1/2" Baker 'GBH-22' Locator seal assembly with 10' seals (4.0" OD) @ 8163' MD E. Baker 'FAB-I' permanent packer 3-1/2" X 7" @ 8164' MD RKB (8179' WLM) D. Baker Seal Bore Extension, 80-40, @ 8167' MD C. XO 5" LTC x 4-1/2" EUE @ 8177' MD B. Pup jt 4-1/2" x 6.2' 12.6# L80 EUE 8rd Mod @ 8178' MD A. Wireline Entry Guide 4-1/2" EUE @ 8184' MD Tagged top of cement plug at 8248' (151' cement plug) Tagged top of sand plug at 8399' (7' above perfs) J-4 Sand Perfs 8406-8493 MD PBTD @ 8721' WLM, top of fish (perf guns) TD @ 8850', 7" shoe @ 8839' FJ 4/15/96 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Thomas W. McKay, P.E. Senior Drilling Engineer Kuparuk Drill Site Development ATO 1202 Phone 265-6890 Fax 265-6224 March 4, 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' Weekly Operations Report Summary Alpine #1B Completion & Production Well Test APl #50-103-20211-02 Permit No. 95-20 "TIGHT HOLE" Gentlemen- Please find attached the weekly operations summary for the ARCO Alpine No. 1B for the period of February 26 through March 4, 1996. This well has recently been perforated and production flow tested off-rig. This week's operations included perforating, flow testing and stimulating the well for continued production flow testing. 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 265-6890. Sincerely, Thomas W. McKay, P.E. Senior Drilling Engineer Kuparuk Drill Site Development ARCO Alaska, Inc. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Date: 3/4/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:Alpine #lB RIG:NO RIG WELL ID: AX9323 AFC: AX9323 -- STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: WILDCAT SPUD: START COMP' BLOCK: FINAL: TIGHT HOLE AP1 NUMBER: 50-103-20211-02 02/26/96 (19) TD: 8850'( SUPV:JLH/ACB 02/27/96 (20) TD: 8850'( SUPV:MEE 02/28/96 (21) TD: 8850'( SUPV:SDB 02/29/96 (22) TD: 8850'( SUPV:SDB 03/1/96 (23) TD' 8850'( SUPV:SDB 03/2/96 (24) TD: 8850'( SUPV:SDB 0) MW: PV/YP: APIWL: RIG RELEASED ND BOP stack. NU tree. Tested adapter to 5000 psi. Release rig @ 1800 hrs. 2/25/96. 0) MW: PV/YP: APIWL: PERFORATING Safety meeting. Tested flowline, choke skid, heater & separator to 1000 psi. Tested flowline & choke manifold to 5000 psi. RU Schlumberger. Pressure tested lubricator to 3000 psi. Perf'd 8463-8493' (30') 6 spf w/2-1/8" enerjet. Ail shots fired. RIH to perf 2nd interval. 0) MW: PV/YP: APIWL: RIGGING UP COIL UNIT Perf'd interval %2: 8433-8463' 6 spf w/2-1/8" enerjet. Ail shots fired. RIH to perf 3rd interval. Fired perf guns to shoot interval 8406-8433'. Ail shots fired. Open up well thru choke to tanks. Flow well. SI well. Rig up coil unit and N2. 0) MW: PV/YP: APIWL: FLOW WELL Held safety meeting. Pressure test coil, hardline, wellhead to 4000%. Pressure test N2 lines to 4000%. Pump N2. SD N2 pumping and continue to flow well. POH w/CT. Flow well. 0) MW: PV/YP: APIWL: RECORDING DOWNHOLE PRESSURE DATA Continue flowing well. Held safety meeting. RIH with well flowing w/PRST, GR, Temp, Press, Continuous Spinner. Sting PRST into 'X' profile at 8069'. Flow well while recording downhole and surface pressures. 0) MW: PV/YP: APIWL: PULL PLUG FROM 'XN' NIPPLE Continue to flow well while recording BHP and surface pressure. Shift PRST tool to shut in well downhole. Record and analyze PBU data. RIH w/1-7/8" tool string and 2.73" swedge. Displace tubing with diesel. RIH to set 2.81" positive plug in 'XN' nipple. RIH w/kickover tool. Latch Petradat. Pressure up tubing. Pull Petradat. Tbg pressure dropped to 1100%, 7" pressure came up from 50% to 250%. POOH. Dropped Petredat while POOH. RIH w/2.73" LIB. Set down at 8123' WLM. POOH. Date: 3/4/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 03/3/96 (25) TD: 8850'( 0) MW: PV/YP: WAIT ON FRAC GEL TO BREAK SUPV:SDB RIH with pulling tool. Latch plug and release from 'XN' nipple. POOH w/plug. Prepare to frac well. Pump breakdown, step rate, conditioning and data frac. Pump frac. Flushed to completion. Sand in place at 0200 hrs. Secure well. 03/4/96 (26) MW: PV/YP: APIWL: TD: 8850' ( 0) POST FRAC FLOWBACK SUPV:SDB Leave well SI while waiting for frac gel to break in formation. Flow back well thru choke into flowback tanks to clean up well before sending flow thru test facilities. End of WellSummary for Well:AX9323 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Thomas W. McKay, P.E. Senior Drilling Engineer Kuparuk Drill Site Development ATO 1202 Phone 265-6890 Fax 265-6224 February 26, 1996 Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1 433 (907) 276-7542 (fax) Re' Weekly Operations Report Summary Alpine #1B Completion & Production Well Test APl #50-103-20211-02 Permit No. 95-20 "TIGHT HOLE" Gentlemen' Please find attached the weekly operations summary for the ARCO Alpine No. lB for the period of February 19 through February 26, 1996. This well has recently been completed and prepared for an off-rig production well test. This week's operations included rigging up test equipment, and the running of tubing and a production packer in the well. The well was then secured and freeze protected for an off rig production test scheduled in the next few days. 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 265-6890. Sincerely, Thomas W. McKa~Y,~,E. Senior Drilling Engineer Kuparuk Drill Site Development ARCO Alaska, Inc. f:EB 27 1996 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Date' 2/26/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page- 1 WELL:Alpine #lB RIG:NO RIG WELL ID: AX9323 AFC: AX9323 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: WILDCAT SPUD' START COMP: BLOCK: FINAL: TIGHT HOLE API NUMBER: 50-103-20211-02 02/19/96 (12) TD: 8850'( SUPV'SDB/GTG 02/20/96 (13) TD: 8850'( SUPV:SDB/MBM 02/21/96 (14) TD' 8850'( SUPV'GTG 02/22/96 (15) TD: 8850'( SUPV:JLH/ACB 0) 02/23/96 (16) TD: 8850'( SUPV:JLH/ACB 0) 02/24/96 (17) TD' 8850'( SUPV:JLH/ACB 0) 0) 0) 0) MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 STANDBY WHILE LINING UP COILED TUBING FISHING UNIT RIH with 3-prong spear & spangs. Stop at 805'. Spud and push junk to bottom. POOH. RIH w/5.95" CCL/GR/JB to bottom. RIH with perf guns. Guns hung up at 4833' Wait for fishing unit. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 N/U ANNULAR BAG Prepare site for coiled tubing unit. Cannot tighten flange on annular. Start nipple up annular bag. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 RD COIL RIH with coil BHA. Latch fish at 4834'. POOH. Getting stuck every 50' to 100'.Work fish to 8500'. Tag PBTD @ 8730' POOH. Stuck. Jar & work pipe. No movement. Pump slick brine to release from overshot. POOH. Freeze protect well from 1250' with diesel. MW' 10.6 PV/YP: 0/ 0 APIWL' 0.0 RIH W/FISHING ASSY RD Coil unit. Loaded 4-3/4" DC's and fishing equipment. Held safety meeting. RIH w/overshot assy. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 RIH TO LD EXCESS TBG RIH w/overshot assembly. Latched perf guns @ 8430' POH to 8220'. Guns dragging. Guns broke free @ 8820'. Maybe lost guns. RIH to PBTD @ 8747'. POH w/ gun assy. Tight thru casing collars @ 4600'. Fluid imbalance, circulate diesel to brine @ 1800'.~OOH w/fish, found 2 centralizer bolts backed out and 4 bolts missing. Left anchor assy on bttm. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 RIH w/TBG RIH 5 stands tbg. Circulated. POH & LD 5 stands 3-1/2" tbg. Run junk basket & 5.95" OD gauge ring. No tight spots. No recovery in JB. Tagged top of gun, Hanger assy @ 8721'. RIH packer assy. Set top @ 8179' MD, tail @ 8200'. Load petredat gauge in GLM and test to 1000 psi. Function test BOPE and RIH w/completion. FEB 2 ? 1 96 Aiask¢ Oi~ & Ges Cons. Commission Ar~cho,~'age Date: 2/26/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 02/25/96 (18) TD: 8850'( SUPV:JLH/ACB 0) MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 ND STACK RIH w/3-1/2" completion. Tagged packer at 8163.57' Displaced tubing with diesel. Tested tbg to 3000 psi for 30 minutes. Tested annulus to 3000 psi for 15 min. Set BPV, ND stack. 02/26/96 (19) MW: PV/YP: APIWL: TD: 8850'( 0) RIG RELEASED SUPV:JLH/ACB ND BOP stack. NU tree. Tested adapter to 5000 psi. Release rig @ 1800 hrs. 2/25/96. End of WellSummary for Well:AX9323 ISpill Response Trailet Camp Telecommu nica~i( Trailers 0 0 0 0 0 Seperator Choke & Scrubber Flow Line L Alpine #1 B Generators I I I I I I I L-,, ,--, Flow Line Flare Stack M. Elis 2/24/96 N t ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Thomas W. McKay, P.E. Senior Drilling Engineer Kuparuk Drill Site Development ATO 1202 Phone 265-6890 Fax 265-6224 February 20, 1996 Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1 433 (907) 276-7542 (fax) Re; Weekly Operations Report Summary Alpine #1B Completion & Production Well Test APl #50-1 03-20211-02 Permit No. 95-20 "TIGHT HOLE" Gas Cons. Commi.~tor~ A~cho~rage Gentlemen- As per the APD and Sundry approval for this well, please find attached the weekly operations summary for the ARCO Alpine No. lB for the period of February 8 through February 20, 1996. This well is currently being completed and prepared for an off-rig production well test. This week's operations included rigging up test equipment, and the running of tubing conveyed perforating guns in the well. The well was cased during the spring of 1995, and completion operations are currently underway. A Vertical Seismic Profile ("VSP") was also run in the well prior to the completion operation. 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 265-6890. Thomas W. McKay, P.E. Senior Drilling Engineer Kuparuk Drill Site Development ARCO Alaska, Inc. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Date' 2/20/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page' 1 ~LL'Alpine #lB RIG:NO RIG WELL ID: AX9323 AFC: AX9323 -- STATE:ALASKA AREA/CNTY- NORTH SLOPE WEST FIELD' WILDCAT SPUD' START COMP' BLOCK' FINAL' TIGHT HOLE API NUMBER: 50-103-20211-02 02/8/96 (1) TD: 8850' 0) SUPV:HEE 02/09/96 (2) TD: 88507 SUPV:MEE 02/10/96 (3) TD' 8850' SUPV'MEE 02/11/96 ( 4) TD: 8850' SUPV:HEE 02/12/96 (5) TD' 8850' SUPV:MEE o) 02/13/96 ( 6) TD' 8850'( 0) SUPV'MEE 02/14/96 (7) TD' 8850'( 0) SUPV'SDB 02/15/96 (8) TD' 8850'( 0) SUPV:SDB/GTG 02/16/96 { 9) TD- 8850'( 0) SUPV:SDB/MBH MW: 10.6 PV/YP: 0/ 0 RU HES TEST EQUIPMENT MIRU Nabors 22E camp accommodations. APIWL- 0.0 MW: 10.6 RIGGING UP TEST EQUIPMENT Continuing to rig up. PV/YP' 0/ 0 APIWL' 0.0 MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 RIGGING UP TEST EQUIPMENT 7" SICP 0 psi. 7" x 13-3/8" SICP 850 psi. Bled off 7" x 13-3/8" SCIP from 850 to 250 psi. MW: 10.6 PV/YP: 0/ 0 APIWL' 0.0 RIGGING UP TEST EQUIPMENT 7" SICP 0 psi. 7" x 13-3/8" SICP 300 psi. Bled off 7" x 13-3/8" SICP from 300 to 90 psi. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 RIGGING UP TEST EQUIPMENT Finished making up flow lines. Made up test tank manifold & hoses. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 RIGGING UP TEST EQUIPMENT Connected test tank outlet lines. Connected flare stack to hardline. MW' 10.6 PV/YP: 0/ 0 APIWL' 0.0 RIG UP TEST EQPT./NABORS 3S Nabors Rig 3S arrived on location. Spot rig over well. MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 NU BOPS Raise derrick. Accept rig at 1800 hrs. on 2/14/96. Hold environmental and safety orientation meeting. ND dry hole tree. Install test plug & RILDS. NU Nabors 13-5/8" 5M BOPs. MW' 10.6 PV/YP' 0/0 APIWL: 0.0 WAITING ON PARTS FOR BOP'S Continue to NU BOPs. Testing BOPs. Annular preventer will Date: 2/20/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 not function test (leaking hydraulic fluid). 02/17/96 (10) TD: 8850'( SUPV:SDB/GTG 0) MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 TEST BOPS Begin testing choke manifold and stack. Function test annular. 02/18/96 (11) TD: 8850'( SUPV:SDB/MBM 0) MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 WOW Annular element failed en high pressure test. Annular repaired and tested. Ail BOPE tested. Test 7" casing te 3500 psi for 30 minutes. RIH with junk basket. 2 small pieces ef rubber retrieved. Suspect piece ef rubber element wedged in casing. Wait on weather for slickline unit. 02/19/96 (12) TD: 8850'( SUPV:SDB/GTG 0) MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 STANDBY WHILE LINING UP COILED TUBING FISHING UNIT RIH with 3-prong spear & spangs. Stop at 805' Spud and push junk to bottom. POOH. RIH w/5.95" CCL/GR/JB to bottom. RIH with perf guns. Guns hung up at 4833'. Wait for fishing unit. 02/20/96 (13) TD: 8850'( SUPV:SDB/MBM 0) MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 N/U ANNULAR BAG Prepare site for coiled tubing unit. Cannot tighten flange en annular. Start nipple up annular bag. End of WellSummary for Well:AX9323 2 3 Gas Co~s. Commi~sio~ ~,-chora9~ bcc: Alpine No. lB Well File T.W. McKay ATO-1202 FEB 2 3 1996 Oi~ & Gas Cor~s. Commi~sio~: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well_ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate Change approved program _ Pull tubing _ Variance _ Perforate X Other X(Completion) 2. Name of Operator ARCO Alaska, Inc. 3. Address Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory X Stratigraphic _ Service 4. Location of well at surface 1465' FSL, 2250' FWL, Sec. 1, T11N, R4E, UM At top of productive interval 2002' FNL, 1617' FEL, At effective depth At total depth 2207' FNL, 1522' FEL, Sec 12, T11N, R4E, UM ORIGINAL Sec. 12, T11N, R4E, UM 12. Present well condition summary Total Depth: measured true vertical 8850' feet 7531 ' feet 6. Datum elevation (DF or KB) RKB 38' Above SL 7. Unit or Property name N/A 8. Well number ALPINE #1B 9. Permit number 95-20 10. APl number 5o-1 03-2021 1 -02 11. Field/Pool Wildcat ~,1~1 V [~iJ feet J AN 2 6 1 J96 Effective depth: measured 8 4 0 7' true vertical 71 51 ' Casing Length Size Structural Conductor 8 0' 2 0" Surface 1 735' 1 3-3/8" Intermediate Production 8 8 0 9' 7" Liner Perforation depth: measured: None feet feet Naska Oit & Gas Cons. Commission Anchorage Cemented Measured depth True vertical depth 350SxASI 110' 110' 350 Sx AS III & 1765' 1765' 650 Sx AS I 235 Sx Class G 8839' 7522' true vertical: None Tubing (size, grade, and measured depth: None Packers and SSSV (type and measured depth): None Plan to resume operations in February 1996 at which time ARCO will run a completion and begin production testing. 13. Attachments Description summary of proposal_ Present well status. Proposed completion 14. Estimated date for commencing operation (Shutdown Date) February 4, 1996 16. If proposal was verbally approved Name of approver Date approved Detailed operation program X BOP sketch -- 15. Status of well classification as: Oil __ Gas __ Suspended Service 7. I hereby ~. i~ cer fy that t e foregoing is true and correct to the best of my knowledge. Signed ur Title Area Drillin~l En~lineer FOR COMMISSION USE ONLY Conditions of appro ify Commission sorep, resentative may witness BOP Test ~ Location clearance __ Date IApproval No. Plug integrity M '~DDroved Copy I ¢'¢ - o/~ Mechanical Integrity Test_ Subseauent form require 10- OPJGINAL SIGNED BY Approved by the order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT II~TRIPI_'IC,~TE Completion & Test Procedure Alpine lB AFC AX-9323 General Information Permit No.: 95-20 (Permit to Drill) 95-048 (Operation Shutdown) API No.: 50-103-20211-02 Geometry: 20"@ 120' 13-3/8" 68 lb/~ L-80, BTC @ 1765' 7" 29 lb/ft, L-80, BTC @ 8839' PBTD +8747 TD @ 7531' TVD TD @ 8850' MD KOP @ 11940' Maximum Angle = 43° @ 7900' Angle @ TD = 30° Average Angle thru J-4 = 31° Status: Complete & Test AFC Expected Cost = Upper Li'mit = Cost to date = Set 7" casing 3/111/95. Bumped plug. Tested 7" 29 lb/ft L-80 Casing to 3000 psi Freeze protected 13-3/8"x7" ann. with 1.87 bbl diesel 3/12/95. Cased hole cement bond logs tagged PBTD @ 8732' (15' above tally PBTD) 3/26/95 No cleanout is required No squeeze is necessary Wellhead is FMC PBU Big Bore Modified Gen IV 13-5/8" 5M Casing Head with 2" 5M Wing Valve w/VR plug 13-5/8" 5Mx13-5/8" 5M Csg Spool w/3" 5M wing w/VR plug 13-5/8" 5Mxll" 5M Tbg Head w/2" 5M wing w/VR Plug Tree is FMC Gen IV 11" 5M x 3-1/8" 5M 11" 9" Acme top, 3-1/2" Fox btm Tbg Hgr with BPV installed Wellbore fluid is 10.6 ppg brine with 38 bbl (1000') diesel cap Objectives: Pressure test 7" casing Run 3-1/2" single completion with gun hanger and permanent packer Perforate J-4 Sand underbalanced using gun hanger Perforation/packer depths reference 3/29/95 SWS USI JAN 2. 6 1996 Alaska Oil & Gas Cons. Commission And~ora[le Completion & Test Procedure Alpine lB AFC AX-9323 Test Prognosis: Tubing: Perforations: Packer Depth: Correlation Log: Perforating Gun: Rathole f/ Base Perf: Reservoir Pressure: Desired Underbalance: _+650 Cushion: Diesel 3.5", 9.3# L-80, EUE 8rd Mod ID = 2.992" DD = 2.867" Burst = 10,160 psi Collapse = 10,530 psi Capacity = 0.0087 bbl/ft 3.5" x 7" Annulus Capacity = 0.0252 bbl/ft 8406'- 8493' (87' MD) 7150' - 7224' (74' TVD RKB) _+8257' MD RKB SWS USI log dated 3/29/95 4 5/8" Vann TCP Guns, 6 SPF 32 gram RDX DP Charges 240' 3255 psi psi JAN ?_6 1996 Alaska Oil & Gas Cons. Commission Anchorage Completion & Test Procedure" Alpine lB AFC AX-9323 Note: Prior to completing the Alpine #lB well, an offset VSP cased hole log survey will be run on the well. I. MIRU Nabors Rig #3S and Nabors 28E satelight camp. Fill pits with I00 bbl of 10.6 ppg brine. Rig up to circulate. 2. Rig up lubricator. Pull BPV. ND dry-hole tree. Remove tbg hanger. NU BOPE. Remove VR plugs from tubing head and 13-5/8" 5Mx13-5/8" 5M middle spool. NU 13-5/8" 5M BOP. 3. Test rams and choke manifold to 3500 psi. Test annular to 3000 psi. Note: (Notify AOGCC 24 hours prior to testing BOPE). 4. Pressure test 7" casing to 3500 psi for 30 min. Record pressure test on chart. Note results on morning report. 5. Pickup and RIH with + 8300' of 3-1/2" 9.3 lb/ft, L-80, ABM EUE tubing. 6. Circulate to displace diesel out of tbg and annulus with 10.6 lb/gal brine. POOH stand back tubing. 7. RU SWS E-line unit. Run gauge ring and junk basket through gun hanger assembly setting depth to +8700' (Wireline TD 8732'). 8. RU and run the following TCP gun assembly on E-line and set the guns with top shot at 8406' MD RKB ( top gun hanger at 8492' MD RKB, see attached schematic). , 7. 6. 5. 4. 3. 2. 1. J-Slot Running Tool Ported Sub Time Delay Firing Head Blank Gun Section 4-5/8" TCP Guns, 6 SPF, 32 GM RDX DP Charges Auto Release Gun Hanger Time Delay Firing Head Ported Bullplug Use GR/casing collar locator to correlate gun setting depth. 9. RU and run the following permanent packer and tubing tail assembly on E-line. o 4. 3. 2. 1. Baker Model FAB-1 Permanent Packer Seal Bore Extension 10' Long, 4-3/4" 8 Stub Acme Pin x Pin XO Sub 4-3/4" 8 Stub Acme Box x 4-1/2" EUE Pin 4-'1/2" Pup Joint 4-1/2" EUE 4-1/2" WL Entry Guide 4-1/2" EUE(10' of seals) Use GR/casing collar locator to correlate packer setting depth. Completion & Test Procedure Alpine lB AFC AX-9323 10. RU and run the following test string assembly. 12. 13. 12. II. 10. 9. 8. 7. 6. 5. . 3. 2. 1. 5-K Tree Tubing hanger 9" Acme x 3-1/2" Fox XO Fox x Eue 3-1/2" Tbg., EUE 8rd to Surface 3-1/2" Otis 'X' Nipple (between 1000 and 1500' MD RKB) (2.81" ID) 3-1/2" Tbg., EUE 8rd 3-1/2" Otis 'X' Nipple (2.81" ID) I Jt 3-1/2" Tbg, EUE 8rd 3-1/2" Tbg Sub 3-1/2" x 1-1/2" Camco MMM GLM (w/ Petredat Gauge in 1-1/2" sidepocket) 3-1/2" Tbg. Sub 3-1/2" OTIS 'XN' Nipple (2.75" ID) I Jt 3-1/2" Tbg, EUE 8rd Seal Locator Sub (10' of seals) 11. Sting into packer. Tag up locator sub on packer and space out so locator sub is 6" above landing point in the packer when tubing hanger is landed in the tubing head. Space out. PU tubing hanger. 12. With the seal assembly unstung, displace the tubing to diesel and freeze protect the well by pumping '100 bbls diesel down the tubing taking returns from the annulus. (Tubing volume to 8300' is 72 bbl and annulus volume to +1000' is 25 bbl). '13. Slowly lower string and land tubing hanger in tubing spool. Run in all lockdown screws. 14. Pressure test annulus to 2500 psi for '15 min. Record pressure test on chart. Bleed off pressure. 116. Install BPV. ND stack. NU tree. Pull BPV. Install test plug. Test tree to 250 and 5000 psi. Test packoff to 5000 psi. Pull test plug. 17. Pressure test tubing to 2000 psi. 18. Rig down and move rig off. txc. v '18. Complete RU of surface test equipment. ,J/~,~i 2__6 l~t~ 19. Hold safety meeting with testing personnel. /~laska Oil & Gas Cons. Commission 20. Pressure tubing to fire the TCP guns. Bleed off surface presst~0arf~wait for guns to fire. The guns will fire approximately 10 minutes after the firing heads are activated. Monitor well for indication of guns firing. 21. After guns fire, slowly open choke and allow well to flow. Flow test well as per instructions from O/A onsite engineer. (Note: if well damage 'is severe and well will not flow at stabilized rate, a fracture stimulation treatment will be performed.) Completion & Test Procedure Alpine lB AFC AX-9323 22. After well testing operations are complete, conduct a multi step rate water injectivity test. 23. Depending on the results of the well test the well may be left completed, suspended or P&A as per AOGCC regulations. ALPINE #1 B WELLBORE SCHEMATIC sHUTDOWN STATUS VR PLUGS INSTALLED WELLHEAD 20" CONDUCTOR AT 120' RKB 16" HOLE 8-1/2" HOLE BRINE 10.6 LB/GAL DIESEL 6.75 LB/GAL CEMENT TD 885O' MD 7531' TVD L 3-1/2" 5000 PSI LOWER TREE ASSEMBLY J BACK PRESSURE VALVE INSTALLED IN TUBING HANGER 1000' DIESEL CAP IN THE 7" CASING 13-3/8" SURFACE CSG AT 1765' RKB JAN 2 6 '1996 Anchorage TOP OF CEMENT +7900' J-4 INTERVAL _+8407'-8493' PBTD 8747' 7" PRODUCTION CSG AT TD +8839' FJ 3/13/95 .,pine #1 B Proposed . mpletion K. 3-1/8" 5M FMC Gen IV tubing hanger with 3-1/2" Fox pin down. 7" 29# L-80 J. 3-1/2" OTIS 'X' Nipple 2.813" ID Selective Profile 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 48/64" ciro valve and TG latch. Handling pups installed on mandrel: 6' L-80 on top & 4' J-55 on bottom G. 3-1/2" OTIS 'XN' nipple 2.75" ID/2.75" NOGO profile F. 3-1/2" Baker 'GBH-22' Locator seal assembly with 10' seals (4.0" OD) E. Baker 'FAB-I' permanent packer 3-1/2" X 7" @ 8260' RKB D. Baker Seal Bore Extension C. XO 4-3/4 Stub Acme x 4-1/2" EUE B. Pup jt 4-1/2" x 15' J-55 BTC 4-1/2" EUE 8rd A. Wireline Entry Guide 4-1/2" EUE Hallibuton TCP Guns on Gun Hanger Assembly J-4 Sand Perfs 8406' - 8493' PBTD @ 8747' TD @ 8850' FJ 1/7/96 State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage AK 99501-3192 The AOGCC releases confidential data to authorized ,employees of the Division of Oil and Gas (DNF~/DOG). Blueline logs and copied reports :are inventoried by prior to release. These confidential ~re then re, s. ponsibility,o.[ the undersigned DNR/,DOG employee. PTD # ~-' - ©~ WELL NAME ~'~r{ j~ ~.. ::~ I L-~ ~ / FORM __PAGES COMMENTS REPORTS PAGES COMMENTS 401 . SURVEY 403 CORE Description _____ Analysis _.___ Conventional SWC 4O7 DWOP . . . PICKS Formation Picks or DSTs Production Tests - _ Geological Markers '~. ! BLUE LINE - RUN IN'II',,ERVAL . SCALE NOTE Mud log , rev 08~03~95 confidnr, doc State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage AK 99501-3192 The AOGCC releases confidential data to authorized employees of the Division of Oil and Gas (DNPJDOG). Biueline logs and copied reports are inventoried by prior to releasE;. These confidential data are then responsibility of the undersigned DNPJDOG employee. PAGE TWO IF NEEDED PTD # c~5-- - ~,.r~ WELL NAME -_. BLUE LINE , RUN .. INTERVAL SCALE NOTE .. ,, Mud log · , DIGITAL DATA RUIN i INTERVAL O/C NOTE ~ ., I i i i I i i ~ ' l ~: ' ' lm9'08/03/95 c~nfidnr, doc ARCO Alaska, Inc. AtlanticRichfieldCompany TO: Alaska Oil & Gas Consveration Commission FROM: Attn.: Robert P. Crandall 3001 Porcupine Dr. Anchorage Alaska 99501 DATE: August 10, 1995 Ms. Kelli A. Thibodeau A'1'O-1466 ARCO Alaska, Inc. 700 G. Street Anchorage, Alaska 99510 (907) 265-6240 The enclosed MWD information has been reprocessed by Sperry for Alpine lB. Please replace and destroy the information sent July 10, 1995. If you have any questions please call me at (907) 265-6240. Kelli ~'~ ~/~/. ~ Alpine 1 B I LDWG Formatted 6" Open Reel 1600 BPI Tape- MPT GRC EWR CNP SFD ROP 6/26/95 as Displayed by Sperry-Sun I Paper Copy LIS Verification Displayed by Sperry-Sun RETURN SIGNED COPY TO: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 / Approved for transmittal by: ,' / / F. M;' Honeycutt Manager, North Ala~'l~a Exploration I OF2 State of Alaska Oil and G~ Conservation Conmfission 3001 Porcupine Drive ga~chorage AK 99501-3192 The Oil and Gas Conservation Conmfission will release comfidential data to authorized state employees of the Depa~unent of Natural Resources. Division of Oil and Gas (DNPdDOG). All data is to be copied and inventoried. These copies and inventory are given to the DNK:DOG employee. The DNIUDOG employee is then responsible for the data as it leaves the premises. Well Permit Number Well Nam. e Iiem Pages Comment Fom~ 40'7 ~ ~ ~ o ~ c4 ~ ~ (__.0 ~). ~'l c~ PTD '~ Formation Picks . ~~ ~ ~~ ~. Daily well operations ~ - Core analysis Core description Production,tests(DSTs) ,, ~.. ~-~'~..C..~.~&. .. . ~ ~ ,., ~ .... ... I Digital data w'eiI log ..... Run #' Intervals "Scale conunents ' , , Mud log I b ~ ¢'r'~ ,,, r~Lf , - -' ,,, ,,, The unde,fgned tm tvO_.OCi employee h~eby accepks r~ a~e l'is't~o,~~d data,/' P,'intname~~ ~Q~.f~~ ' Sight_Q). ~_~~~ Sign MEMORANDUM State of Alaska TO: David Johns. q¢~ Chairman" Alaska Oil and Gas Conservation Commission DATE: July 7, 1995 THRU: Blair Wondzell, 4':J'..a.,.L FILE NO: P. I. Supervisor 7/~zl9~- 199LGGCD.doc John Spaulding,~f~z)..,.v.,...., SUBJECT: FROM: Petroleum Insp.~""-~v Location Clearance AIpine~ tE~ Arco Alaska Inc. Exploration PTD-95-=T8- Friday July 7, 1995: I traveled ~ Alpine 1-A with Arco's environmental technician Larry Brown to inspect the area for location clearance. The wellhead is Still on and is covered by a small shelter. The area around the well is very clean with no apparent damage to the tundra. Due to the water in the area of the wellhead and shelter being more than my leather boots would navigate I did not inspect near the base of the wellhead; from a distance of about 75' everything appeared to be OK with no visible oil sheens. Since the wellhead is still on I can not recommend Alpine 1-A for final surface abandonment. Summary,: I inspected Arco's exploration well Alpine 1-A for location clearance. Attachments: 199LGGCD.XLS Photos STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment / Location Clearance Report ( Title 20 AAC 25, Article 2 ) FILE INFORMATION: Operator: ARCO ALASKA Inc. Address: Surface Location: F L, F L Section 1 ,T 11N ,R 14E ,M Umiat Well Name: Alpine 1-A PTD No.: 95-18 APl No. 50- Unit or Lease Name: Exploration Field and Pool: Downhole P&A Date: 2/28/95 Inspection Date: J 20 AAC 25,125 -ABANDONMENT MARKER: I Approval Date: :Steel Post OD: (4" min) '; Length (10' min.) ft. Height Above Final Grade Level (4' min.) ft. Top of Marker Post Closed With: (Welded, Cmt., Cap), Set: (On Wellhead, Csg, In Cmt) Distance Below Final Grade Level: ft. Side Outlets: All valves and nipples removed ? ~AII openings closed ? With Marker Plate Diameter: "Thickness: "Distance Below Final Grade Level: Marker Plate Attached To: Wellhead Cutoff Csg Other Operator: Well Name: Surface Location: F Section Information Beadwelded Directly to Marker Post or Blind Marker Plate: Unit / Lease Name: Remarks: Inspection Date: PITS: Filled In: L, F L ,T ,R ,M 7/7/95 I ( Note when different from file information) 20 AAC 25.170 - LOCATION CLEANUP: I Approval Date: yes Liners Removed or Buried: N/A Debris Removed: yes SURFACE CONDITION OF PAD AND / OR LOCATION · Contoured ( Rough, Smooth, Contoured, Flat, Compacted ) Clean: yes Type & Quan. of Debris if any remaining on pad and / or location: None TYPE AND CONDITION OF SURROUNDING AREA' Tundra ( Wooded,Tundra,Grass, Brush, Dirt, Gravel,Sand) Clean: yes Type &Quan. of Debris if any remaining on surrounding area · None TYPE AND CONDITION OF ACCESS ROAD AND SURROUNDING AREA: ' Ice ( Dirt, Gravel, Ice, Other) Clean: yes Type & Ouan. of Debris if any remaining on access road or surrounding area · None CLEANUP WORK REMAINING TO BE DONE · None RECOMMENDED FOR APPROVAL OF ABANDONMENT: Yes XXX No ( If "No" See Reason ) Distribution: orig - Well file c - Operator c - Database c- Inspector FI-000 (Rev. 3/93) Reason' FINAL INSPECTION: Yes XXX No INSPECTED BY: John H. Spauldin~ 199LGGCD.XLS DATE: 7/7/95 TO: DATE: ARCO Alaska, Inc. AtlanticRichfieldCompany Alaska Oil & Gas Consveration Commission Attn.: Robert P. Crandall 3001 Porcupine Dr. Anchorage Alaska 99501 FROM: May 25, 1995 Ms. Kelli A. Thibodeau ATO-1466 ARCO Alaska, Inc. · 700 G. Street Anchorage, Alaska 99510 (907) 265-6240 Transmitted herewith is the followinq data concerninq Alpine 1 lA lB Fiord 3 & 3A: REPORTS: EPOCH WELL REPORTS ALPINE lA : q ~-'- ~0 ALPINE lB .................... ,_ FIORD 3 FIORD 3A 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: Approved for transmittal by: F.M. eycutt ' Manager, North Alaska'Exploration RECEIVED MAY 2 ~ 1-395 Alaska Oil & Gas Ce~s. Commiss[0n Anchorage I OF1 TO: DATE: ARCO Alaska, Inc. AtlanficRichfieldComparry Alaska Oil & Gas Consveration Commission Attn.: Robert P. Crandall 3001 Porcupine Dr. Anchorage Alaska 99501 FROM: Ms. Kelli A. Thibodeau ATO-1466 ARCO Alaska, Inc. 700 G. Street Anchorage, Alaska 99510 (907) 265-6240 21, April 1995 Transmitted herewith is the foilowinq data concerninq Alpine 1: AP! # 501032021100 REPORTS: ...... Alpine lA 1 ,,Copy Morning Drilling Reports Alpine 1 B 1 Copy Morning Drilling Reports 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 995'10-0360 (907) 265-6240 RECEIVED APR 2 4 ]995 Alaska 0il & Gas Cons. Comm/ss~on Anchora{-,~ Received by: DATE: Approved for transmittal by: F.M. HoneycUtt Manager, North Alaska Exploration 1 OF1 ARCO Alaska, Inc. Daily Drilling Report ALPINE #lB 2177' D) 412' C~a~or ~ ~ C~ ~ ~ ~ ~o ~ $127,5~ //~ ~ ~ POOL RIG ~6 $127,5~ , ~/ ~at~ ~ ~ L~ C~ Displace hole w/new mud. 13 3/8" ~ 1,765' N/A 1~ ~D ~TA ~ ~A ~D L~ ~TA ~G ~TA ,uu~ LSND U~T 0.00 ~b ~. (2RR) ~1 ~ ~177 D~ 2,1~ ~ 105 ~hz 9.9 ~ ,pH 11.8 ~, 1~25 8.5 U~ 10 P.U.~. 105 S.O.~ 105 v~ 40 s~ ~ 0.0 u~, STC ~C F~a~ SH MUDST Avg ~g 5 ~ Drag 5 pv~ 9/9 ~ 3.00 T~ ~HC ATJ*~D ~ 2 Tm ~ 75 iTm S~ 75 ~,~ ~ 0 ~ 6.00 ~ ~. NC0~ Tg2WH c~ g, ~ ~. I 2 3 ~P:WL 8.4 cc ~, 600 ~m ~ 1800 2177 T~g, ,L~S~, 5.5X12 5.5~2 HTHP 2~ p~ CC O~ % ~, 155' cmt 412 u~ ~G ~PM 60 HTHP ~p~ O~ ~T/AST 3.5 ~5 ~ ~ 0.85 ~PM 212 212 So~d~ 10.0 % ES ~PM 70 6~ S~k ~ ~r~r, 2,~ Ho~v~. 270 bbl P~Vo~. 530 ~1 ~.TFA o~n 13 13 13 ~,~ 163 SL~PPJ~ 375 D~ U~d $23298 ~o~ud $23298 ~ n/a ~1~ ~d 1~ )ate 0400 , .o1, I Su~. No, I 2 3~ 4 5 D~ (MD) 1752 1868 1899 19~ 2089 ~gle 1.2 3.8 5.0 7.8 10.1 Direai~ 124.5 136.2 1~.7 I~A 1~.6 T,V.D, 1752 1868 1899 1993 2087 Ve~ S~, 12.8 15.7 la.0 28.1 42R Sou~ 6.9 10.3 12~ 20A 32R Earn 12.9 16.6 18~ 25.~ 33~ D~ Leg 2.26 4.10 2.~ 2.79 TIME C~ O~mt~ns From ~- ~ 0600-0800 2.0 6 P/U BHA. TI H F 1037'. 0800-1000 2.0 13 Wait on cement. 1000-1030 0.5 6 TIH. 1030-1100 0.5 5 Break circ.,tag cement at 1645', soft F firm. ~ ..... , 3o- 2oo 0.5 5 CBU. 1200-1230 0.5 E Test csg V 1500 psi. OK. APR 2 4 ]995 1230-1700 4.5 2 Drilling firm cement f/1672-1800'. A~sk~ 0il & ~a~ 6~_ 1700-1800 1.0 5 CBU. Anchor~, 1800-1900 1.0 6 TOH, UD 8" DC. 1900-2100 1.0 6 M/U BHA to kickoff, TIH. 2100-2400 3.0 2 Drilling cmt 1800-1940'. Checking for valid tool face. 0000-0200 2.0 2 Drilling to kick off hole, alternate slide/rotate to 2177'. _ 0200-0230 0.5 6 TOH ~ 1775'. 0230-0600 3.5 5 iClean pits, take on new mud, pump 30 bbl sweep and displace hole. ARCO Alaska, Inc. Daily Drilling Report 8 1/2" BIT, 6 3/4" Mach 1C AKO 1.2°, NM STAB, XO, MWD, XO FLT SUB, 3- SpDC, XO, 4-HWDP, DNT JARS, 25 HWDP. OAL= 1070.86' ~HA NO.: I.) nlll;q)e I oo w.~ 11x 5 19.5~ G 41/21F~ prem 1066.39 ~7/9s 5 19.5~ S135 41/21F prem Daily J~ ~ 1~1-~2 DNT 124 Ac~7 (Y/N) I~e Em~yer ~. F~S? (Y~) no I ~ F~ & Wa~r In~ Well: ~te: ' Prate F~l ~ L~ ~a~) F~ ~ (g~) 2M-23 6 BPM 900 " 20422 5030 Volume 393 Mud CPF-1 70 Diesel 700 450 H20 650 Lake 93-12 169 96 Dai~ Volume C~u~e V~ume P~ W~ R~ ~) Po~ Wa~r ~u~ 463 bbls 12783 bbls 100 Lake 93-12 Cua~ Dam W~er Dam Pe~l o yd~ -14 ARCO 1 3/1/95 3/1/95 7ssy~ 16 ~s. CONTRACTOR 35 i~27/95 5t~a~ 5~e ~111 la.or .a~ ~le~ M~ La~ ~a Urla Alpi~ ~1 L~tion -45 °F SERVICE 19 3/~95 ~26/95 Alpine ~1 3/~95 OTHER NO S~n~ [~ ~11 R~ F~ D. C. Bumgarner TO~AL 55 Time H~m C~ O~mtbns From KE Elv[ N~a 0il & Gas ~ons. Commissio~ A~chor~~ Road M~i~t Water Used f/L~ke ~91-23 = 0 bbl ~um= 5100 bbl Road maint Water Used f/Lake ~93-12 = 0 bbl Cum=14900 bbl Road Maint Water Used f/Lake ~91/16 = 0 bbl Cum=10630 bbl Road Maint Water Used f/Lake ~93/32 =0 bbl Cum=56050 bbl I Daily gre~ water disposed at ~PF-1 = 0 bbls Total ~rey water disused at CPF-1: 3158 bbls Dail~ cu~in~s to ~C2-A ball mill = 0 yds Total cu~in~s to CC2-A ball mill = 284 ~ds TOTAL Page 2 ARCO Alaska, Inc. Daily Drilling Report AX9330 2 3/3/95 2/2.5 IDCB We~l Dep~ (MD/TVD) PmVX>us Dep(h {MD) IProgre~ ALPINE #1B 3460' 2177',o/~ 1283' C~a~or ~ ~ C~ ~ E~ ~ POOL RIG ~6 $131,338 $258,882 ~a~ ~ ~ L~ C~ N~ ~ ~ T~ Drilling 8 1/2" hole. 13 3/8" ~ 1,765' N/A 14.6 ~D ~TA ~ ~TA ~ L~ ~TA .a~a~ LSND UaT 16.0 ~b 9~. (2RR) ~1 ID~ 3,321 ~ 3,363 ~ 118 W~h~ 10.2 ~ ~ 9.9 S~ 12.25 8.5 U,d~ 10.2 P.U.~. 125 S.O.~ 115 V~ 44 S~ ~ 0.37 u~, STC HTC ro~a~ SH MUDS7 Avg ~g 10 M~ Drag 15 PV~P 1W 15 ~ 0.28 T~ ~HC ATJ-P~D ~g 6 ~ ~ 1~ Tm S~ 150 ~ 3/8 M~ 0.80 ~a ~. NC09~ T92WH c~ g~, ;P~ No. I 2 3 AP~ WE 7.0 CC ~d~s 550 ~m ~ 18~ ~0 m~ g= 30 .~ S=~ 5.5X12 5.5xl 2 HTHP 2~ p~ CC Oi~ % ~, 155' C mt 1695 a= ~G ;PM 60 60 HTHP ~ p~ O~ ~TIAST 3.5 14 ~~t O.g =Pa 212 212 So~= 10.0 % ~S ~PU 70 60~50 S~ a=~ Pre--re 2,300 Sand 0.13 °/o LGS 54.3 'b~b' N~ 6~0 10~5 E~ ~e p~. ~.1 SLOW PS' 40 ~ ~0 ~ H~va. 338 bbl P~ Vo~. 730 ~1 ~=.T~A o~n 13 13 13 ROP~ab 136 SLOW PPI 325~ ~450 o~i~ U~d $6064 ITo~l ~ud $29362 a~ Co= n/a ~1~ ~OP~ 202 Dale 0400 hrs 1/28/95 ,=~. E I no TDI Su~. ~. 7 9 11 13 15 17 'D~ (MD) 2274 2~ 2~ 2835 3024 3211 ~g~ 14.7 20.6 26.2 33.0 37.9 39.7 )ire~ 159.1 156.9 157.1 159.5 159.8 157.6 T,V.D. 2177 2~ 2616 2780 2933.5 3079 Ven S~. 60.1 138.1 211.6 305.0 414.3 532.3 Sou~ ~.2~ 120.6 1~ 275.0 3~.7 47~.7 Ea= 41.5 70.6 99.5 1~.1 171.6 2145 D~ Leg 2.67 3.14 3.10 3.6~ 2.58 0.~ TIME C~ O~mtions From ~ - ~ 0600-0830 2.5 5 Displace w/new mud. Change shaker screens. 0830-0900 0.5 6 TIH. 0900-0930 0.5 2 Drilling F 2177-2239'. ADT =0.5 hrs 0930-1030 1.0 5 Circulate, a~empt to communicate w/MWD, pump d~ job. 1030-1200 1.5 6 TOH. 1200-1330 1.5 21 Work on MWD. Replace electronic interface module, downhole component. 1330-1400 0.5 7 Rig se~ice. 1400-1500 1.0 6 :TIH. 1500-0600 15.0 2 ~Drilling F 2239-3460'. Build angle as per plan. ADT =9.75 hrs ARCO Alaska, Inc. Daily Drilli,ng Report DInA ueScr~pt~c~ 8 1/2" BIT, 6 3/4" Mach 1C AKO 1.2°, NM STAB, XO, MWD, XO FLT SUB, 3- SpDC, XO, 4-HWDP, DNT JARS, 25 HWDP. OAL= 1070.86' BHA NO.: L)nlll:~pe Baa (lop lo t~o~tom) 1 oD we~t G~e ~ c~ 24x 5 19.5~ G 41/21F prem 2283.87 Date ~ ln~ ~/27/9~ 5 19.5~ S135 41/~1F prem Daily J~ ~ 1~1-~2 DNT 130.25 ~? (y~ i~me Ember ~. ~;7 (Y/N) no I ~ Fu~ & Wa~r In~ We~: ~m: Prate F~I ~ L~ ~a~) F~ ~ (g~) 2M-23 6 BPM 900 24905 5017 Volume T~ Flu~: ;uel R~ {g~) Fu~ ~ur~ 1168 Mud 9500 CPF-1 95 Diesel 600 1060 ~s ~ wamr ~ ~) u~ Wa~r ~ur~ 233 H20 960 Lake 93-12 171 88 Dai~ Volume Cumu~e V~ume P~ W~ R~ ~) Po~ Wamr ~ume 1496 bbls 14279 bbls 90 Lake 93-12 Cu~h~ Da~ W~er Dam Pe~el ~fe~ / ~P D~a Dai~ T~rmure .a~ ~P t~w ~ Lam ~P D~II 3 yds - 16 ARCO 1 3/1/95 3/~95 758yds 1 8 ~S. CONTRACTOR 35 ~27/95 5t~a~ ~e ~111 la.or La~ ~le~ Mtg La~ ~111Urlll Alpi~ ~1 L~ation -55 °F SERVICE 15 3/3/95 ~26/95 we[l'Na'~e ~a[e ~11 {Y~) Volume ~a~) Alpine ~1 3/3/95 OTHER NO Sign~ Ty~ S~II R~ Fi~? D. C. Bumgarner TOTAL 51 Time Houm C~ O~mtions From~- ~ Road Maint Water Used f/Lake ~91-23 = 0 bbl Cum= 5100 bbl Road maint Water Used f/Lake ~93-12 = 0 bbl Cum=14900 bbl Road Maint Water Used f/Lake ~91/16 = 0 bbl Cum=10630 bbl Road Maint Water Used f/Lake ~93/32 =0 bbl Cum=56050 bbl Daily grey water disposed at CPF-1 = 119 bbls Total grey water disposed at CPF-1 = 3277 bbls Daily cuttings to CC2-A ball mill = 120 yds Total cuttings to CC2-A ball mill = 404 yds TOTAL Page 2 ARCO Alaska, Inc. ' Daily Drilling Report AX9330 3 3/4/95 I 3/4 IDCB w~u [~o~h (Mz:~rv~) pmv,ou~ D~ paD) IPrc, gr*,, ALPINE #1B 4676' ~60' ~o~, 1216' C~a~or POOL RIG ~6 $126,418 $385,300 ~a~ ~ ~ ~ C~ N~ ~ ~ T~ Drillin~ 8 1/2" hole. 13 3/8" ~ 1,765' N/A 14.6 ~D DATA ~ud~ LSND ~BT 26.0 ~b a~. ~1 o~ 4,594 D~ 4,5~ ~t~ 135 W~ht 10.2 ~ ~pH 9.6 S~, 8.5 aud~ 10.2 P.U.~. 1~ S.O.~ 125 ~ 42 S~ ~ 0.42 a~, HTC Fo~ SH MUDS1 *vg ~ag 10 I~ Dag 15 PV~ 1~ 16 ~ 0.28 T~ ATd-P~D ~ ~ rm ~ 160 T~ S~ 160 ~a ~12 ~ 0.72 ~ ~. T92WH c~ ~u a~ No. 1 2 3 ~P~w: 6.2 cc ~, 350 ~m ~ ~76 ring= 1~ :~,s~. 5.5x12 5.5~2 HTHP 2~ p~ CC Oi~ % :r~. 2911 a~ ~G SPa 60 60 HTHP ~p~ O~ ~TaST 30.1 3C ~ I ~PM 212 212 So~, 12.0 % ~S aPM 60~50 S~ d~ ,r~ 2,~ Sand 0.13 % LGS 68.0 Ib~bl W~ 10~5 E~ep~ 9.1 SLOW 40 50 H~va. 422 bbl 'Pa Vol. 550 ~1 ~=.TFA 13 13 13 ROP~ab 93 SLOW PP ~ 475 Oai~ Vud $3905 To=~ Mud $33268 ~ Co= ~1~ ROPed 153 3ate ~95 0400 hfs 1/28/~5 Su~. No. 19 22 25 28 ID~ (MD) 3398 3673: 39~ 4235 ~26~ ~gH ~ ~.1 ~.0 39.7 38.8 Dim~ 158A 158.8 159.8 160~ 161.0 T.V.D. 3222, ~2 3~ 3863 ~88 Yen S~. 652.1 769.9 1011.4 1191.0 1375.0 Sou~ 598.9 708.2 9~.0 1103.' 1276A Ea~ 258.9 302.8 388.5 ~9.5 511 D~ Leg 0.22 1.20 0.18 0~ 0~2 TIME Code O~mtions From 0600-0730 1.5 2 DRILLING F/3460-3550'. ADT=I.0 ,0730-0800 0.5 5 CBU. 10800-0900 1.0 6 Short trip 19 stds to shoe. 0900-0930 0.5 21 BOP drill/safe~ meeting. 0930-1000 0.5 7 ~Rig se~ice. 1000-1100 1.0 6 TIH, no fill or tight hole. 1100-0600 19.0 2 Drilling F 3550-4676'. ADT=13.8 .... ARCO Alaska, Inc. Daily Drilling Report 8 1/2" BIT, 6 3/4" Mach 1C AKO 1.2°, NM STAB, XO, MWD, XO FLT SUB, 3- SpDC, XO, 4-HWDP, DNT JARS, 25 HWDP. OAL= 1070.86' BI-IA No.: Dnllp~pe L)ata (lOp¥O 1 ~ We~t Gr~ ~ C~ 36X 5 19.5~ G 41/21F. prem 3504.35 1/27/95 5 19.5~ S135 41/21F prem H~m ~ ~m DaiN J~ ~ 1~1-~2 DNT 146 i~im Fu~ & Wa~r In~~ Well: ~te: Pr~re Fuel ~ L~a ~a~) F~ ~ (g~) 2M-23 6 BPM 900 30600 ;3805 Volume T~ Fiu~: Fuel R~ (g~) FuN ~ur~ 1168 Mud 9500 CPF-1 95 Diesel 1805 600 Phis Iun Water ~ {~) u~ Wa~r ~ur~ 233 H20 805 Lake 93-12 ~ wax~ ~ L~. [Dins ~O~Om water Us~ 95 171 Dai~ Volume Cumu~t~e V~ume Pm~ W~w R~d ~) Po~ Wa~r ~ume 1496 bbls 14279 bbls 95 Lake 93-12 Cu~m~ Da~ W~er Da~ Pem~el ~feN / BOP D~a Dai~ Tem~rature La~ BOP t~N ~ ~ BOP Dna ~.s yds + 1 8 ARCO 1 3/1/95 3/3/95 ~u~tNe ~d ~ed La~ ~ Urlll La~ P~ Unit 759.5y~ 5 ~S. CONTRACTOR 35 ~27/95 5t~age 5~e ;hdl ta~or La~ ~ale~ Mtg iLa~ ~1~ Urlll Alpi~ .1 L~ation +1 0 °F SERVICE 16 3/3/95 3/3/95 Well marne ~a[e ,~11 {~ volume Alpine ~1 3/4/95 OTHER NO S~n~ [y~ S~II R~A Fi~ D. C. Bumgarner TOTAL 52 Time Houm Co~ O~mtions From ~- ~ Road Maint Water Used f/Lake ~91-23 = 0 bbl Cum= 5100 bbl Road maint Water Used f/Lake ~93-12 = 0 bbl Cum=14900 bbl Road Maint Water Used f/Lake ~91/16 = 0 bbl Cum=10630 bbl Road Maint Water Used f/Lake ~93/32 =1050 bbl Cum=57100 bbl Daily grey water disposed at CPF-1 = 119 bbls Total grey water disposed at CPF-1 = 3396 bbls I Dail~ cuttings to CC2-A ball mill = 120 yds Total cuttings to CC2-A ball mill = 524 yds TOTAL Page 2 ARCO Alaska, Inc. I AFC No. IRpL No. w.,1 AX9330 I c.~,=, ALPINE #lB _ POOL RIG #6 iDa~ k~JD DATA M-d ~ LSND MBT 27.0 ppb w.~t 10.2 p~g pH 8.9 v',,~,,W 44 sec 15/22 ~o~. 6/20 AP~ WL 6.0 cc HTHP 2O0 psi CC ~ 0.21 P~ 0.20 Mf 0.80 Ch~o,~ 350 ppm Oa % HTHP SOO ~ )WR So~d, 12.0 % Es Sand Tr % LGS 86.0 Ib/bbl Ho~ vo~. 457 bbl Pa VoL 665 bbl Daily Mud :$3328 Tot~ Mud $36596 Rig Accept 0400 hrs 1/28/95 3/5/95 5282' 13 3/8" @ 1,765' B,'T DATA 8.5" 8.5 STC HTC MFDSSHL ATJ-POSD LC7420 T92WH 5282 S059 223 3259 3.5 41 70/250 6O/250 15/20 10/15 131313 131313 $4146 $9164 ipr~ou,, ~ (MD) c~c~ 4676' $493208 5,156 10.2 SH BGG 1 9.1 48 Daily Drilling Report ISu,pv. in[ DCB 114.6 606' 5,282 ~ ~ 140 w~. 1 ~0 s.o.wt 135 10 u,,- DmO 15 200 T,~ s~ 200 1 5.5x12 65 229 2,400 45 450 Date 3/5/95 TIME 0600-1930 1930-2000 2000-2200 22OO-223O 223O-23OO .2300-0200 O20O-O23O 0230-060O Operations From 0600 - 0600 f/4676-5059'. Hole angle dropped in sands, alternate slide drilling/rotating to build/maintain angle. Bit torqued up while sliding. ~te/build slug. POH f/bit. Unload MWD. Bit#1 had nose cone portion of #1 cone broken, seals failed, iunk damac, XO motor, bit, P/U lead collar, orient MWD. TIH w/bit #2, no tight spots or fill. No undergauge hole noted. Control drill 5059-5063' to work past any junk. Low RPM/GPM. No junk detected. f/5063-5382'. Have not seen any indication of junk. ARCO Alaska, Inc. Daily Drilling Report 8 1/2" BiT, 6 3/4" Mach 1C AKO 1.2°,LDC, NM STAB, XO, MWD, XO FLT SUB, 3- SpDC, XO, 4-HWDP, DNT JARS, 25 HWDP. gAL= 1080.77' _ ... BHA No.: Dnl~ U~a ~ lo 2 oD we~t Gr~ ~ C~ _ 38 5 19.5~ G 41/21F prem 3565.52 .. Date ~ in~ ~/27/~s 5 19.5~ S135; 41/21F prem DaiN Jar. 1~1-~2 DNT 162 ~? (YIN) ]~me Em~yer ~. ~s? (Y/N) no I ~ Fu~ & Wa~r In~~ We~: ~te: Pr~re :uel ~ L~a~a ~ak) Fu~ ~ (g~) 2M-23 6 BPM 900 30470 4130 Volume T~ Flu~: ~uel R~ (g~) Fu~ ~ur~ Mud 4000 CPF-1 ~n wamr ~ ~a[~ ~) ~n water ~ Diesel 700 605 ~ Wa~r ~ (~) u, Water ~ur~ H20 500 Lake 93-12 157 38 Dai~ Volume Cumu~e V~ume P~ W~ R~ ~) Po~ Wa~r ~ume bbls 14279 bbls 100 Lake 93-12 Cua~ Data W~er Da~ Pommel ~fe~ I ~P D~a Dai~ [~raure La~ BOP t~N ~ Laa ~P D~ll 2.0 yds +3 ARCO 1 3/1/95 3/3/95 U~U~tNO ~ ~ed :La~ ~ UrlII La~ Fl~ UnlF 761.5yds 20 ~S. CONTRACTOR 35 3/4/95 St~age Sae ~111 la,or _a~ ~ale~ Mtg La~ ~lli Urlll Alpine .1 L~a~ion -35 °F SERVICE 15 3/4/95 3/3/95 we, ~ame ~a[e 5~11 [Y~) Volume ~a~ Alpine ~1 3/5/95 OTHER NO Sign~ [y~ S~II R~ Find? D. C. Bumgarner TOTAL 51 Time Houm Code O~mtions From ~ - ~ Note: 3/4-5 mud to 2M injection rept will be on 3/6. D ~ C ~ 1 A~as~ Oti · Gas ~ons. Road Maint Water Used f/Lake ~91-23 = 0 bbl Cum= 5100 bbl Road maint Water Used f/Lake ~93-12 = 0 bbl Cum=14900 bbl Road Maint Water Used F Lake ~91/16 = 0 bbl Cum=10630 bbl Road Maint Water Used F Lake ~93/32 =0 bbl Cum=57100 bbl Daily grey water disposed at CPF-1 = 0 bbls Total grey water disposed at CPF-1 = 3396 bbls Daily cuttings to CC2-A ball mill = 240 yds Total cuttings to CC2-A ball mill = 764 yds TOTAL Page 2 ARCO Alaska, Inc. Daily Drilling Report AX9330 5 3/6/95 J 5/6 IDCB .., ALPINE #lB 6308' 5282' ~o... 1026' Caqt=actor Dady Co~ C;um Co~ E~. Coat POOL RIG #6 $123982 $617190 C~atx:m ~ 0~x3 Last Ceg Next Ceg Shoe iDRILLING 8 1/2" 13 3/8" @ 1,765' :N/A 14.6 MUD DATA ~ I~TA MUO LOG gAlA I:~LLI~IG DATA aud~m. LSND MBT 26.0 ppb B~No. #2 #3RR D~ 6,120 o,~h 6,200 Ro, Wt 160 w~ht 10.1 ppg ~ 9.0 S~,. 8.5" 8.5" audW~ 10.2 ~.U.W~. 170 S.O.Wt 145 v',.,=o.~y 44 sec ~ 0.30 M,,~o STC HYC Fom~ation SH MUDS1 *vo O,,,; 10 U,.- Dm; 15 PV/YP 15/ 18 P~ 0.20 Ty~ MFDSSHL DS40HF bko 6 rrqe~ 300 TmSu~ 300 G.~, 5/24 M~ 0.80 .S,,~a No. LC7420 16096 c,x,, oa~ >ump No. I 2 3 APIWL 6.0 CC Ch~o,~d., 300 ppm ~ 5995 6308 T~;,-- 157 ~.,Siz. 5.5X12 5.5X12 HTHP 200 psi 22.0 cc oa % ;~° 936 313 ~Max eGG SP~ 65 65 HTHP So0 psi OWR aJ3TIAST 14.8 2.0 :)C E,ax~.,,t 1.39 C-PU 229 229 So,id, 12.0 % ES RPM 70/~250 85/250 Shale daneity Preaaure 2,700 Sand Tr% LGS 98.0 Ib/'Dbl woe 15/20 5/10 ~o~vol. 518 bbl P~VoL 665 bbl .~ts.T;A 13 13 13 .407 F~OP/Sh,,~ 69 SLOWPPI 500I 1490 Daily Mud $4157 To=~ aud $40753 ~ Cost $4146 $0 ROP/Sand 1 00 Date 3/6195 Rig Accept Dull 4 4 0400 hrs 1/28/95 G.~. E I NO HR Sun/. No. 37 39 41 43 45 47 49 Depth (MD) 5088 5277 5462 5648.1 5836 6022 6209 Angle 37.7 38.1 38.1 40.0 43.1 43.1 43.0 Directicn 159.6 158.7 156.3 156.61 157.8 159.1 158.9 T.V.D. 4541.6 4591 4837 4982.8 5125 5261 5397 Veal Sec, 1705.8 1821,9 1936.5 2051.6 2174.3 2301.7 2429.4 Sou~ 1587.8 1696.2 1802.8 1009.9 1961.5 2142.~ 2261.9 East 623.6 665.1 707.1, 749.1 769.2 840.3 886.6 Dog Leg 0.96 0.24 0.10 1.O4 2.63 0.0 0.29 TIME Code Operations From 0600 - 0600 0600-2030 14.5 2 Drilling f/5282-5995'. ADT-11.0 hrs. Slide/rotate to regain angle. Bit slidin~ good. 2030-2100 0.5 5 Circulate f/trip. 2100-0300 6.0 6 Round trip change bits. Hole good. Unload MWD. 0300-0600 3.0 2 i Drilling f/5995-630~'. ADT-- 2.2 hrs ,,, ARCO Alaska, Inc. Daily Drilling Report 8 1/2" BIT, 6 3/4" Mach lC AKO 1.0°,LDC, NM STAB, XO, MWD, XO FLT SUB, 3- SpDC, XO, 4-HWDP, DNT JARS, 25 HWDP. OAL= 1080.77' BI'IA NO.: Unl~ Data (lop lo t:Tottom) 3 oo Wek~t Grade ~ 38 5 19.5~ G 41/21F prem 3565.52 1~7/95 53 5 19.5~ S135 41/21F prem 1660 H~m ~ ~m Dai~ U~ ~ lm1-~2 DNT 176.75 ~7 ~IN} J~o E~yor ~. F ~7 (Y/NJ I ~i~ Fu~ & WaMr I~ WoE ~m: Prate F~I ~ L~u ~ab) F~ ~ (g~) 2M-23 6 BPM 900 25718 ,4752 Volume T~ FJu~: Fuel R~ (g~) Fu~ ~ur~ (3 days) 1453 Mud 0 CPF-1 Jfl wamr~ ~ [~J ~n wa~r ~ 235 Diesel 650 720 140 H20 670 Lake 93-12 ~ W~ ~ L~. [~S~ ~O~ wa[er ~ 138 99 DaJ~ Volume ~umu~tNe V~ume P~ Wa~ R~d ~) Po~b Water ,~s~s bbls 16107 bbls 80 Lake 93-12 Cu~ Da~ W~er Da~ Pem~el ~fe~ / ~P Da~ T~r~ure La~ BOP t~N ~3 La~ BOP D~i 3.0 y~ -8 ARCO I '3/1/95 3/3/95 764.5y~ 5 ~S. CONTRACTOR 35 3/4/95 St~a~ 5~e ~lll la.or La~ ~le~ M~ La~ ~1~ Urdl Alpi~ .1 L~ation -1 5 °F SERVICE 15 3/5/95 3/5/95 Well ~ame I ~aTe ~11 {Y~) Volume Alpine ~1I 3/6/95 OTHER NO S~n~ Ty~ S~II R~ Fi~ D. C. Bumgarner TOTAL 51 Time H~m C~ O~mtions From ~ - ~ REEETV U ~p~ 2,4 ~995 Road Maint Water Used f/Lake ~91-23 = 0 bbl Cum= 510~'~ .... Road maint Water Used f/Lake ~93-12 = 0 bbl Cum=14900 bbl Road Maint Water Used f/Lake ~91/16 = 0 bbl Cum=10630 bbl Road Maint Water Used f/Lake ~93/32 =0 bbl Cum=57100 bbl Daily grey water disposed at CPF-1 = 0 bbls Total grey water disposed at CPF-1 = 3396 bbls Daily cuttings to CC2-A ball mill = 270 yds Total cuttings to CC2-A ball mill = 1034 yds TOTAL Page 2 ARCO Alaska, Inc. AFC No. [Rpt No. AX9330 6 ALPINE #1B t~ac~or POOL RIG #6 :TOH F/LWD Tool 3/7/95 ID~¢h (MD/'rVD) 7804' Daily Cost $110927 MUD DATA M.~ ~. LSND UBT 27.0 ppb pH 9.0 ~Ne~ght 1 0.1 ppg V~x,.~y 41 sec P~ 0.30 Pv/YP 15/ 15 ~ 0.24 4/16 ~, 0.84 APIWL 5.6 CC Ch~dc~s 300 ppm HTHP 200 psi 18.0 CC io, % HTHP 500 p~ OWR so,~, 12.0 % ES S~d Tr % LGS 98.0 Ib/bbl Ho~v,~. 624 bbl Pa Vol. 640 bbl DaiS/Mod $3850 Tot~ Mud $44604 0400 hrs 1/28/95 13 3/8" @ 1,765' #2 #3RR 8.5" 8.5' STC HYC MFDSSHL DS40HF LC7420 16O96 5995 6308 936 1809 14.8 18.4 70/250 65/250 15/20 5/12 13 13 13 .407 $4146 $0 IPmv~ou= Depth ~D) . ¢~c°~6308' $728117 N/A Daily Drilling Report DCB 1P'°~"1496, 14.6 7,800 ;.p~ 7,472 dM 10.1 ~.u. w~ 190 SH Drag 15 11 e~ 300 1 157 5.5xl 2 0.9 229 p,,, 9.1 45 103 5~ 187 Date ~6/95 ~,wt 172 s.o.wt 155 Max Drag 20 T,~ s~ 300 TIME O6OO-O4OO 0400-0530 O530-O60O Operations From 0600 - 0600 f/6308-7804'. ADT=15.6 hrs. Attempts at sliding to control angle unsuccessful. drop varied f/-0.2/-0.8° per 100ft. CBU f/trip. TOH f/MWD tool. Some tight hole @ 6870, to 30-40 k. ARCO Alaska, Inc. Daily Drilling Report .8 1/2" BIT, 6 3/4" Mach 1C AKO 1.0°,LDC, NM STAB, XO, MWD, XO FLT SUB, 3- SpDC, XO, 4-HWDP, DNT JARS, 25 HWDP. OAL= 1080.77' BHA No.: Uniipq=e L)ata (1 op 1 o 37~ 5 19.5~ G 41/21F prem 3534.8 ~7/9~ 33~ 5 19.5~ S135 41/21F prem 3148.78 Daily J~ ~ 1~1-~2 DNT 190 ~7 (YIN) ~e Em~yer ~. P~7 (Y~ I no in~mi~ FuN & Wa~r In~ Well: ~te: Pr~re Fuel ~ L~= ~ab) Fu~ ~ 2M-23 6 BPM 900 221085 4628 Volume ~ Flu~: Fuel R~ (g~) Fu~ ~ur~ 556 Mud 0 CPF-1 ~n wamr ~ c~a~ {~) un wamr ~ 73 Diesel 625 985 H20 960 Lake 93-12 126 102 Dai~ Volume Cumu~tNe V~ume Pm~b W~ R~ (~) PO~ Wamr ~u~ ,~e bbls 16736 bbls 90 Lake 93-12 Cua~ Dam W~er Da~ Pe~el ~f~ I ~P Dm~ T~r~ure ~ ~P I~N t~ LI~ ~ D~I 2.5 y~s + 10 ARCO 2 3/1/95 3/3/95 ~u~t~e :W~ ~d La~ ~ Urlll La~ ~ Unit 767yds 2 ~S. CONTRACTOR 33 3/4/95 15forage ~de ;~111 tabor La~ ~te~ Utg La~ ~1~ U~II Alpi~ ~1 L~ation +1 0 °F SERVICE 16 3/6/95 3/6/95 well ~ame ..... jua]e ;~ [y~) Volume Alpine ~1J 3/7/95 OTHER NO S~n~ Ty~ S~ll R~ F~ D. C. Bumgarner TOTAL 51 Time Houm Co~ O~mtions From ~- ~ Road Maint Water Used f/Lake ~91-23 = 0 bbl Cum= 5100 bbl Road maint Water Used f/Lake ~93-12 = 2700 bbl Cum=17600 bbl Road Maint Water Used f/Lake ~91/16 = 0 bbl Cum=10630 bbl , Road Maint Water Used f/Lake ~93/32 =300 bbl Cum=57400 bbl Daily grey water disposed at CPF-1 = 130 bbls Total grey water disposed at CPF-1 = 3526 bbls Daily cuttings to CC2-A ball mill = 0 yds Total cuttings to GG2-A Ball mill = 1034 TOTAL Page 2 ARCO Alaska, Inc. Daily Drilling Report IDRM _, AX9330 7 3/8/95 Well Dep~ (MD/TV'D) Pmwc~us Depth (MD) ALPINE #1B '7,945' 7,804'~ 141' C~a~or ~ ~ C~ ~ ~ POOL RIG ~6 $91,321 $819,438 ~at~ ~ ~ ~ C~ ~ ~ ~ T~ Drilling and logging w/MWD 13 3/8" ~ 1,765' N/A 14.6 ~D ~TA ~ ~TA ~ L~ ~TA ~G ~TA ~.d~ LSND MBT 28.0 ~b ~. ~3RR ~3RR .~ 7,892 ~ 7,9~ ~ 180 w~,~ 10.1 ~ ~H 9.0 ~e a.5' 8.5' a~ 10.1 v~ 40 s~ ~ 0.30 ~, HYC HYC =~ SH BUDST ~WP 1~ 15 ~ 0.22 ;~ ~OHF D~F ~ 5 Tm~ ~ TmS~ 3~ G~ 4~4 ,~ 0.86 ~,,~. 160~ 16096 =~ 21 ~. 1 2 3 ~P~ WL 5.6 CC ~ 300 ~m ~ 7892 7945 ~ ~ 13 L~ ~, 5.5xl 2 S.5X12 HTHP 2~ ~ 18.0 CC Ca % ~W* 88 ~ U= ~G ~SPU 65 65 HTHP ~ ~ ~ ADT/AST 1.3 .9 ~ ~t 0.~ ~PM ~ 229 So~i~s 12.0 % ES RPM 65~50 S0~50 S~b dm~ Presto 2,~ ,,. Sand Tr% LGS 98.0 Ib~b, w~ 5~0 5~2 ;E. ~. pm. 9.1 SL~PS~ 45 ~ ~oL 634 bbl p~ VoL 580 ~1 ~.~ .~7 .~7 ~o.~a~ 103 SL~ PP~ 3~~ ~1750 D~ U~ $3850 ~o=~ Vud $~604 ~ ~= ~ $0 ~OP~ 187 Date ~8195 R~Acc~t Dull II I NolA I 0400 hrs 1/2B/95 s~. xI ~6 IDs~ Suw. No. NONE D~ (MD) T.V.D. Ve~ S~. Sou~ ~ ~t~ka Iii & G~ Cons. Corn ~issio~ D~ Log TIME C~ O~mt~ns From ~ - ~ 0600-1000 4.0 6 POOH for densi~ equiped MWD check motor and bit. 1000-1200 2.0 6 Lay down MWD, pick up densi~ equiped MWD, load sources and RIH to 1,600'. 1200-1300 1.0 9 Cut drillin~ line 103'. 1300-1530 2.5 6 :RIH, fill pipe and chec MWD at 4,950' and 7,747'. Washed 60' to btm 0' fill. 1530-1700 1.5 2 Drilling and MWD logging from 7,804' to 7,892'. Mud motor locked up. 1700-1830 1.5 5 Circulate bottoms up and pump pill. 1830-2200 3.5 6 POOH for new mud motor. No tight hole at moderate pulling speeds. 2200-0130 3.5 15 Test BOPE 500 psi. Iow and 5,000 psi. high. See a~ached sheet. AOGCC inspector Dou~ Amos waived witnessin~ test. 0130-0500 3.5 6 Change mud motors, load MWD and RIH with a~ain RR bit ~3. Filled pipe and tested MWD at 1,852' and 5,120'. Washed 40' to bottom 0' fill. 0500-0600 2.0 2 Drilling and MWD Io~ and su~ey from 7,892' to 7,945' ARCO Alaska, Inc. Daily Drilling Report ~3MA IJ e scrl~tlo,rl 8 1/2" BIT, 6 3/4" DD F-2000 W/1.0° SET, XOS, LDC, NM STAB, XO, MWD, XO FLT SUB, 3- SPDC,.XO, 4-HWDP, DNT JARS, 25 HWDP. OAL= 1100.34' - I:IHA NO.: Unttl:~e Uata (lop lo 4 oo weight Grade C, ennection Cla~ I.~ng~ 37xx' 5 19.5# G 41/21F pram 3534.8 L~ate Last 1/27/95 33~ 5 19.5~ S135 41/21F prem 3148.78 Daily Jar ~ 1621-~42 DNT 192 RO~ ,, ln~ F~ & Wa~r 2M-23 6 BPM 1030 ;17,464 13,621 Volume ]~ Flu~: ~uel R~ (g~) Fu~ 394 Mud 0 CPF-1 70 Diesel 475 750 ~ Water ~ {~} )~ Water ~ur~ H20 600 Lake 93-12 163 88 Dai~ Volume CumuA~e V~ume P~ W~ R~d ~) Po~ Water 464 bbls 17200 bbls 125 Lake 93-12 Cuings Da~ W~er Da~ Pe~el ~te~ / ~P Dai~ T~raure ~ ~P t~N ~ L~ ~P D~ 2 +12 ARCO 2 ~3/8/95 3/7/95 769 20 ~S. CONTRACTOR 33 3/4/95 Storage 5~e ~lll la,or .a~ ~le~ ~g La~ ~111Urlll Alpi~ ~ L~ation -28 °F SERVICE 17 3/8/95 3/6/95 wail mare6 ua[e 5~11 {~ Volume Alpine ~1 3/8/95 OTHER NO S~n~ Ty~ S~II R~ Fi~? D. R. MCKEL VEY TOTAL 52 Time Houm Code O~mt~ns From ~ - ~ Road Maint Water Used f/Lake ~91-23 = 0 bbl Cum= 5100 bbl Road maint Water Used F Lake ~93-12 = 2700 bbl Cum=17600 bbl Road Maint Water Used f/Lake ~91/16 = 0 bbl Cum=10630 bbl Road Maint Water Used F Lake ~93/32 =750 bbl Cum=58150 bbl Daily grey water disposed at CPF-1 = 240 bbls Total grey water disposed at CPF-1 = 3766 bbls Daily cu~ings to CC2-A ball mill = 0 yds Total cuttings to CC2-A ball mill = 1034 yds TOTAL Page 2 .RCO Alaska, Inc. Daily Drilling Report ~9330 ~ 8I 3/9/95 ~ 8/9 ~DRM W~l ~ ~ (MD~D) Proves D~, ~D) ~Pr~ ALPINE ~1 B ,8,788' 7,945~~ 843' POOL RIG ~6 $93,276 $921,714 ~a~ a ~ L~ C~ Ne~ C~ ~a T~ Drilling and logging w/MWD 13 3/8" ~ 1,765' N/A 14.6 ~D DATA ~ ~TA ~ L~ ~TA ~G DATA ~ud ~ LSND MBT 28.0 ~b B~ ~. ~3RR ~ 8,768 ~O~ 8,768 ~ ~ 2~ W~ht 10.0 ~ )H 8.9 ~S~ 8.5' a~ ~ 10 =.U. ~ ~ S.O.~ 180 ~ 41 s~ ~ 0.32 a~. ~C ~a~ SH SE ~ ~g 20 ~ Drag ~ PV~ 1~ 1S ~ 0.24 r~ D~F ~ 24 ~m ~ ~ Tm S~ 4~ Ge~ ~ 2 ~ 0.88 ~a ~. 16~6 :~ ga= P~ ~. I 2 3 AP~ WE 4.4 CC ~ 300 ~m ~ 8,788 rm g~ 76 L~ S~e 5.5X12 5.5~ 2 .HTHP ~ ~ 14.8 CC ~Oi~ % F~. 896 a~ aaa SPa 65 65 HTHP ~ p~ O~ ADT/AST 20.4 DC ~t 0.083 GPM ~ 2~ So~= 1 2.0 % ES RPM 80~50 S~ d~ Pre~. 2,3~ H~ va. 687 bbl Pa Vo~. 647 ~1 ~.TFA .~7 ROP~ab 68 SL~ pp~ ~~ ~730 Da~ Uud $5,404 mo~ aaa $53,136 ~aa ~a $0 ROPed 53 Date ~95 0400 hrs 1/28/95 ~, Suw. No, 68 71 73 75~ 76 D~ (MD) 7890.S ~163.~ ~9~ B5~.37 8627~ ~g~ ~.9 32.3 31.~ 31.2 30.6 Dire~i~ 155.7 155.4 1~.6 156A 155.5 T.V,D. 6715.566~.36 7101.197259.~ 7339.62 iVe~ S~, ~69.9 3620.1 3717~ 3812.9 3860.7 Sou~ -3217.2-33~.4 -~2.9 -~29.8 -~73A~ Ea~ 1299.3 1361.8 1~2.8 1~2.7 1~2~ D~ Leg 0.13 0.~1 0.~5 0.67 O.B2 TIME CO~ O~mtbns From ~ - ~ 0600-0600 24.0 2 Drill, log and su~ey from 7,945' to 8,788'. Ter~ Bradley (Arctic Catering) sent to Anch. because of tooth ache. ARCO Alaska, Inc. Daily Drilling Report 8 1/2" BIT, 6 3/4" DD F-2000 W/1.0° SET, XOS, LDC, NM STAB, XO, MWD, XO FLT SUB, 3- SPDC~; XO, 4-HWDP, DNT JARS, 25 HWDP. OAL= 1100.34' BHA No.: IJnllplpe I.)ate (lop Io I:~:~to~n) . 37xx 5 19.5~ G 41/21F prem 3534.8 Data ~ .~7/95 33stc 5 19.5~ S135 41/21F prem 4118.83 DaiN Jar ~ 1~1-~2 DNT 212 Ac~7 {YIN) ~ E~yer ~. ~? (Y~) I RO ln~ Fu~ & Wa~ in~ Well: ~: Pt~re F~I ~ L~ ~a~) Fu~ ~ (g~) 2M-23 6 BPM 1030 12,335 5,129 Volume T~ Flu~: Fuel R~ (g~) Fu~ 460 Mud 0 CPF-1 ~n wa[er ~ ~a~ [~J ~n wa~r ~ 70 Diesel 355 570 H20 450 Lake 93-12 156 102 Da~ Volume Cumu~We V~ume P~ W~ R~ ~) Po~ Wa~r ~u~ sao bbls 17730 bbls 95 Lake 93-12 Cu~ Dam W~er Da~ Pem~l ~ I ~ Dai~ T~raure .a~ ~P t~N ~ La~ ~P D~ 7 - 16 ARCO 2 3/8/95 3~/95 ~ulat~e W~ ~d .a~ ~5 Urlll LeE k~ unlr ~6 B ~S. CONTRACTOR 31 3/4/95 ~tora~ ~e ~hlll la.or La~ 5ale~ Mtg La~ ~111Urlll Alpine fll L~ation -41 °F SERVICE 20 3/8/95 3/6/95 Well ~ame uam 5~11 {Y~) Volume Alpine ~1 3/9/95 OTHER NO S~n~ Ty~ S~ll R~n F~ D. R. MCKEL VEY TOTAL 53 Time Houm C~ O~mtbns From ~- ~ Road Maint Water Used f/Lake ~91-23 = 0 bbl Cum= 5100 bbl Road maint Water Used F Lake ~93-12 = 0 bbl Cum=17600 bbl Road Maint Water Used F Lake ~91/16 = 0 bbl Cum=10630 bbl Road Maint Water Used F Lake ~93/32 =0 bbl Cum=58150 bbl .Daily grey water disposed at CPF-1 = 240 bbls ITotal grey water disposed at CPF-1 = 3766 bbls Daily cuttings to CC2-A ball mill = 0 yds Total cuttings to CC2-A ball mill = 1034 yds TOTAL Page 2 ARCO Alaska, Inc. kFC No. ~Rpt. No, AX9330 I 9 ALPINE #1B POOL RIG #6 Circulate and cond. for 7" ca,, ID ate 3/10/95 8,850' Daily Co~t ?~1032,214 13 3/8"@ 1,765' 9/11,0...,,,. D.~ ~D) Ic~ co= 8,788' IN/A Daily Drilling Report DRM Est Corn To Date 114.6 62' ~ud~ LSND 10.0 ppg ~=co~y 40 sec PV/YP 12/14 Go~. 3/13 MBT 27.0 ppb ,H 8.9 P~ 0.32 P~ 0.22 M~ 0.82 ;API WL 4.6 cc c~, 300 ppm HTHP 200 ps~ 15.0 CC oi~ % HTHP 500 psi OWR So~, 12.0 % ES S,,d Tr % .GS 104.6 Ib/bbl Hole vol. 695 bbl P~ VoL 720 bbl Daily Mud $1,766 Tot~ Mud $54,903 Rig Accept 0400 hrs 1/28/95 B~T DATA #3RR #3RR 8.5' 8.5' HYC HYC DS4OHF DS40HF 16096 16096 8850 8850 0 958 0 22.6 30 801250 0 2/16 .407 .407 $o $o blud W~ SH/T BGG 1.1 Shale d~Mity 8,850 10 Drag 10 rr, ~,n 8,850 RD, wt 195 200 s.o.wt 180 20 ,u~x bag 40 400 'Tm su~ 400 1 5.5x12 65 229 2,300 40 300 Date 3J8/95 TIME 0600-0900 0900-1030 1030-1430 1430-1600 1600-1730 1730-2000 2000-0000 0000-0100 0100-0130 013O-04O0 O4O0-06OO- Operations From 0600 - 0600 and survey from 8,788' To 8,850. Pump Hi Vis sweep, circulate hole clean and pump dry job. POOH to down load and check MWD log quality. SLM (no correction). Tight 3,728' and from 4'635' to 3'728'. Max drag 50 K over. Remove sources from MWD and down load same. Lay down MWD, mud motor and stabilizer. Pick up RR bit #3 and add stabilizer to steel dc. string. up Schlumberger wire line tools and RIH with GR/CNL/LDT/DSI/ADT. Tools stuck al 7,500' while RIH. Worked free in 1 hour. Max pull 8,500 on line and 3,400 on socket. . POOH with Schlumberger wire line tools and rig down logging equipment. RIH w/RR bit #3 and BHA #6 to condition hole for casing. Cut drilling line 53'. Continue to RIH to condition hole for casing. Filled pipe at 5,600'. Hole slick. Washed 50' to btm. no fill.Circulate and condition for 7" casing at TD. at0600. ARCO Alaska, Inc. Daily Drilling Report ~I'IA LJ e~crl~aon 8 1/2" BIT, BIT SUB, 1- SPDC, 8 1/2" STEEL STAB, 2-SPDC, XO, 4-HWDP, DNT JARS, 25 HWDP. OAL= 1006.52' ._ u[-~tA NO.: L)nl~ Data ~ 1o .,, 37~ 5 19.55 G 41/21F prem 3534.8 1/27/95 33stc 5 19.5~ S135 41/21F prem 4118.83 Daily Jar ~ 1~1-~2 DNT 214 ~c~t?~o (Y~) '" ~me E~yer ~. k~s7 (YIN) Jnj~ Fu~ & Wa~r 2M-23 6 BPM 1030 18,091 32~ Volume ~ Flu~: Fuel R~ (g~) Fu~ 182 Mud 9000 CPF-1 75 Diesel 625 150 ~ Water ~ [~) U~ Water ~ur~ 320 ~H20 50 Lake 93-12 ~m~ wm~ ~ L~. [~J ~O~ wa[er ~ 150 106 ~Dai~ Volume Cumu~tNe V~ume P~b W~ R~ (~) Po~ Water ~u~e s77 bbls ~ bbls 100 Lake 93-12 C~m~ Da~ W~er Da~ Pem~l ~fe~ I ~P Dai~ T~rature La~ ~P t~N ~ ~ ~P Dna 3 -25 ARCO 2 3/8/95 3/7/95 ~9 CALM CONTRACTOR 33 3/4/95 A~p~ ,~ L~a~on CALM °F SERVICE 19 3/8/95 3/9/95 wei~ ~ame ,~a[e 5~11 {~) VOlUme Alpine ~1 3/10/95 OTHER NO S~n~ Ty~ S~U R~ Fi~ D. R. MCKEL VEY TOTAL 54 Time Hours Code O~mlions From ~ - ~ Barbara Burns (ARCO), Bruce Webb (DNR) and Arne Schrock (ADEC) made an inspection visit to the location on 3/9/95. All comments good. See aEachment. Began rig down of Sper~ Sun equipment. All MWD and directional tools sent in. Road Maint Water Used F Lake ~91-23 = 0 bbl Cum= 5100 bbl ~Road maint Water Used F Lake ~93-12 = 0 bbl Cum=17600 bbl Road Maint Water Used F Lake ~91/16 = 0 bbl Cum=10630 bbl Road Maint Water Used F Lake ~93/32 =2200 bbl Cum=60350 bbl Daily grey water disposed at CPF-1 = 240 bbls Total grey water disposed at CPF-1 = 3766 bbls Daily cuttings to CC2-A ball mill = 0 yds Total cuttings to CC2-A ball mill = 1034 yds TOTAL Page 2 ARCO Alaska, Inc. AFC No. ~ No. [Date AX9330 I~t 10 I ALPINE #lB POOL RIG #6 Circ. and condition )rior to cmt. I~LID DATA ~,,d~* LSND Weight 1 0.3 ppg V~,~y 40 sec PV/YP 15/ 13 Go~ 4/1 3 MBT 27.0 ppb ,H 8.9 0.30 0.24 0.88 API WL 4.8 CC ~,~, 300 ppm HTHP 200 psi 1 5.0 CC Oi~ % HTHP SO0 psi OWR so~, 12.0 % ES Sand Tr % LGS 104.6 Ib/bbl .~o~v<~. 695 bbl pit VoL 550 bbl Daily Mud $3,926 Tota~ Mud $58,829 Accept 0400 hrs 1/28/95 3/11/95 10/11 Ipmvx)ua ~ (MD) c~co. 8,850' #3RR 8.5" HYC IDepel ffaDrlVo) 8,850' 13 3/8"~,,1,765' Daily Drilling Report ISupv. DRM E~. Co~ 1o D~ 14.6 Node Dal=4h 8,850 =.u.w. 250 ~.vg Drag 90 DS4OHF rm a~ 16096 G-- Pu~p No. ! 1 ~0 ,Gm Lher ~. ~ 5.5x12 958 SPM ~ 28 22.6 ~t GPM [ 99 .~7 ~SL~ PPI 300 $0 ~d IDate ~95 1 D~ILL i~IG DATA Rot V~ s.o.~ 160 u.x D~g 140 T~ SuH TIME O60O-0730 0730-1630 1630-1800 1800-1930 1930-0430 043O-O600 Operations From 0600 - 0600 Circulate at 8,850' to condition for 7" casing. POOH laying down drilling string. Hole in good shape. Pull wear bushing and set test plug. Change top rams to 7" and test to 3,000 psi. Pull test plug. to run 7" casing. Helc pre job safety meeting. Ran 207 jts. 7" 29# 1-80 Butt. csg. to 8,840'. Detail to follow. Circulate and condition mud prior to cementing. Tight hole and packing off. Loose returns at circulation rates above2.5 bbl/min. Lost approx. 90 bbls since 0430 hr ARCO Alaska, Inc. Daily Drilling Report Ill-iA ~ e scrlp~c~ None . ,., Bi-lA NO.: Dnlli~i~ l..)iILa (l op l 0 t:~,,,) None oD weight Grade ~ Ct~a~ Le~g~ 5 19.5# G 41/21F pram None ~ate Last Inspec~e~l ~/27/9s 5 19.5# S135 41/211= prem None Hours On Jars Daily Jar # 1621-0042 DNT Acc~dentY (Y/N) INarne E. mployer H~. i..~e~7 (Y/N) I no Injecaon Fue~ & Water In~ect~n We[i: Rate: Pr#~ure F~el On Locatmnl (gal~) Fuel Ueed 2M-23 4 BPM 820 13,875 4216 Volume Type Fiu~d: Fuel Received (gaJs) Fuel S<)urce 226 Mud 0 CPF-1 ~n wamr ~n ~.oca[mn [oo~s), tJn wa[er use~ 35 Diesel 700 280 JI1 Water Hece~ved {bi;~s) UI1 Water ~ource H20 355 Lake 93-12 i-,ginnie w~e~- ~ i.oc. [ol;x,s)I-'O[aDle water U~eO 150 95 Daily Volume Cumulative Volume Potable Wat~ Rcvd (bbis) Potable Water Soume 2s~ bbls 18568 bbls 95 Lake 93-12 Cuttmgs Data Wea~er Data Per~x~nel Safety I BOP Data ;Daily i-emperature .est BOP t~lif, J~N ~ .eat BOP Ddlt -52 ARCO 1 3/8/95 3/7/95 ~u~nulat~ve I~,/ir~ speed Last I"~ Llrlll La~ I-Ire Unlr 77~ CALM CONTRACTOR 33 3/4/95 ~lorage 5~te ~l'Hll lector Last tSatety Mtg Last ~;Splll Urlll Alpine .1 Location -52 °F SERVICE 16 3/10/95 3/9/95 welt I'~ame l l~"axe ~sp~fl (Y/N) Volume [gals) Alpine #1I 3/11/95 OTHER NO Signed Type Spill Report Filed? D. R. MCKEL VEY TOTAL 50 Time Hours Code Operations From 0600 - 0600 Began rig down of Epoch equipment. Will release mud loggers today. Road Maint Water Used f/Lake #91-23 = 0 bbl Cum= 5100 bbl Road maint Water Used f/Lake #93-12 = 0 bbl Cum=17600 bbl Road Maint Water Used f/Lake #91/16 = 0 bbl Cum=10630 bbl Road Maint Water Used f/Lake #93/32 =4450 bbl Cum=64800 bbl Daily grey water disposed at CPF-1 = 214 bbls Total grey water disposed at CPF-1 = 3980 bbls Daily cuttings to CC2-A ball mill = 0 yds Total cuttings to CC2-A ball mill = 1034 yds TOTAL Page 2 ARCO Alaska, Inc. AFC No. Wea AX-9323 2 I ... ALPINE #lB POOL RIG #6 O~'a~:~ ~ Set BPV and VR plug in tb~ head. ~D DATA Mud type Weight PV/YP Gels APl WL HTHP 200 psi HTHP 500 ps~ Solids Sand Hole vol. Daily Mud $3,926 To~a~ Mud $5,74~ Rig Accept 0400 hrs 1/28/95 3/12/95 IDer~h (M[VTVD) PBTD 8,747' ~2~5,190 7" @ 8,839' cu., co. 8,850' $249,311 Next Ceg N/A De~ None Mud Wt. Gas ) Exponent Porn Prom Shale Sand Rig Relea~ Daily Drilling Report DRM IE:~ O.¢h NONE R~ ~,U, W~. S.O,Wt. Drag Max Drag frq ~ T~ Sa'f 1 5.5x12 Date TIME 0600-0700 0700-1000 1000-1530 1530-2000 2OOO-24OO 2400-0500 Operations From 0600 - 0600 Circulate and condition 7" casing prior to cementing. Revised estimate of mud losses while circulating is 70 bbls. Final hour of circulation at 7 bbl/min with no losses. led Dowell and cemented 7" casing. Pumped 20 bbls ARCO preflush followed by, 48 bbls of 11.2#/gal ARCO spacer, 49.3 bbls (233sks) class G cement with additives / mixed to 15.8#/ga1.. Displaced cement with 38 bbl diesel and 178 bbls of 10.6#/ga, brine. Held prejob safety meeting. Used 3 wiper plugs. Tested lines to 3500 psi. / Reciprocated pipe until last 10 bbls of displacement. Had full returns entire job. Bumped with 1800 psi. (500psi over circ prsr.) Floats held OK. See attachment for details. Monitored static well 1 hour. Rigged up and picked up BOPE. Set 7" casing slips with 000 lbs. Cut off casing and layed down stub. rams to 5" and load off BOPE. Nipple up and test tubing head and casing hanger to 5,200 psi. Install VR plug in 20"x 13 3/8" head. Set 3/12" tubing hanger and nipple up tree adapter and master valve. up and freeze protect 7"x13 3/8" ann. by pumping 200bbl fresh water followed by 1 bbl diesel. Injection pressure w/diesel 580psi at 5bbl/min. Shut in prsr. 460psi. Tested 7" casing while freeze protecting ann. to 3000psi for 30 minutes. Lost 50psi. ARCO Alaska, Inc. Daily Drilling Report None 51'4A NO.: Un~ U~a (l~ lo HeRe OD W,~ ~r~, ~ C~-- 5 19.5~ G 41/21F prem None ~2~s 8 ~.8~ S~88 ~/21~ pram None H~m~mZl4 ,Daily Jar ~ 1621-~42 DNT ~sent in ;Acc~ent? (YIN) ~me Em~ye~ ~. F~e7 RO~ , In~i~ Fu~ & Wa~r In~ Well: ~te: Prate Fuel ~ L~a ~a~) Fu~ ~ (g~) 2M-23 4 BPM 820 13,875 4216 Volume ~ Ftu~: :Fuel R~ (g~) Fu~ ~ur~ 750 Mud 0 CPF-1 170 Diesel 500 700 290 H20 355 Lake 93-12 ~m~ w~ ~ L~. [~J ~o~ water u~ 150 100 Dai~ Volume Cumu~tNe V~ume Pm~ W~ R~ ~) Po~ Water ~umo 1210 bbls 18568 bbls 100 Lake 93-12 Cuings Da~ W~er Da~ Pe~el ~fe~ I BOP D~a Da~ T~rature ,La~ ~P t~N ~ ~ ~P -60 ARCO 1 3/8/95 3/7/95 ~u~t~e ~ s~e~ .a~ ~ Urlll La~ F~ UnI[ 779 7kts CONTRACTOR 33 3/4/95 5t~a~ ~e ~111 la~or La~ ~to~ Mtg La~ ~lll Ur~ Alpine ~1 Location -95 °F SERVICE 13 3/10/95 3/9/95 ~ell ~ame ~aTe ~ll [Y~} VOlume Alpine ~1 3/1~95 OTHER yes Less than 1 gal. Slgn~ Ty~ S~II R~ D. R. MCKEL VEY TOTAL 47 Diesel Yes Time Houm Code O~mt~ns From ~- ~ 0500-0530 0.5 21 Rigged down Dowell. Set VR plug in tubing head and set back pressure valve. 0530-0600 0.5 I Cleaning mud pits. Road Maint Water Used F Lake ~91-23 = 0 bbl Cum= 5100 bbl Road maint Water Used F Lake ~93-12 = 0 bbl Cum=17600 bbl Road Maint Water Used F Lake ~91/16 = 0 bbl Cum=10630 bbl Road Maint Water Used F Lake ~93/32 =3150 bbl Cum=67950 bbl Daily grey water disposed at CPF-1 = 214 bbls Total grey water disposed at CPF-1 = 3980 bbls Daily cuttings to CC2-A ball mill = 0 yds Total cuttings to CC2-A ball mill = 1034 yds ~TOTAL 1.0 Page 2 ARCO Alaska, Inc. ? '~--' -''~ ~ ~ Daily Drilling Report AX-9323 3 3/13/95 IDRM ALPINE #1B PBTD 8,747' 8,850'~o 0' POOL RIG ~6 $184,182 $433,483 Rig released 7" ~ 8,839' N/A ~D DAIA ~ ~IA ~ L~ ~IA ~G ~TA Mud ~ B~ ~. W~ht S~e ~ M~ g~a~ kvg ~ag M~ D~g PV~ T~ B~. ~ ~ T~ S~ Ge~ ~N ~. C~ ~ P~ No. I 2 3 :APl WL ~ T~ G~ L~ ~e 5,5xl 2 5,5xl 2 IHTHP ~ p~ g~e M~ ~G ~PM HTHP ~ p~ ADT/AST DC ~t ~PM Sol~s RP M S~ ~ Pre--re I I I Ho~ v~. ~m.TFA ROP ~a~ SLOW PP Dai~ Mud To~l Mud $5~7~ ~ Coa IROP S~d Date 0400 hrs 1/28/95 ~' ~ I ~ 1200 hrs 3/1~95 Suw. ~. NONE D~ (MD) ~g~ Dire~ T.V.D. Ve~ S~. Sou~ Earn D~ Leg TIME Co~ O~ml~ns From ....... , 0600-1200 6.0 22 Clean mud pits, dewatering system and celler. Belease0 ri~ at 1200 hfs ~KB to tubin~ hea~ = 27.~' ~chorz.~ ~ ARCO Alaska, Inc. Daily Drilling Report · i None _ ~HA NO.: I.,)nllplPe Data (lop lo Uol~om) ,= None oo w.~t ~-r.~. ~ C~. 5 19.5# G 41/21F prem None ., L)ate Lam Inspected 1/27/95 5 19.5# S135 41/21F pram None Hours C~ Jars Daily Jar # sent in Acmde~t? (Y/N) IName I-mployer Ppi. FLieS? (Y/N) no I InJeChon Fuel & Water injemien Well: Rate: Pressure Fuel O~ Locatmn,J (.gals) Fuel ~ (gals) 2M-23 6 BPM 980 10623 3000 Volume iType Fluid: Fuel Received (gals) Fuel Source 873 Mud 0 CPF-1 ~n wa[er Un LOCa[~ [goisJ L~n wa[er use~ 135 Diesel 200 0 Url Water Hec=,-.'~ (bl3ts} I.)rl Water ~5ource 58 H20 Lake 93-12 ~meo~e wa~e~ un LOC. iDOlS} ~'o[aDle wa[er use~ 143 Daily Volume CumulatNe Volume Potable Wate~ Rcvd (bi~) Potable Water Source 1066 bbls 19634 bbls =Lake 93-12 Cuttings Data Weather Data Personnel Safety I BOP Data Daly Temperature Last BOP test/Div lunct~°n Last BOP Drill -58 ARCO 1 3/8/95 3/7/95 ~umulat~ve Wll3cl speeQ Last I-IZJ5 Urlll LaS~ J-ire Unit 779 7kts CONTRACTOR 34 3/4/95 TStorage ~5~te (..,hill factor LaSl ;safely Mtg La~l ~o111 LJrlll Alpine #1 Location -93 °F SERVICE 9 3/13/95 3/9/95 wail ~&me juate ~Sj~ll {~'/N} volume Lgals) Alpine #1J 3/13/95 OTHER NO i S~gned Type Spill Ropor~ Flied? D. FI. MCKEL VEY TOTAL 44 Time Hours Code operations From 0600 - 0600 Road Maint Water Used f/Lake #91-23 = 0 bbl Oum= 5100 bbl Road maint Water Used f/Lake #93-12 = 0 bbl Oum=17600 bbl Road Maint Water Used f/Lake #91/16 = 0 bbl Cum=10630 bbl Road Maint Water Used f/Lake #93/32 =0 bbl Oum=67950 bbl I Daily grey water disposed at CPF-1 = 0 bbls Total grey water disposed at CPF-1 = 3980 bbls Daily cuttings to CC2-A ball mill = 0 yds Total cuttings to CC2-A ball mill = 1034 yds TOTAL Page 2 ARCO Alaska, Inc. AtlanticRichfieldCompany TO: Alaska Oil & Gas Consveration Commission FROM' Attn.: Robert P. Crandall 3001 Porcupine Dr. Anchorage Alaska 99501 Ms. Kelli A. Thibodeau ATO-1466 ARCO Alaska, Inc. 700 G. Street Anchorage, Alaska 99510 (907) 265-6240 DATE: 18, April 1995 Transmitted herewith is the followinq data concerninq Alpine 1: APl 4/501032021100 LO S: RECEIVED 1 Sepia Copy Displayed by Sperry-Sun: xA!pinel ~¢-/7 }APR 2_0 1995 ---.4 DGR EWR4 ROP - 2" & 5" (120' to 7500') Alaska 0il & 6as Cons. 60mmissi0n %,,,. ,Alpine lA Anchorage ~"'4DGR EWR4 ROP- 2" & 5" (1700' to 7340')TVD 6;:~~J/~ DGR EWR4 ROP - 2" & 5" (1700' to 9940') MD Alpine 1B "-...~ DGR EWR4 ROP - 2" & 5" (1700' to 7500') TVD %-.....j, DGR EWR, ROP- 2" & 5" (1700' to 8800')MD ~_//~_.._~ '~ (~ I Paper Copy Displayed by Sperry Sun: · .~ A!pine 1 --..2 DGR EWR4 ROP - 2" & 5" (120' to 7500') '% A!pine lA --.o DGR EWR4 ROP - 2" & 5" (1700' to 7340') TVD """.--J DGR EWR4 ROP - 2" & 5" (1700' to 9940') MD Alpine 1 B .~_j~DGR EWFt4 ROP - 2" & 5" (1700' to 7500') TVD DGR EWR4 ROP 2" & 5" (1700' to 8800') MD REPORTS: · Alpine 1 ~ 1 Wireline Tops as Displayed by ARCO Alaska Inc '% '""J I Copy MWD End of Well Report as Displayed by Sperry-Sun I Copy Core Analysis Report-CL File No. BP-3-1572 as Displayed by CORE LABORATORIES (Including 3.,5" Diskette Containing Files AR1572DS.WK3 & AR1572SW.WK3-07-APR-95) -~ Alpine lA "~ 1 Wireline Tops as Displayed by ARCO Alaska Inc ~1 Copy MWD End of Well Report as Displayed by Sperry-Sun I OF1 ARCO Alaska, Inc. AtlanticRichfieldCompany TO: Alaska Oil & Gas Consveration Commission FROM' Attn.' Robert P. Crandall 3001 Porcupine Dr. Anchorage Alaska 99501 Ms. Kelli A. Thibodeau ATO-1466 ARCO Alaska, Inc. 700 G. Street Anchorage, Alaska 99510 (907) 265-6240 DATE: 11, April 1995 Transmitted herewith is the following data concerninq Alpine 1' APl # 501032021100 -~ Alpine lB ~ 1 Wireline Tops as Displayed by ARCO Alaska Inc '"'~-31 Copy MWD End of Well Report as Displayed by Sperry-Sun TAPES: .-..Alpine lA 1 LDWG Formatted 6" Open Reel 1600 BPI Tape- MPT GRC EWR CNP SFD ROP 4/10/95 as Displayed by Sperry-SUn "'"'"'~ I Paper Copy LIS Verification Displayed by Sperry-Sun ~ ,.Alpine lB ~ I LDWG Formatted 6" Open Reel 1600 BPI Tape- MPT GRC EWR CNP SFD ROP '"'--~....~. 4/10/95 as Displayed by Sperry-Sun 1 Paper Copy LIS Verification Displayed by Sperry-Sun 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: APR 2 0 1995 Alaska 011 & Gas Cons. Commission Anchorage 2OF1 Approved for transmittal by: F. M. Honeycutt Manager, North Alaska Exploration ARCO Alaska, Inc. Atlanti~ ~dchfieldCompany TO: · Alaska Oil & Gas Consveration Commission Attn.: Robert P. Crandall 3001 Porcupine Dr. Anchorage Alaska 99501 FROM: Ms. Kelli A. Thibodeau ATO-1466 ARCO Alaska, Inc. 700 G. Street Anchorage, Alaska 99510 (907) 265-6240 DATE: 18, April 1995 Transmitted herewith is the followinq data concerninq Alpine 1 lA & lB: LOGS: I Sepia Copy Displayed by EPOCH: Alpine 1 Formation Log 2" = 100' (120' to 7500') Alpine lA Formation Log 2" = 100' (120' to 8940') Alpine 1B Formation Log 2" = 100'120' to 8850') I ~1~ Copy Displayed by EPOCH: Alpine 1 Formation Log 2" = 100' (120' to 7500') Alpine lA Formation Log 2" = 100' (120' to 8940') Alpine 1B Formation Log 2" = 100'120' to 8850') 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 b~~/ ~?~ ~.~..D \995 Received ~0 DATE: * 9.0 Approved for transmittal by: F. M. Honeycutt Manager, North Alaska Exploration I OF1 ARCO Alpine #1 B RECEIVED APl #: Location: Surface: 50-103-20211-02 '"" lq q APR 2 L., ,,.,~5 Alaska Oil & Gas Con°. WKE 92-02, sp. 1360 Ancilorage ASP: x=375,455 y=5,972,482 zone:4 Lat.: 70.333225 N Long: 151.010348 W S/T/R: 1468' FSL, 2248' FWL, sec 1, T11N, R4E BHL: ASP: x=376,905 y=5,968,785 zone:4 Lat.: 70.323191 N Long: 150.998093 W S/T/R: 2207' FNL, 1522' FEL, sec.12,T11N, R4E Lease Number: ADL 38OO75 BHL Geological Tops: MD SS Base Permafrost 835' -797' Top West Sak 1010' -972' Top Schrader Bluff 1310' -1272' C-40/K- 10 2281' -2236' C-30/K-5 2392' -2342' C-20 2804' -2716' K-3 4179' -3782' K-2 4466' 4004' Top Albian B 6016' -5218' Top Albian C 6671' -5704' HRZ 7912' -6695' K- 1 8132' -6879' LCU 8236' -6966' Top Jurassic J4 8407' -7112' Total Depth (driller) 8850' -7492' Conventional Cores: none Logging Runs: MWD gamma ray/resistivity: surface to TD MWD gamma ray/resistivity/neutron/density: 7750' MD to TD Mudlog: surface to TD Sidewall Cores: none RFT: none ORIGINAL ID R I L. 1_ I IM {~ c; I= R V I C I= c:; IVIWD End of Well Report for ARCO ALASKA INC. Rig : POOL RIG6 Well : ALPINE //lB (WILDCAT) Field : WESTERN COLVILLE EXPLORATION Country: USA APl//50-103-20211-02 Job No.: AK-MM-95104 Date : 10-MAR-95 R C iV cD APR 20 1995 Alaska 0i~ & Gas Cons. CoInraissl0D Anchorage IVIWD End of Well Report Contents · 2. 3. 4. 5. 6. General Information Operational Overview Summary of MWD Runs Bit Run Summaries Survey Data Service Interrupt Reports AK-MM-95104 MWD End of Well Report Section 1. : General Information I AK-MM-95104 MWD End of Well Report spenn~/-sun General Information Company Rig Well Field Country Sperry-Sun job number Job start date Job end date North reference Declination Dip angle Total magnetic field Date of magnetic data Wellhead coordinates N Wellhead coordinates E Vert. section direction MWD Engineers Company Representatives Company Geologists ARCO ALASKA INC. POOL RIG 6 ALPINE #lB (WILDCAT) WESTERN COLVILLE EXPLORATION USA AP1//50-103-20211-02 AK-MM-95104 01-MAR-95 10-MAR-95 TRUE 27.9 80.4 57183.00 23-JAN-95 1465 FSL 2250 FWL S1 T1 IN R4E 327.2 DOUG ELLIS FERGUS TAIT DAVE BUMGARNER DON McKELVEY KEN HELMHOLD ' Engineering units used: Depth / length : OD / ID : Temperature : Flow Rate : Pressure : Weight on bit : Mud Weight : feet inches deg. F galls/min psi lbs (1000s) PPg Viscosity : PV : YP : Chlorides : Fluid loss : Casing weight : sec/quart mPa.s lb/(100 sq.ft.) ppm ml (cc.) lbs/ft AK-MM-95104 MWD End of Well Report Section . : Operational Overview AK-MM-95104 MWD End of Well Report Operational Overview RAN WIRELINE LOGS FROM il-FEB-95 TO 16-FEB-95. TESTED B.O.P. PICKED UP 12 1/4" BIT AND DRESSED TOP OF CEMENT TO 1800 MD. PICKED UP 8 1/2" BIT, DRILLING MOTOR AND MWD TOOLS. STARTED SIDETRACKING AT 1863 MD. MWD RIIN #9 WAS USED TO SIDETRACK ALPINE 1 TO PROVIDE REALTIME STEERING, SURVEY, GAMMA RAY AND RESISTIVITY DATA FROM 1863 TO 2239 MD. A FAULT WITH THE CIM RESULTED IN A COMPLETE TOOL SHUTDOWN NECESSITATING A TRIP TO REPLACE THE CIM. REALTIME AND RECORDED DATA NOT OBTAINED OVER LAST 62' OF BITRUN. AS PER INSTRUCTIONS, NO ATTEMPT WAS MADE TO OBTAIN DATA OVER THIS INTERVAL ON THE FOLLOWING BITRUN. MWD RUN #10 CONTINUED THE SIDETRACK AND DRILLED FROM 2239 TO 5060 MD. ONE HUNDRED PERCENT REALTIME AND RECORDED GAMMA RAY AND RESISTIVITY DATA RECOVERED. POOH TO CHANGE BIT AND BHA. MWD RUN #11 DRILLED FROM 5060 TO 5997 WITH ONE HUNDRED PERCENT REALTIME AND RECORDED GAMMA RAY AND RESISTIVITY DATA RECOVERED. TRIPPED OUT OF HOLE TO CHANGE THE BIT. MWD RUN #12 DRILLED FROM 5997 TO 7804 WITH SAME BHA USED ON RUN %11. TRIPPED TO CHANGE THE BIT AND PICKUP NEUTRON/DENSITY SENSORS. 100% REALTIME AND RECORDED DATA RECOVERED. MWD RUN #13 DRILLED FROM 7804 TO 7891 AND PROVIDED REALTIME AND RECORDED STEERING, SURVEY, GAMMA RAY, RESISTIVITY, NEUTRON, AND DENSITY DATA. TRIPPED OUT OF THE HOLE DUE TO A MOTOR FAILURE. ONE HIINDRED PERCENT DATA RECOVERED. MWD RUN #14 DRILLED FROM 7891 TO TD AT 8850 AND PROVIDED THE SAME REALTIME AND RECORDED INFORMATION AS ON RUN %13. ONE HUNDRED PERCENT DATA RECOVERED. AK-MM-95104 MWD End of Well Report Section · : Summary of MWD Runs AK-MM-95104 MWD End of Well Report Summary of IVIWD runs DRILLING NIWD Bit Max. Service Trip for Failure Run No. Temp. Interrupt MWD Type Y Y FE 09 1 lO 1 11 2 12 3 13 3 14 3 Hole MWD Start End Drill/Wipe Run Start Run End BRT Oper. Circ. Size Sensors Depth Depth Distance Time Date Time Date Hours Hours Hours 8.50 DIR-FE 1863.0 2239.0 376.0 19:50 O1-MAR-95 12:15 02-MAR-95 16.42 16 87 9.20 8.50 DiR,FE . ""' 2239-0" ": 50600'.:' :i:i~8~[:.'01-:::i ::i::i~::i-~O: ~'~:.~'95'..i.":' ].' 22:; 03 .' 0Z[:]'~95. '56 55 ' 77 6,84 8.50 DIR-FE 5060.0 5997.0 937.0 22:30 04-MAR-95 23:26 05-MAR-95 24.93 25 12 2.63 8.50 DIR-FE ' .. 5997.. 0.. .. .i ~78~4:~.~?~:~]~8(~7:~;i:~i::?i::!~2~5i.~5~!~95?~:~!~:~:~i:~9~25.?~:~5:: :i:...'33167'i. : .33 82 5,35 - . . i - . ..- :. · - ' ' -:-. '-:-..' ..- ..' ' '""- -":'::.'.:':.-.::::::':::':-' :::-.: :-:.:::F-"::..: :::.: :--.:-': '::-:-:: :::--.:": ':'::: :-: -':'-:': ::.': -: ': -': ':::::-" :' "-'-:-" '::: ":":':' ::: .' -' :: .:':. '"':' ' :' : :'. ' '". ' - ' ' 8.50 DIR-FE 7804.0 7891.0 87.0 10:41 07-MAR-95 21:45 07-MAR-95 11.07 11 47 2.01 8.50 DIR-FE' i.:'; '7891.0:.· ~i.~"~.:~::.~:]~].:~?~i].~.~:~95~]~.~:!?~?.~:B~i~i~!:~.~?~:i~4~]~ ' ' "40.47 0,00 I , ., - . -" :. '.. -:.-!:-::.-'.i.:'ii:'.Z";:;';:..[ ;:Z:;:::'-Z.: ::-".i '-. :']:.']:';~; ':':;':::' :: -i-;-i ; .'.."; "-: .'.'.'-: ' 'i'-: '.."] i.: ';'!:.:-: :-;']i;-- - ' - · - · -.. . - ' ..... -- · ..... - '- :-:-'-..-:.:-..-....:. ::.'.:..'-:-'-'-'- : :-:.'.:. - ."...- ..: ' -' ' --' "-: :-' -.:::: .-".' ::': '":':'":- '---. ' -: :- -':: ..... .'..: ' ' ' "': -.. I .:. . '. ' TOTALS --> 6987.0 182.89 184.52 26.03 AK-MM-95104 88.0 113.0 113.0 122.0 I 1 133.0 129.2 llnllI~J Iq*VI · Section e Bit Run Summaries , AK-MM-95104 MWD End of Well Report Bitrun Summary MWD Run Time Data Drilling Data Mud Data MWD Run : 09 Start Depth: 1863.0 ft Rig Bit : 1 End Depth : 2239.0 ft Hole Size: 8.50 in Footage : 376.0 ft Run Start: 19:50 01-MAR-95 Flow Rate : 460.00 gpm Run End : 12:15 02-MAR-95 R.P.M. : 70 BRT hrs : 16.42 W.O.B. : 15 Klbs Circ.hrs : 9.20 R.O.P. : 119 ft/hr Oper.hrs : 16.87 S.P.P : 2100 psi Mud type : BLAND Weight/Visc: 10.00 / 39.0 Chlorides : 500 PV / YP : 18 / 15 Solids/Sand: 10.0 / 0.01 %0il/ O:W : 0 / 0 :90 MWD Schematic BHA Schematic PM / Pulser S/N : PO346PM6 Choke : 12 Component Length O.D. I.D. I PM sub Directional sensor PM to bit : 54.57 RLL S/N : PO345CRG6 CIM sub Downhole processor EWR Phase 4 sub Resistivity EWR to bit : 38.09 DGR sub Dual Gamma Ray DGR to bit : 30.74 12. 25 X HWDP 11. D.O.T. JARS 10. 4 X HWDP 9. CROSS-OVER SUB 8. 3 x DRILL COLLAR 7. FLOAT/CROSS-OVER SUB 6. PULSER / PM s. RLL STRING 4. x/o SUB 3. NON MAG STABILIZER 2. 6 3/4" MACE lC 1.2 AKO 1. 8 1/2" HTC ATJ-PO5 748.66 5.000 3.063 33.20 6.250 2.250 120.25 5.000 3.063 3.65 6.375 2.812 91.41 6.438 2.875 2.87 6.875 2.625 20.58 6.750 21.63 6.750 1.85 6.125 2.812 4.96 6.750 2.812 20.95 6.750 0.85 8.500 Comments MWD Performance ASSEMBLY WAS PULLED WHEN TOOL STOPPED PULSING. ON SURFACE, THE CAUSE OF THE FAILURE WAS ASCERTAINED TO BE THE CIM WHICH WAS SWAPPED OUT WHILE IN TEE ROTARY TABLE. PICKED UP TOOL TO KICK OFF AT 1863 MD AND DRILLED TO 2239 MD Max. Temp. : 88.0 deg F Survey/ TF%: 100 / 100 DGR RT/Rec%: 80 / 0 EWR RT/Rec%: 80 / 100 CNP RT/Rec%: 0 / 0 SFD RT/Rec%: 0 / 0 SLD RT/Rec%: 0 / 0 AK-MM-95104 MWD End of Well Report Bitrun Summary MWD Run Time Data Drilling Data MWD Run : 10 Start Depth: 2239.0 ft Rig Bit : 1 End Depth : 5060.0 ft Hole Size: 8.50 in Footage : 2821.0 ft Run Start: 13:30 02-MAR-95 Flow Rate : 460.00 gpm Run End : 22:03 04-MAR-95 R.P.M. : 70 BRT hfs : 56.55 W.O.B. : 10 Klbs Circ.hrs : 6.84 R.O.P. : 73 ft/hr Oper.hrs : 56.77 S.P.P : 2000 psi sper, m~,-sum Mud Data Mud type : BLAND Weight/Visc: 10.10 / 42.0 Chlorides : 400 PV / YP : 14 / 16 Solids/Sand: 11.o / o.ol %Oil/ O:W : 0 / 0 :89 MWD Schematic PM / Pulser S/N : PO346PM6 Choke : 12 BHA Schematic Component Length O. D. I. D. PM sub Directional sensor PM to bit : 54.57 RLL S/N : PO345CRG6 CIM sub Downhole processor EWR Phase 4 sub Resistivity EWR to bit : 38.09 DGR sub Dual Gamma Ray DGR to bit : 30.74 12. 25 X HWDP 11. D.O.T. JARS 10. 4 X HWDP 9. CROSS-OVER SUB 8. 3 x DRILL COLLAR 7. FLOAT/CROSS-OVER SUB 6. PULSER / PM RT,T, STRIN~ 4. X/O SUB 3. NON MAG STABILIZER 2. 6 3/4" MACH lC 1.2 AKO 1. 8 1/2" HTC ATJ-PO5 748.66 5.000 3.063 33.20 6.250 2.250 120.25 5.000 3.063 3.65 6.375 2.812 91.41 6.438 2.875 2.87 6.875 2.625 20'.58 6.750 1.920 21.63 6.750 1.920 1.85 6.125 2.812 4.96 6.750 2.812 20.95 6.750 0.85 8.500 Comments MWD Performance DRILLED TO 5060 MD WHEN IT WAS DECIDED TO PULL THE STRING TO Max. Temp. : 113.0 deg F CHANGE THE BHA AND BIT. ALL DATA WAS RECOVERED FROM THE Survey/ TF%: 100 / 100 TOOL. DGR RT/Rec%: 100 / 100 EWR RT/Rec%: 100 / 100 CNP RT/Rec%: 0 / 0 SFD RT/Rec%: 0 / 0 SLD RT/Rec%: 0 / 0 AK-MM-95104 MWD End of Well Report Bitrun Summary MWD Run Time Data Drilling Data MWD Run : 11 Start Depth: 5060.0 ft Rig Bit : 2 End Depth : 5997.0 ft Hole Size: 8.50 in Footage : 937.0 ft Run Start: 22:30 04-MAR-95 Flow Rate : 420.00 gpm Run End : 23:26 05-MAR-95 R.P.M. : 50 BRT hrs : 24.93 W.O.B. : 20 Klbs Circ.hrs : 2.63 R.O.P. : 60 ft/hr Oper.hrs : 25.12 S.P.P : 1950 psi ~p~r",r',~-~un Mud Data Mud type : BLAND Weight/Visc: 10.10 / 42.0 Chlorides : 300 PV / YP : 14 / 17 Solids/Sand: 12.0 / 0.01 %0il/ O:W : 0 / 0 :88 MWD Schematic PM / Pulser S/N : P0346PM6 Choke : 12 BHA Schematic Component Length O.D. I. D. I PM sub Directional sensor PM to bit : 64.48 RLL S/N : P0345CRG6 CIM sub Downhole processor EWR Phase 4 sub Resistivity EWR to bit : 48.00 DGR sub Dual Gamma Ray DGR to bit : 40.65 13. 25 X HWDP 12. D.O.T. JARS 11. 4 X HWDP 10. CROSS-OVER SUB 9. 3 x DRILL COLLAR 8. FLOAT/CROSS-OVER SUB 7. PULSER / PM 6. RLL STRIN~ 5. X/O SUB 4. NON MAG STABILIZER 3. LEAD COLLAR 2. 6 3/4" MACH lC 1.2 AKO 1. 8 1/2" STC MFDSSHL Comments 748.66 5.000 3.063 33.20 6.250 2.250 120.25 5.000 3.063 3.65 6.375 2.812 91.41 6.438 2.875 2.87 6.875 2.625 20.58 6.750 1.920 2i.63 6.750 1.920 1.85 6.125 2.812 4.96 6.750 2.812 9.87 6.188 2.750 21.04 6.750 0.80 8.500 MWD Performance DRILLED TO 5997 MD WHEN THE BHA WAS PULLED FOR A BIT CHANGE. Max. Temp. : 113.0 deg F ALL DATA WAS RECOVERED FROM THE TOOL. Survey/ TF%: 100 / 100 DGR RT/Rec%: 100 / 100 EWR RT/Rec%: 100 / 100 CNP RT/Rec%: 0 / 0 SFD RT/Rec%: 0 / 0 SLD RT/Rec%: 0 / 0 I AK-MM-95104 MWD End of Well Report Bitrun Summary MWD Run Time Data Drilling Data MWD Run : 12 Start Depth: 5997.0 ft Rig Bit : 3 End Depth : 7804.0 ft Hole Size: 8.50 in Footage : 1807.0 ft Run Start: 23:45 05-MAR-95 Flow Rate : 460.00 gpm Run End : 09:25 07-MAR-95 R.P.M. : 60 BRT hrs : 33.67 W.O.B. : 10 Klbs Circ.hrs : 5.35 R.O.P. : 99 ft/hr Oper.hrs : 33.82 S.P.P : 2500 psi Mud Data Mud type : BLAND Weight/Visc: 10.10 / 41.0 Chlorides : 300 PV / YP : 15 / 16 Solids/Sand: 12.0 / 0.01 %0il/ O:W : 0 / 0 :88 MWD Schematic BHA Schematic PM / Pulser S/N : PO346PM6 Choke : 12 Component Length O. D. I.D. I PM sub Directional sensor PM to bit : 64.48 RLL S/N : PO345CRG6 CIM sub Downhole processor EWR Phase 4 sub Resistivity EWR to bit : 48.00 DGR sub Dual Gamma Ray DGR to bit : 40.65 13. 25 X HWDP 12. D.O.T. JARS 11. 4 X HWDP 10. CROSS-OVER SUB 9. 3 x DRILL COLLAR 8. FLOAT/CROSS-OVER SUB 7. PULSER / PM 5. x/o SUB 4. NON MAG STABILIZER 3. LEAD COLLAR 2. 6 3/4" MACH lC 1.2 AKO 1. 8 1/2" HYC DS40HF 748.66 5.000 3.063 33.20 6.250 2.250 120.25 5.000 3.063 3.65 6.375 2.812 91.41 6.438 2.875 2.87 6.875 2.625 20.58 6.750 1.920 21'.63 6.750 1.920 1.85 6.125 2.812 4.96 6.750 2.812 9.87 6.188 2.750 21.04 6.750 0.80 8.500 Comments DRILLED TO 7804 MD. PULLED STRING TO SWAP RLL COLLAR FOR TEE TRIPLE COMBO COLLAR AND BHA CHANGE. ALL DATA WAS RECOVERED FROM THE TOOL. MWD Performance Max. Temp. : 122.0 deg F Survey/ TF%: 100 / 100 DGR RT/Rec%: 100 / 100 EWR RT/Rec%: 100 / 100 CNP RT/Rec%: 0 / 0 SFD RT/Rec%: 0 / 0 SLD RT/Rec%: 0 / 0 AK-MM-95104 MWD End of Well Report Bitrun Summary MWD Run Time Data Drilling Data MWD Run : 13 Start Depth: 7804.0 ft Rig Bit : 3 End Depth : 7891.0 ft Hole Size: 8.50 in Footage : 87.0 ft Run Start: 10:41 07-M~LR-95 Flow Rate : 460.00 gpm Run End : 21:45 07-MAR-95 R.P.M. : 60 BRT hrs : 11.07 W.O.B. : 10 Klbs Circ.hrs : 2.01 R.O.P. : 65 ft/hr Oper.hrs : 11.47 S.P.P : 2500 psi Mud Data Mud type : BLAND Weight/Visc: 10.10 / 41.0 Chlorides : 300 PV / YP : 15 / 16 Solids/Sand: 12.0 / 0.01 %0il/ O:W : 0 / 0:88 MWD Schematic BHA Schematic Length O.D. I .D. I Component PM / Pulser S/N : PO346PM6 Choke : 12 PM sub Directional sensor PM to bit : 78.87 RLL S/N : PO335CRNDG6 CIM sub Downhole processor EWR Phase 4 sub Resistivity EWR to bit : 62.40 CNP sub Neutron Porosity CNP to bit : 55.01 SFD sub Density SFD to bit : 44.47 DGR sub Dual Gamma Ray DGR to bit : 40.65 13. 25 X HWDP 12. D.O.T. JARS ii. 4 x ~P io. CROSS-OVER SUB 9. 3 x DRILL COLLAR 8. FLOAT/CROSS-OVER SUB 7. PULSER / PM 6. RLL STRING 5. X/O SUB 4. NON MAG STABILIZER 3. LEAD COLLAR 2. 6 3/4" MACH lC 1.2 AKO 1. 8 1/2" HYC DS40HF Comments 748.66 5.000 ' 3.063 33.20 6.250 2.250 120.25 5.000 3.063 3.65 6.375 2.812 91.41 6.438 2.875 2.87 6.875 2.625 20.58 6.750 1.920 36'.02 6.750 1.920 1.85 6.125 2.812 4.96 6.750 2.812 9.87 6.188 2.750 21.04 6.750 0.80 8.500 MWD Performance DRILLED TO 7891 MD WHEN THE MOTOR FAILED. THE BHA WAS THEN TRIPPED TO CHANGE OUT THE MOTOR. ALL DATA WAS RECOVERED FROM THE TOOL. AK-MM-95104 Max. Temp. : 133.0 deg F Survey/ TF%: 0 / 0 DGR RT/Rec%: 100 / 100 EWR RT/Rec%: 100 / 100 CNP RT/Rec%: 100 / 100 SFD RT/Rec%: 100 / 100 SLD RT/Rec%: 0 / 0 MWD End of Well Report Bitrun Summary MWD Run Time Data Drilling Data MWD Run : 14 Start Depth: 7891.0 ft Rig Bit : 3 End Depth : 8850.0 ft Hole Size: 8.50 in Footage : 959.0 ft Run Start: 22:20 07-MAR-95 Flow Rate : 450.00 gpm Run End : 14:35 09-MAR-95 R.P.M. : 60 BRT hrs : 40.25 W.O.B. : 10 Klbs Circ.hrs : 0.00 R.O.P. : 42 ft/hr Oper.hrs : 40.47 S.P.P : 2400 psi Mud Data Mud type : BLAND Weight/Visc: 10.10 / 41.0 Chlorides : 300 PV / YP : 15 / 14 Solids/Sand: 12.0 / 0.01 %0il/ O:W : 0 / 0 :88 MWD Schematic PM / Pulser S/N : PO346PM6 Choke : 12 BHA Schematic Component Length O. D. I. D. I PM sub Directional sensor PM to bit : 84.07 RLL S/N : PO335CRNDG6 CIM sub Downhole processor EWR Phase 4 sub Resistivity EWR to bit : 67.60 CNP sub Neutron Porosity CNP to bit : 60.21 SFD sub Density SFD to bit : 52.67 DGR sub Dual Gamma Ray DGR to bit : 45.85 Comments 14. 25 X ~WDP 13. D.O.T. JARS 12. 4 X HWDP 11. CROSS-OVER SUB 10. 3 x DRILL COLLAR 9. FLOAT/CROSS-OVER SUB 8. PULSER / PM 7. RLL STRING 6. x/o sub 5. NON MAG STABILIZER 4. LEAD COLLAR 3. X/O SUB 2. 6 3/4" F2000 1 BH 1. 8 1/2" HYC DS40HF DRILLED TO TD AT 8850 MD, 7532 TVD. ALL RECORDED DATA WAS RECOVERED FROM THE TOOL. 748.66 33.20 120.25 3.65 91.41 2.87 20.58 36.02 1'.85 4.96 9.87 1.53 24.71 0.80 5.000 3.063 6.250 2.250 5.000 3.063 6.375 2.812 6.438 2.875 6.875 2.625 6.7501.92 6.750 6.125 6.750 6.188 6.750 6.750 8.500 1. 920 2. 812 2. 812 2.750 2.750 MWD Performance Max. Temp. : 129.2 deg F Survey/ TF%: 100 / 100 DGR RT/Rec%: 100 / 100 EWR RT/Rec%: 100 / 100 CNP RT/Rec%: 100 / 100 SFD RT/Rec%: 100 / 100 SLD RT/Rec%: 0 / 0 AK-MM-95104 MWD End of Well Report spenn~-s~n Section Se : Survey Data AK-MM-95104 MWD End of Well Report SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA, INC. WILDCAT/ALPINE ~IB 501032021102 NORTH SLOPE COMPUTATION DATE: 4/ 7/95 DATE OF SURVEY: 031095 MWD SURVEY JOB NUMBER: AK-MM-950104 KELLY BUSHING ELEV. = 38.00 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 1752 1752.32 1714.32 1863 1862.86 1824.86 1867 1867.68 1829.68 1899 1899.10 1861.10 1994 1993.53 1955.53 1 14 S 55.52 E .00 6.86S 12.95E 1 6 S 49.87 E .16 8.22S 14.75E 3 48 S 43.80 E 56.29 8.37S 14.89E 5 2 S 39.26 E 4.06 10.19S 16.49E 7 49 S 39.65 E 2.94 18.41S 23.27E 11.12 13.05 13.24 15.52 25.65 2088 2086.64 2048.64 2181 2177.26 2139.26 2273 2267.55 2229.55 2367 2357.26 2319.26 2460 2445.19 2407.19 2553 2531.17 2493.17 2646 2615.65 2577.65 2739 2698.15 2660.15 2835 2779.91 2741.91 2929 2858.25 2820.25 10 7 S 31.41 E 2.79 30.43S 31.69E 12 5 S 23.59 E 2.67 46.23S 39.79E 14 41 S 20.89 E 2.89 66.15S 47.88E 17 42 S 21.41 E 3.21 90.45S 57.30E 20 34 S 23.15 E 3.14 118.67S 68.89E 23 16 S 23.27 E 2.92 150.47S 82.53E 26 9 S 22.88 E 3.10 186.25S 97.77E 29 37 S 21.93 E 3.75 226.63S 114.40E 33 0 S 20.49 E 3.61 273.02S 132.36E 35 27 S 19.74 E 2.63 323.06S 150.68E 39.92 57.58 79.08 105.14 135.64 170.23 209.11 252.77 302.51 355.79 3023 2933.56 2895.56 3117 3006.83 2968.83 3211 3079.05 3041.05 3305 3151.40 3113.40 3397 3222.10 3184.10 37 52 S 20.18 E 2.58 375.76S 169.83E 39 19 S 21.32 E 1.72 43.0.44S 190.55E 39 40 S 22.42 E .84 485.67S 212.73E 39 58 S 21.52 E .69 541.62S 235.29E 40 9 S 21.61 E .22 596.91S 257.15E 411.84 470.31 529.83 590.15 649.61 3492 3294.53 3256.53 3579 3361.06 3323.06 3673 3432.28 3394.28 3767 3504.92 3466.92 3862 3577.25 3539.25 40 25 S 22.51 E .67 653.82S 280.21E 40 9 S 20.95 E 1.19 706.21S 301.09E 40 5 S 21.21 E .19 762.21S 322.68E 40 0 S 21.09 E .13 819.16S 344.71E 40 7 S 20.18 E .63 876.08S 366.14E 711.00 767.41 827.42 888.48 949.30 3955 3648.17 3610.17 4048 3719.67 3681.67 4150 3797.60 3759.60 4235 3863.01 3825.01 4337 3941.99 3903.99 39 57 S 20.23 E .19 932.01S 386.73E 39 58 S 20.39 E .11 988.21S 407.53E 39 54 S 19.09 E .82 1049.63S 429.57E 39 43 S 19.76 E .55 1101.06S 447.70E 39 25 S 20.00 E .34 1162.45S 469.90E 1008. 89 1068.80 1134.02 1188.52 1253 . 78 4430 4013.87 3975.87 4525 4087.97 4049.97 4618 4161.37 4123.37 4713 4237.63 4199.63 4799 4308.25 4270.25 39 8 S 19.57 E .42 1217.76S 489.80E 38 49 S 18.96 E .52 1274.37S 509.59E 37 7 S 20.55 E 2.11 1328.28S 528.93E 35 13 S 20.01 E 2.04 1380.57S 548.26E 34 12 S 19.52 E 1.23 1426.61S 564.81E 13 12.54 1372 .46 1429. 71 1485.45 1534.34 sp~ f-SUN DRILLING SERVICES ANCHOR_AGE ALAS KA PAGE 2 ARCO ALASKA, INC. WILDCAT/ALPINE #lB 501032021102 NORTH SLOPE COMPUTATION DATE: 4/ 719 DATE OF SURVEY: 031095 MWD SURVEY JOB NUMBER: AK-MM-950104 KELLY BUSHING ELEV. = 38.00 OPERATOR: ARCO ALASKA INC FT. TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA VERTICAL DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 4901 4392.08 4994 4467.86 5087 4541.65 5182 4616.33 5276 4690.72 4354.08 4429.86 4503.65 4578.33 4652.72 35 3 S 18.93 E .91 1481.28S 583.87E 36 50 S 20.22 E 2.08 1533.06S 602.30E 37 44 S 20.43 E .97 1585.77S 621.82E 37 54 S 21.08 E .45 1639.97S 642.36E 38 4 S 21.31 E .23 1694.13S 663.36E 1592.20 1647.13 1703.32 1761.28 1819.37 5370 4764.99 5462 4837.00 5557 4911.62 5648 4982.82 5734 5049.51 4726.99 4799.00 4873.62 4944.82 5011.51 38 5 S 21.55 E .16 1748.30S 684.62E 38 3 S 21.69 E .10 1800.74S 705.41E 38 2 S 21.20 E .32 1855.10S 726.76E 38 58 S 21.41 E 1.03 1907.88S 747.34E 40 27 S 21.30 E 1.72 1959.47S 767.52E 1877.57 1933.97 1992.38 2049.03 2104.43 5835 5124.92 5930 5193.70 6022 5261.01 6116 5329.44 6209 5397.49 5086.92 5155.70 5223.01 5291.44 5359.49 43 3 S 22.17 E 2.63 2022.01S 792.46E 43 8 S 20.88 E .94 2081.88S 816.07E 43 8 S 20.88 E .00 2140.81S 838.55E 43 7 S 21.13 E .18 2200.66S 861.53E 42 59 S 21.13 E .14 2259.96S 884.45E 2171.75 2236.11 2299.18 2363.29 2426.86 6300 5464.75 6394 5534.25 6488 5604.36 6582 5674.86 6676 5746.62 6766 5815.37 6861 5889.45 6949 5957.85 7046 6033.68 7137 6106.02 5426.75 5496.25 5566.36 5636.86 5708.62 5777.37 5851.45 5919.85 5995.68 6068.02 42 32 S 21.96 E .79 2317.82S 907.29E 41 54 S 22.78 E .89 2376.15S 931.30E 41 31 S 23.31 E .56 2433.66S 955.76E 40 46 S 21.82 E 1.32 2490.53S 979.40E 40 9 S 22.06 E .68 2547.30S 1002.27E 39 39 S 23.00 E .87 2600.40S 1024.29E 39 0 S 23.22 E .68 2656.23S 1048.11E 38 27 S 23.23 E .63 2706.65S 1069.75E 38 2 S 23.78 E .56 2761.47S 1093.59E 37 54 S 23.52 E .23 - 2813.18S 1116.24E 2489.06 2552.13 2614.60 2676.18 2737.39 2794.86 2855.53 2910.38 2970.12 3026.53 7230 6179.04 7325 6255.33 7424 6335.37 7517 6410.70 7611 6486.99 6141.04 6217.33 6297.37 6372.70 6448.99 37 13 S 23.59 E .74 2864.66S 1138.68E 36 28 S 24.59 E 1.01 2916.84S 1162.01E 36 2 S 23.99 E .56 2970.34S 1186.15E 35 42 S 24.22 E .38 3020.07S 1208.40E 35 30 S 24.35 E .23 3069.88S 1230.87E 3082.65 3139.75 3198.38 3252.79 3307.37 7704 6563.20 7803 6644.32 7890 6715.58 7984 6792.99 8071 6865.99 6525.20 6606.32 6677.58 6754.99 6827.99 35 5 S 24.82 E .53 3118.95S 1253.33E 34 48 S 24.18 E .47 3170.55S 1276.84E 34 53 S 24.32 E .13 3215.79S 1297.22E 33 42 S 24.46 E 1.27 3263.88S 1319.02E 32 58 S 24.81 E .85 3307.53S 1339.04E 3361.26 3417.88 3467.44 3520.17 3568.12 SPt PAGE 3 SUN DRILLING SERVICES ANCHORAGE ALASKA ARCO ALASKA, INC. WILDCAT/ALPINE ~iB 501032021102 NORTH SLOPE COMPUTATION DATE: 4/ 7/95 DATE OF SURVEY: 031095 MWD SURVEY JOB NUMBER: AK-MM-950104 KELLY BUSHING ELEV. = 38.00 OPER3ITOR: ARCO ALAStCA INC FT. TRUE SUB-SEA COURS COURSE MEASD VERTICAL VERTICAL INCLN DIRECT DEPTH DEPTH DEPTH DG MN DEGREE DLS TOTAL ION RECTANGULAR COORDINATES S DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8163 6943.37 8256 7022.27 8349 7101.21 8442 7181.25 8534 7259.78 6905.37 32 15 S 24.56 E .81 3352.52S 1359.72E 6984.27 31 48 S 24.74 E .48 3397.38S 1380.31E 7063.21 31 0 S 25.42 E .95 3441.04S 1400.74E 7143.25 31 3 S 24.80 E .35 3484.65S 1421.17E 7221.78 31 13 S 23.65 E .67 3527.92S 1440.64E 3617.56 3666.84 3714.95 3763.01 3810.40 8627 7339.63 8725 7424.37 8761 7455.36 8850 7531.58 7301.63 30 36 S 24.52 E .82 3571.56S 1460.15E 7386.37 30 20 S 26.02 E .82 3616.65S 1481.43E 7417.36 30 21 S 24.81 E 1.70 3633.04S 1489.21E 7493.58 30 21 S 24.81 E .00 3673.56S 1507.95E 3858.16 3907.90 3926.00 3970.57 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3971.01 FEET AT SOUTH 22 DEG. 19 MIN. EAST AT MD = 8850 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 158.54 DEG. SP~ PAGE 4 f-SUN DRILLING SERVICES ANCHOR_AGE ALASKA ARCO ALASKA, INC. WILDCAT/ALPINE ~IB 5o1o32o211o2 NORTH SLOPE COMPUTATION DATE: 7/95 DATE OF SURVEY: 031095 JOB NUMBER: AK-MM-950104 KELLY BUSHING ELEV. = 38.00 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 1752 1752.32 1714.32 6.86 S 12.95 E .12 2752 2709.45 2671.45 232.66 S 116.81 E 42.99 3752 3493.05 3455.05 809.86 S 341.12 E 259.39 4752 4269.50 4231.50 1401.72 S 555.96 E 482.94 5752 5062.88 5024.88 1970.18 S 771.71 E 689.56 42.87 216.40 223.55 206.62 6752 5804.78 5766.78 2592.32 S 1020.86 E 947.66 7752 6602.11 6564.11 3143.78 S 1264.81 E 1150.33 8752 7447.40 7409.40 3628.80 S 1487.25 E 1305.04 8850 7531.58 7493.58 3673.56 S 1507.95 E 1318.42 258.10 202.67 154.72 13.38 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 ARCO ALASKA, INC. WILDCAT/ALPINE ~iB 501032021102 NORTH SLOPE COMPUTATION DATE: 4/ 7/95 DATE OF SURVEY: 031095 JOB NUMBER' AK-MM-950104 KELLY BUSHING ELEV. = 38.00 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 1752 1752.32 1714.32 1838 1838.00 1800.00 1938 1938.00 1900.00 2039 2038.00 2000.00 6.86 S 12.95 E 7.91 S 14.38 E 13.17 S 18.93 E 23.64 S 27.23 E .12 .14 .02 .43 .30 1.33 .90 2140 2138.00 2100.00 2243 2238.00 2200.00 2347 2338.00 2300.00 2452 2438.00 2400.00 2560 2538.00 2500.00 38.58 S 36.42 E 2.87 1.54 59.17 S 45.16 E 5.35 2.48 84.86 S 55.11 E 9.09 3.74 116.20 S 67.84 E 14.67 5.58 153.21 S 83.71 E 22.49 7.82 2671 2638.00 2600.00 2785 2738.00 2700.00 2905 2838.00 2800.00 3029 2938.00 2900.00 3157 3038.00 3000.00 3287 3138.00 3100.00 3418 3238.00 3200.00 3549 3338.00 3300.00 3680 3438.00 3400.00 3811 3538.00 3500.00 196.60 S 102.10 E 248.45 S 123.01 E 309.49 S 145.81 E 379.00 S 171.02 E 454.23 S 199.87 E 531.17 S 231.17 E 609.39 S 262.09 E 688.03 S 294.12 E 766.71 S 324.42 E 845.05 S 354.69 E 33.06 10.56 47.65 14.60 67.04 19.39 91.43 24.39 119.86 28.43 149.86 30.00 180.53 30.67 211.73 31.19 242.52 30.80 273.12 30.59 3941 3638.00 3600.00 4072 3738.00 3700.00 4202 3838.00 3800.00 4332 3938.00 3900.00 4461 4038.00 4000.00 924.02 S 383.78 E 1002.61 S 412.88 E 1081.49 S 440.68 E 1159.37 S 468.78 E 1236.27 S 496.38 E 303.82 30.70 334.29 30.47 364.66 30.36 394.48 29.82 423.62 29.14 4589 4138.00 4100.00 4713 4238.00 4200.00 4835 4338.00 4300.00 4957 4438.00 4400.00 5082 4538.00 4500.00 1311.72 S 522.72 E 1380.82 S 548.35 E 1445.67 S 571.56 E 1512.06 S 594.56 E 1583.12 S 620.83 E 451.64 28.02 475.88 24.24 497.31 21.43 519.53 22.22 544.99 25.46 5209 4638.00 4600.00 5336 4738.00 4700.00 5463 4838.00 4800.00 5590 4938.00 4900.00 5719 5038.00 5000.00 1655.71 S 648.43 E 1728.62 S 676.85 E 1801.47 S 705.70 E 1874.35 S 734.23 E 1950.32 S 763.95 E 571.60 26.62 598.59 26.98 625.63 27.04 652.61 26.98 681.68 29.07 5853 5138.00 5100.00 2033.33 S 797.07 E 715.81 34.13 SPt,, SUN DRILLING SERVICES A_NCHO~GE ALASKA PAGE 6 ARCO ALASKA, INC. WILDCAT/ALPINE #lB 501032021102 NORTH SLOPE COMPUTATION DATE: 4/ 7/95 DATE OF SURVEY: 031095 JOB NUMBER: AK-MM-950104 KELLY BUSHING ELEV. = 38.00 OPERATOR' ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 5990 5238.00 5200.00 2120.66 S 830.87 E 752.81 6127 5338.00 5300.00 2208.13 S 864.42 E 789.84 6264 5438.00 5400.00 2295.04 S 898.12 E 826.55 6399 5538.00 5500.00 2379.25 S 932.60 E 861.76 6533 5638.00 5600.00 2461.00 S 967.52 E 895.56 37.01 37.03 36.71 35.21 33 .80 6665 5738.00 5700.00 2540.56 S 999.54 E 927.30 6795 5838.00 5800.00 2617.66 S 1031.62 E 957.59 6924 5938.00 5900.00 2692.16 S 1063.53 E 986.31 7051 6038.00 6000.00 2764.56 S 1094.95 E 1013.70 7178 6138.00 6100.00 2835.97 S 1126.16 E 1040.49 31.74 30.29 28.72 27.40 26.78 7303 6238.00 6200.00 2905.19 S 1156.68 E 1065.88 7427 6338.00 6300.00 2972.09 S 1186.93 E 1089.94 7551 6438.00 6400.00 3037.97 S 1216.45 E 1113.27 7674 6538.00 6500.00 3102.88 S 1245.89 E 1136.08 7796 6638.00 6600.00 3166.54 S 1275.04 E 1158.15 25.39 24.06 23.34 22.80 22.08 7918 6738.00 6700.00 3230.04 S 1303.66 E 1180.02 8038 6838.00 6800.00 3291.04 S 1331.42 E 1200.41 8157 6938.00 6900.00 3349.44 S 1358.31 E 1219.29 8275 7038.00 7000.00 3406.24 S 1384.39 E 1237.22 8392 7138.00 7100.00 3461.02 S 1410.23 E 1254.13 21.86 20.39 18.89 17.93 16.91 8508 7238.00 7200.00 3515.83 S 1435.34 E 1270.90 8625 7338.00 7300.00 3570.69 S 1459.75 E 1287.54 8741 7438.00 7400.00 3623.83 S 1484.89 E 1303.55 8850 7531.58 7493.58 3673.56 S 1507.95 E 1318.42 16.77 16.64 16.01 14.87 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPERRT-SUN DR [LL [ NO bERV [CES VERT I CRL/Hi3R I ZONTRL WI~/RLPINE =lB 5131~110~ NSR'I'H PROJECTION S'I'RRT TVD = 1752. ~2 FINIal'! I'VD = '~31.B9 VERT SECT ~:~ILE IS 11300 FEE'r/IN ~ 51~CT 5CRI.E IS 1500 FEET/IN 7531.7 LLI I'-- lt~IZBNTRL DISPt.~C~ IS 3~71.08 88~0 VERT I CRL SECT I ON 39'7,1.08 FEET RT S ~2 DEG 19 MI~ E SSDS GEOMAG SHEET SSDS Job # AK-MM-950104 Date l/21/95 Field Name WEST COLVILLE EXPLORATION Lease/Block # N/A Rig Name POOL 6 Well Identificaton ALPINE NO. lB Slot # N/A Side track NO Northings 5972482.250 ft* Eastin gs 375455.030 ft* Latitude 70:19:59.612 N* Longitude 151:00:37.253 W* Datum & Projection I Data Source (y/n) SSDS MAGUTM BGM1992 I Geomag. Values Office Generated Field Generated Dip Angle (deg) 80.373 80.373 Total Intensity (nT) 57183 57183 Declination (deg)* 27.885 27.885 Convergence (deg)* N/A N/A If No, be specific; Signature Date SSDS District Supervisor SSDS Lead Engineer DWD JORPs Version 2.1 March 1994 1/21/95 1/21/95 * Where appropriate MWD End of Well Report Section Se : Service Interrupt Reports AK-MM-95104 MWD End of Well Report spenng-sun Failure Report MWD run number Rig bit number MWD run start time/date MWD run end time/date Time / Date of failure Depth at time of failure : 09 1 : 19:50 01-MAR-95 : 12:15 02-MAR-95 : 06:00 02-MAR-95 : 2239.0 ft Rig Activity : DRILLING AT TIME OF FAILURE. Description of failure Action taken : TOOL FAILED TO PULSE AFTER A SHORT WIPER TRIP. : DRILLED TWO SINGLES WITHOUT STEERING DATA. Operations impact : LOST 62' OF REALTIME GAMMA RAY DATA. NO RECORDED DATA RECOVERED. UNABLE TO RECOVER 62' OF EWR-P4 INFORMATION FROM REALTIME OR RECORDED DATA. Lost rig hours: 8.0 Reason for failure : CIM INSERT SENT TO LAFAYETTE FOR FAILURE ANALYSIS. AK-MM-95104 MWD End of Well Report sperw W-sun DRILLING ~:ERVIr'E'=: 5631 Silverado Way, Suite G Anchorage, Alaska 99518 Tel. · 907-563-3256 Fax '907-563-7252 Telex · N/A Versatile Reporting Application This report was produced using VERA version 2.0 Facsimile Cover Sheet To' Company: Phone: Fax: HOWARD OKLAND Alaska O&G Conservation Comm. 907-279-1433 907-276-7542 From: Company: Phone: Fax: Email- Timothy J. Ryherd Alaska D.N.R.- Div. of Oil & Gas (907)762-2140 (907)562-3852 74222.2332 @ compuserve.com Date: 4/3/95 Pages including this cover page: 1 Larry: At your earliest convenience please prepare the following well data for me: · Shell DF-47 (Seal 1) #1 (83-0074)--well history, completion report, drilling permit, horizon picks, directional surveys, core descriptions, core analyses, production test summaries and production test detailed reports (NO WELL LOGS NEEDED AT THIS TIME). · Shell DF-57 (Seal 3) #1 (84-0093)--well history, completion report, drilling permit, horizon picks, directional surveys, core descriptions, core analyses, production test summaries and production test detailed reports (NO WELL LOGS NEEDED AT THIS TIME). · ARCO Pt Mclntyre #P1-12 (AKA: Pt. Mclntyre #11)(91-0013)--all well logs, well history, completion report, drilling permit, horizon picks, directional surveys, core descriptions, core analyses, production ,.......¢.~..test sug:~:L--~a, de_~ and production test detailed reports. ARCO I~ne ~1~94-0172)--all well logs, well history, completion report, drilling permit, horizon picks, / directionaPs'u-rveys, core descriptions, core analyses, production test summaries and production test ..-/' (:J. etailed.._r, ePoct~(CONFIDENTIAL WELL DATA). </I ~..~RCO~pine #1A~e5-oo~--all well logs, well history, completion report, drilling permit, horizon ~-- - pick~d~t~rveys, core descriptions, core analyses, production test summaries and production t.~.est'detai .[ed__r_c_p~rts (CONFIDENTIAL WELL DATA). · .~"'ARCO~pine #1B~95-0020)--all well logs, well history, completion report, drilling permit, horizon "" picks, direc-0tiortah~'urveys, core descriptions, core analyses, production test summaries and production test detailed reports (CONFIDENTIAL WELL DATA). When this data is available for me to pick up, please give me a call. Sincerely, Tim Ryherd TRANSMITTAL TO: State of Alaska AOGCC 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Robert P. Crandall DATE: March 23, 1995 AIRBILL- Airland # 646244 AFT#- ABV05-03-23-01 CHARGE CODE# AX9329 OPERATOR- ARCO Alaska INC. SAMPLE TYPE: Ditch cuttings NAME: Various Alpine wells NUMBER OF BOXES: 11 boxes s^~.,es s~.~: ~~ ~ -~ ? :~ ~ Alpine #1 Alpine #lA gl.pine #lB 1 20-7500' 1 800-9940' 1800-8850' , SENT BY: Dan Przywojski UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: RECEIVED BY' Arco Alaska, Inc. 619 E. Ship Creek Ave Anchorage, AK. 99510 Attn: Suite 104 DATE- /x, R3[/,-[~O03-93 242-2603 ARCO Alaska, Inc. 7~os~). C: March 23, 1995 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Report of Sundry Well Operations Form 404 ARCO Alpine #lB Permit No. 95-20 Dear Commissioner Johnston, Attached is the Report of Sundry Well Operations, Form 404 for the Alpine #lB well. Operations on the Alpine #lB well were shut down and the rig was releasd on March 12, 1995 after setting 7" casing and installing the wellhead equipment. Included with the Form 407 are the "as built" survey showing the surface location, a well bore diagram showing the status of the well, and daily drilling report summaries. The geologic information will be submitted under separate cover. Form 403 for the operation shutdown was approved March 14 (Approval No. 95-048). If you have questions or require additional information, please contact Fred Johnson at 265-1492. Sincerely, Fred Johnson Drilling Enginee'r RECEIVED MAR 24 1995 A~aska 0il & Gas Cons, C0mn",lssi0r,, gnch0ra? Af.13f3-60()3.93 '~fi 2~2,503 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown X Pull tubing Alter casing Stimulate __ Plugging Perforate Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1465' FSL, 2250' FWL, Sec. 1, T11N, R4E, UM At top of productive interval 2002' FNL, 1617' FEL, Sec. 12, T11N, R4E, UM At effective depth At total depth 2207' FNL, 1522' FEL, Sec. 12, T11N, R4E, UM 6. Datum elevation (DF or KB) 38' RKB 7. Unit or Property name N/A 8. Well number Alpine #1B 9. Permit number/approval number 95-2O 10. APl number 50-1 03-20211-02 11. Field/Pool Wildcat feet 12. Present well condition summary Total Depth: measured 8850' true vertical 7531 ' Effective depth: measured 8407' true vertical 7151' Casing Length Size Structural Conductor 8 0' 2 0" Surface 1 735' 1 3-3/8" Intermediate Production 8809' 7" Liner Perforation depth: measured feet feet Plugs (measured) feet feet Junk (measured) Cemented 350 sx ASl 350 sx AS III 650 sx ASl 235 sx Class G Measured depth 110' 1765' MD 8839' True vertical depth 110' 1765' TVD 7522' true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) NONE NONE RECEIVED MAR 2,,4 1995 Olt & Gas Cons. O0~lfli~sio~ Anchora .~ 13. Stimulation or cement squeeze summary Intervals treated (measured) NONE Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water- Bbl Casing Pressure I',Et4E Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil _ Gas Suspended (EXPLORATION) Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 /89 Title Drilling Engineer Date SUBMIT IN DUPLICATE ICE PAD LIMITS ALPINE #1 55o' 35.5' ~ j~ Scde 1"= 2 Mi/es ~u~.~ STOR*~E ALPINE ~ ~ ~ ~ 252' i , LOCA~D ~IN PRO~AC~D ~ i ~f SEC. 1, ~. 11 N., RGE. 4 E. ,~ ,~ UMIAT MERIDIAN LAT. = 70' 19' 59.612" ~ J LONG. = 151' 00' 57.255" ~ 1,468' F.S.L., 2,248' F.W.L Y = 5,972,482.25 TOP ICE PAD ELEV.= 7.6' ~.~sks. Oil & Gas 6o~s. Commissio~ NO~S A.chora: ~ 1. BASIS OF HORIZONTAL LOCA~ON AND ~V~ON IS U.S.~.S. ~ONUMEN~ ~ DOORDINA ~S SHO~ ARE A~SKA STA~ P~NE zoN~ 4, N.A.O. 2Z ~~~. ~. ~A~ OF SUR~. ~/~/95. ~ ~ 4. ~VA ~ONS SHO~ ARE B.P.M.~ ~ .' ~ ".-~ · ' ~~ /~ ~ -'" ] UC~SED TO PRAC~CE ~ND SURe,Ne IN ~E ETA ~ OF ~--'"~~~~~~ ~A AND ~AT ~lS P~T R~RES~ A ~R~Y .~,~ % ,~~ ..~. ~ ~AT A~ DIM~ONE ~O O~ER DETAILS ARE CORRECT ~ ~ .,,,, .... ,,. ~_~ AS OF JAN 15, 1995. LOUNSBURY C/, 5 k ssom s, mc. M1 ~ O0 " CONDUCTOR ~ ICE PAD Subsidiary of Atlantic Richfield Company AS-BUILT C~D R~ NO. l DRA"NO N~ ]sH~= IRev= ~sm172 ~/~6~95 CEA-MIXX-601D172 ALPINE #1 B WELLBORE SCHEMATIC oHUTDOWN STATUS VR PLUGS INSTALLED WELLHEAD 20" CONDUCTOR AT 120' RKB 16" HOLE L 8-1/2" HOLE BRINE 10.6 LB/GAL DIESEL 6.75 LB/GAL CEMENT TD 8850' MD 7531' TVD 3-1/2" 5000 PSI LOWER TREE ASSEMBLY J BACK PRESSURE VALVE INSTALLED IN TUBING HANGER 1000' DIESEL CAP IN THE 7" CASING 13-3/8" SURFACE CSG AT 1765' RKB A,i~sk~ 0il ,& 8as Co~s. Cor~Jflissiol~ TOP OF CEMENT +7900' J-4 INTERVAL +8407'-8493' PBTD 8747' 7" PRODUCTION CSG AT TD +8839' FJ 3/13/95 ~0e:03/21/95 Page: i ARCO Alaska Inc. DAILY DRILLING REPORT WELL:ALPINE #lB RIG:POOL ~6 WI: 56% SECURITY:2 WELLID: AX9330 AFE: AX9330 TYPE:EXP AFE EST:S 0H/ 0M AREA/CNTY:NORTH SLOPE BOROUGH STATE:AK API NUMBER- FIELD: COLVILLE SPUD: START COMP: FINAL: 03/02/95 ( 1) TD: 2177'(2177) SUPV:DCB MW: 9.9 PV/YP: 9/ 9 APIWL: 8.4 DISPLACE HOLE W/ NEW MUD. Tagged top of cement at 1645' Dressed off cement plug to 1800' RIH with 8-1/2" bit. Drill 1800'-1940' Kicked off. Drilled 8-1/2" hole from 1940' to 2177' 03/03/95 TD: 3460' SUPV:DCB 2) 1283 MW: 10.2 PV/YP: 18/15 APIWL: 7.0 DRILLING 8 1/2" HOLE Drilled and logged (LWD) 8-1/2" hole from 2177' to 3460' as per directional plan. 03/04/95 TD: 4676' SUPV:DCB 3) 1216 MW:.10.2 PV/YP: 14/16 APIWL: 6.2 DRILLING 8 1/2" HOLE Drilled and logged (LWD) 8 1/2" hole frem 3460' to 4676' as Der directienal plan. 03/05/95 TD: 5282' SUPV:DCB 4) 606 MW: 10.2 PV/YP: 15/22 APIWL: 6.0 DRILLING 8 1/2" HOLE Drilled and logged (LWD) 8-1/2" hole from 4676" to 5282' as per directional plan. Made bit trip at 5059' 03/06/95 TD: 6308' SUPV:DCB 5) 1026 MW: 10.1 PV/YP: 15/18 APIWL: 6.0 DRILLING 8-1/2" HOLE AT 6308' Drilling f/5282-5995' Slide/rotate to regain angle. Bit sliding good. Circulate f/trip. Round trip change bits. Drilling f/5995-6308' 03/07/95 TD: 7804' SUPV:DCB 6) 1496 MW: 10.1 PV/YP: 15/15 APIWL: 5.6 TOH F/LWD TOOL Drilling f/6308-7804' Attempts at sliding to control angle unsuccessful. Angle drop varied f/-0.2/-0.8 deg. per 100 ft. CBU f/trip. POH to pickup neutron-density LWD tool. 03/08/95 TD: 7945' SUPV:DRH 7) 141 MW: 10.1 PV/YP: 13/15 APIWL: 5.6 DRILLING AND LOGGING W/MWD POOH for density equipped MWD check motor and bit. Drilling and MWD logging from 7804 to 7802' Test BOPE 500 psi low and 5000 psi high. Drilling and MWD log and survey from 7892' to 7945' ~e:03/21/95 Page: 2 03/09/95 TD: 8788' SUPV:DRH 8) 843) ARCO Alaska Inc. DAILY DRILLING REPORT MW: 10.0 PV/YP: 14/15 DRILLING AND LOGGING W/P~D Drill, log and survey from 7945' to 8788' AP!WL: 4.4 03/10/95 TD: 8850' SUPV:DRH o) 62) ~: !O.0 PV/YP: 12/14 APIWI,: 4.6 CIRCULATE AND COND. FOR 7" CSG Drill, leg and survey frem 8788' to 8850'. Pump Hi Vis sweep, circulate hole clean and pump dry job. Pick up RR bit #3 and add stabilizer te steel dc. string. RIH w/GR/CNL/LDT/DSI/ADT. Toels stuck at 7500' while RIH. Worked free in 1 hour. POOH with wireline zeols and rig down logging equipment. RiH to cenditien hele fer casing. · Circulate and cenditien fer 7" casing at TD. WELL:ALPINE #lB RIG:POOL ~6 WI: 56% SECURITY:2 WELLID: AX9323 AFE: *AX9323 TYPE:EXP AFE EST:$ OM/ OM AREA/CNTY:NORTH SLOPE BOROUGH STATE:AK API NUMBER: FIELD: COLVILLE SPUD: START COMP: FINAL: 03/11/95 TD: 8850' SUPV:DRM 1) 8850 MW: 10.3 PV/YP: 15/13 APIWL: 4.8 CIRC. & CONDITION PRIOR TO CHT Circulate at 8850' te cenditien for 7" casing. Rig up ~e run 7" casing. Ran 207 its. 7" csg to 8840' Circulate and condition mud prior te cementing. DAILY:SO CUM:SO ETD:SO EFC:$0 03/12/95 TD: 8747' SUPV:DRM 2) MW: 10.6 PV/YP: 0/ 0 APIWL: 0.0 SET BPV & VR PLUG IN TBG HEAD Circulate and condition 7" casing prior to cementing. Cemented 7" casing. Monitored static well 1 hour. Set 7" casing slips with 150,000 lbs. Cut off casing and layed down stub. Change top rams to 5" and load off BOPE. Nipple up and test tubing head and casing hanger to 5200 psi. Set 3-1/2" tubing hanger and nipple up tree adapter~and master valve. Rig up and freeze pretect 7"x 13 3/8" ann. Rig down. DAILY:SO CUH:$0 ETD:SO EFC:S0 03/13/95 TD: 8747' SUPV:DRH 3) MW: 10.6 PV/YP: 0/ 0 APIWL: RIG RELEASED Clean mud pits, dewatering system and cellar. DAILY:SO CUM:SO ETD:SO EFC:$0 0.0 End of WetlSummary for Well:AX9323 REC;E]VEE 4:0ePI~I AP, CO ALASKA INC Post Office ~,~ 100360 Anchorage, Alaska 99510-0S60 Telephone 907 276 1215 0993 P, 2/4 March 17, 1995 David W. Johnston, Chaim'~an Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchoragc, Alaska 99501-3192 Weekly Operations Report ARCO Alpine ~lB Permit No, 95-20 ARCO Fiord #3 Permit No. 94-171 Dear Commissioner Johnston, Attached is the weekly operations summary for the ARCO Alpine #lB and Fiord #3 wells being dril[eci in the Colville delta area. The 7" production casing was run and cemented at 8839' on the Alpine #lB sidetrack. Operations on Alpine #lB were then be shutdown for the season. ARCO plans to resume operations on Alpine #lB early in the 1996 winter season, At that time the well will be completed and production tested. A Sundry 403 was be submitted after the casing had been set. The drilling rig is aow being moved to the Fiord #3 location. If you have questions or require additional information, please contact Fred Iohnson at 765-1a92. Sincerely, Fred Johnson Drilling Engineer AR3I~, 5003-9a 242-2633 /1:09PM AP. CO ,&L~(SKA INC No, 0993 P, ALPINE #lB Dally Operations Summaries 3/2/95 - Tagged top of cement at 1645'. Dressed ofl cement plug to 1800'. HIH with 8-1/2" bit, Drill 1800-1940'. Kicked olf, Drilled 8-1/2" hole from 1940 to 2177'. 3/3/95 - Drilled and logged (LWD) 8-1/2" hole from 2177' to 3460' as per directional plan. 3/4/9b - Drilled and Iogged(LWD) 8-1/2" hole from 3460' to 4676' as per directional plan. Drilled and logged(LWD) 8-1/2" hole from 4676" to 5382' as per directional plan, Made bit trip at 5059'. 3/6/95 - Drilled and logged (LWD) 8-I/2" hole from 5282' to 6308'. Made bit trip at 5995'. 3/7/95 - Drilled and logged (LWD) 8-1/2" hole from 6308' [o 7804', POOH to pick Up neutron density LWD tools. ,9t8/95- Drilled and logged (LWD) 8-1t2" hole from 7804' to 7945', Tripped for new motor at 7892. Tested BOP while out of the hole on the trip. 3/9/95 - Drilled and logged (LWD) 8-1/2" hole from 7945' to 8788'. 3110t95 - Drilled and Iogged(LWD) 8-112" hole from 8788' to TD at 8850'. Attempted to wireline Icg, Could not get deeper than 7500' with wireline logging toots. Made conditioning trip prior to running 7" production casing, 3/11/95- POOH laid down drill pipe. Ran 7" casing to 8839'. Circulated and conditioned hole. 3/12/95 - Cemented 7" casing st 8839' with 233 sx Class G cement. Displaced cement with 10,6 lb/gal brine and diesel cap. Set casing i~anger. Installed tubing head, tubing hanger and tubing head adapter. Freeze protected 13-3/8"x7" annulus with 180 bbl diesel, Tested 7" casing to 3000 psi for 30 minutes. Cleaned pils. Released rio at 1200 hrs 3/12/95. FIORD #3 Daily Operations Summaries 3/15/95- Continued rig down operations, 3/13/95- Prepared to move rig. Rigged down pipe shed. 3/14/95 - Rigged down rotary tools and mud pumps. Hauled pipe shed to Fiord location. Moved camp to Fiord location, ,i' 10Plk:I ARC.O ALASf(A II'lC. l',[o, 099!: P, 7i.:4 3/16/95 - Continued rig clown operations. Hauled equipment to Fiord location. 3/! 7/95- Rigged down substructure, Laid derrick down, 3/18/95- Completed rig down at Alpine location. Hauled rig equipment to Fiord location. ARCO Alaska, Inc. March 13, 1995 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re' Sundry Notice for Shutdown of Well Operations ARCO Alpine giB Permit No. 95-20 Dear Commissioner Johnston, The ARCO Alpine #lB well has been drilled to 8850' MD, 7531' TVD. The 7" production casing has been run and cemented at a depth of 8839'. ARCO Alaska, Inc. hereby applies for sundry approval for the Shutdown of Well Operations of ARCO Alpine #lB, permit number 95-20. The shutdown is requested due to insufficient time in the remaining winter season to obtain a long term production test to evaluate the well. ARCO plans to resume operations on the well in the early part of the 1996 winter operating season. A wellbore schematic is attached which depicts the secure shutdown status of the well. The 7" production casing was run and cemented as shown in the wellbore diagram. The casing is plugged, at the bottom with the float shoe, +80' of cement, and the float collar. Plug back depth is 8747'. The casing contains kill weight fluids and was pressure tested as per AOGCC regulations. The casing was not be perforated. The wellhead, tubing hanger with back pressure valve, and lower tree valve were installed on the well. The 7" casing and 7"x13-3/8" annulus were freeze protected. If you have questions or require additional information, please contact Fred. Johnson at 265-1492 or myself at 265-6206 in our Anchorage office. Sincerely Mile Z Supervisor KRU Drillsite Development RECEIVED MAR 1 3 1995 Alaska Oil & Gas Cons. Commission Anchorage ARSB-6003-93 242-26()3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend _ Operation Shutdown X Re-enter suspended well_ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate __ Change approved program_ Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator AR(~O Alaska, Inc. 3. Address Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory X_~ Stratigraphic _ Service _ 4. Location of well at surface 1465' FSL, 2250' FWL, Sec. 1, T11N, R4E, UM At top of productive interval 2002' FNL, 1617' FEL, Sec 12, T11N, R4E, UM At effective depth At total depth 2207' FNL, 1522' FEL, Sec. 12, T11N, R4E, UM 12. Present well condition summary Total Depth: measured true vertical 8850' feet 7531' feet Effective depth: measured 8407' feet true vertical 7 1 5 1 ' feet RKB 38' Above SL 7. Unit or Property name N/A feet 8. Well number ALPINE ¢¢1B 9. Permit number 95-20 10. APl number 5o-103-2021 1-02 11. Field/Pool Wildcat 0il & Gas Cons. Commissio~ Anchors Casing Length Size Structural Conductor 8 O' 2 0" Surface 1 7 3 5' 1 3 - 3 / 8" Intermediate Production 8 8 0 9' 7" Liner Perforation depth: measured: None Cemented Measured depth True vertical depth 350 Sx AS I 1 1 0' 1 1 0° 350 Sx AS III & 1765' 1 765' 650 Sx AS I 235 Sx Class G 8 8 3 9' 7 5 22' true vertical: None Tubing (size, grade, and measured depth: None Packers and SSSV (type and measured depth): None Plan to resume operations in February 1996 at which time ARCO would run a completion and begin long production testing. 13. Attachments Description summary of proposal _ Wellbore status diagram prior to Shutdown 14. Estimated date for commencing operation (Shutdown Date) March 12. 1995 16. If proposal was verbally approved Name of approver Date approved Detailed operation program_ BOP sketch 15. Status of well classification as: Oil __ Gas __ Suspended Service 17. I hereby~c,,~tify~,~oregoing 'strue and correcttothe best of mY kn°wledge., Signed ~,--,. Title Area Drilling Engineer Date ~'.-~ FOR COMMISSION USE ONLY Conditions of approval' I~tify Commission so representative may witness IApproval(,~N--'°'~'---~ ~,, ./r--~ BOP Test m Location clearance__ CO MechanicaIPlUg integritYlntegrity__ Test Subs~].l. IRil,t_,fq[ .rP require 10- ~ Approved_Y -- UOIt.IlI~IAL 5E~.~,.[, r.:. [ Returned RUSSELL A. F,,'?,,",'iLASS .... ~m~.[on~r ~._~ Approved by the order of the Commission Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ALPINE #1 B WELLBORE SCHEMATIC SHUTDOWN STATUS 20" CONDUCTOR AT 120' RKB 16" HOLE VR PLUGS INSTALLED WELLHEAD L lii~¢!!:'-::'.:.'.:.'.:. ~::::~ ~:: .'..'..'..'.. !.!~ ~.i]...v.-...'...'. ~:~.i~.¥':~..~i ..'...'...'...'. iii(:~,~¢]'. ....... ~ii~..".~]'-'".'".'-'.'" 8-1/2" HOLE BRINE 10.6 LB/GAL DIESEL 6.75 LB/GAL CEMENT TD 8850' MD 7531' TVD 3-1/2" 5000 PSI LOWER TREE ASSEMBLY / BACK PRESSURE VALVE INSTALLED IN TUBING HANGER 1000' DIESEL CAP IN THE 7" CASING 13-3/8" SURFACE CSG AT 1765' RKB RECEIVED MAR 1 3 1995 Alaska. ()ii & Gas Coas, Commissio~ Anchors ~, TOP OF CEMENT +7900' J-4 INTERVAL +8407'-8493' PBTD 8747' 7" PRODUCTION CSG AT TD +8839' FJ 3/13/95 ~XLASKA OIL AND GAS 'CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 6, 1995 Michael Zanghi, KRU DS Devlp Spvr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Dear Mr Zanghi: Alpine #1B ARCO Alaska Inc 95- 20 1465'FSL, 2250'FWL, Sec 1, T11N, R4E, UM 2487'FNL, 1479'FEL, Sec 12, T11N, R4E, UM Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated February 15, 1995 are in effect for this revision. Chairman BY ORDER OF IHE COMMISSION dlf/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission DATE: February 28, 1995 THRU: FROM: Blair Wondzell, P. I. Supervisor John Spaulding'~'" Petroleum Inspector FILE NO: SUBJECT: a9zlb2cd.doc BOP Test Pool 6 ARCO Alpine lB Exploration PTD 95-20 Tuesday February 28, 1994: I witnessed the BOPE test on Pool rig 6 at Arco's Alpine lB well. The AOGCC BOPE test report is attached for reference. The BOPE test went quite well with no failures observed. Several items that in the preceeding exploration seasons were needing attention have been repaired or replaced. The rig was in excellent condition with good access to all areas. Summary: I witnessed the BOPE test on Pool rig 6 at Alpine lB with 0 failures, 3.5 hr. duration. Attachment: a9zlb2cd.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Pool Rig No. Operator: ARCO Well Name: Alpine lB Casing Size: 13 3/8" Set @ 1765' Test: Initial X Weekly Other DATE: Feb. 28,1995 6 PTD # 95-20 Rig Ph.# 263-3172 Rep.: Tom Covington Rig Rep.: Dave Baumgarner Location: Sec. 1 T. 11N R. 4E Meridian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Drl. Rig OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan 1 250/3000 1 250/5000 1 1 Test Pressure P/F P P 250 / 5000 P 250 / 5000 P 250 / 5000 P 250 / 5000 P 250 / 5000 P N/A N/A 1 2 1 N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Methane Gas Det. OK OK H2S Detectors OK OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Ted Quan. Pressure P/F 1 250/5000 P 1 250/5000 p 1 250/5000 P 1 250/5000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure 16 250/5000 38 250/5000 1 2 , Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Nitgn. Btl's: 1 minutes 4 minutes 3000 J P 1300 P 32 sec. 14 sec. X Remote: X Master: 6 @ 2100 avg. Psig. Number of Failures 0 Test Time 4 Hours Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Excellent test. _ Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector FI-021L (Rev. 2/93) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO A92 Waived By: Witnessed By: 32CD.XLS John H. Spaulding ~o, 1995 ll.:c?A~i AP.C.O, ~,,L;.St(A II~fC ~Io, 0680 ?, 2/'2 ARCO AlasKa, Inc, Post OIISce Box 100360 Anchorage: Ali,~ka 99510-0360 Telephone 907 276 1215 February 28, 1995 David W. Johnston, Chairma__n Alaska Oil and (]as Cun~crvatloa Comn~sion 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill ARCO Alpine #lB (Sidetrack) Dear Commissioner Johnston, A revised aOl Permit To Drill the ARCO All~ine #lB was submitled to AOGCC on February 27. The following well location information is submitted in response to your (Bob Crandall) request for the Ioeation of the base of the objective. Surfam Location:1465' FSL, 2250' FWI,, Sec i. TIlN, R4E, UM Top of Objective: 2108'FNL, 1626'FEL, Sec 12, TllN, R4E, UM B~o of Objective: 2132'FNL, 1617'FEL, See 12, TllN, R4E, UM . Total Depth: 2487' FNL, 1479' FEL, Sec 12, TI iN. R4E, UM If you have questions or require additional infom~ation, please contact me at 265- 1492 ia our Anchoragc offico. Sincerely, Fre. A Johnson Drilling Engi.'neer Kupamk D/illsite Development 242 '~603 AF~SR-6003-'33 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend Alter casing _ Repair well Change approved program _ Operation Shutdown_ Re-enter suspended well_ Plugging _ Time extension Stimulate Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service .4. Location of well at surface 1465' FSL, 2250' FWL, Sec. 1, T11N, R4E, UM At top of productive interval 773' FSL, 678' FEL, Sec 35, T12N, R4E, UM At effective depth At total depth 967' FSL, 790' FEL~ Sec. 35~ T12N, R4E~ UM 12. Present well condition summary Total Depth: measured 9 9 4 0' true vertical 7343' feet feet 6. Datum elevation (DF or KB) RKB 38' Above SL 7. Unit or Property name N/A $. Well number ALPINE #1A 9. Permit number 95-18 10. APl number $o-lO3-2021 t-01 11. Field/Pool Wildcat fee'( Effective depth: measured true vertical feet feet Casing Length Structural Conductor 8 O' Surface 173 5' Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers and SSSV (type and measured depth) Size 20" 13-3/8" Cemented 350 Sx AS I 350 Sx AS III & 650 Sx AS I Measured depth True vertical depth 110' 110' 1765' 1765' RECEIVED FEB 2 ? ]995 ^l~ska. 0il & Gas Cons. Commission Anch0ra 13. Attachments Description summary of proposal Detailed operation program ~ BOP sketch P&A wellbore. 14. Estimated date for commencing operation 15. Status of well classification as: February , 26. 1995 Oil __ Gas __ Suspended 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify thet the foregoing is true and correct to the best of my knowledge ........ .... / Si~ned I"~- Title Area Drilling Engineer ..... {'?~, ' F~ ~MMI~N USE ONLY f'~-;~ ~-,,~,} ~' -- ConditiOns of approval: Notify-CommissiOn s° representative may witness ,~ Location clearan~ MechanicaIPlUg integritYlntegrity__ Test BOP Test__ Subsequent form ~quire 10- _ Approved by the order of the Commission Form 10-403 Rev 06/15/88 ~'"" ,: ~ ~ ~ ' SUB~ITINTRIPLICAT~'" ARCO Alaska, Inc. i;:: .z,s": ..;, ! i'i,c: a L-. c,. ,'L. :,~, ?,,'; .;.'..-';;:'.-;c.,'?.~',:?,..:.i,~:~.': ;,? :~,}:.::' .. ':' ';"--I, -. ....... ,-~ ,. r7 "'7 "' ", 2 - 'C , ,;: c~ -': ; ....... February 25, 1995 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill ARCO Alpine giB (Sidetrack) Dear Commissioner Johnston, Attached is a revised Application for Permit to Drill and directional plan for the ARCO Alpine #lB. Please replace the original permit page and the directional plan in the application with these revised permit pages. This location move does not effect any of the geologic data or drilling plans as presented in the original Permit to Drill application. If you have questions or require additional information, please contact Fred Johnson at 265-1492 or myself at 265-6206 in our Anchorage office. Supervisor Kuparuk Drillsite Development RECEIVED FEB 2 7 1995 Oil & Gas,Cons. Commission Anchora,? STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 i la. Type of Work Drill X Redrill -- I lb. Type of Well ExploratoryX 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. Properly Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL-380075 4. Location of well at surface 7. Unit or properly Name 11. Type Bond (see 20 AAC 25.025) 1465' FSL, 2250' FWL, Sec. 1, Tl11'4, R4E, UM N/A ,,Statewide At top of productive interval 8. Well number Number 2108' FNL, 1626' FEL Sec. 12, T11N, R4E, UM Alpine #lB #U30610 At total depth 9. Approximate spud date Amount 2487' FNL, 1479' FEL, Sec. 12, T11N, R4E, UM 2-28-95 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) property line 1479 feet 0.70 Miles (Alpine #1) 4376 Lease Acres 9100' MD~ 7600'TVD feet ' 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 1 9 0 0 feet Maximum hole an~lle 40° Maximum surface 1 146 pslg At total depth (TVD) 3 557 pslg 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casin~t Wei~lht Grade Couplin~t Len~Ith MD TVD MD TVD (include stage data/ 26" 20" 94# B PEB 80' 30' 30' 110' 110' Permafrost cement 16" 13.375" 68# L-80 BTC 1735' 30' 30' 1765' 1765' +350 sxASlll, +600sx AS1 8.5" 7" 29.0# L-80 BTC 9070' 30' 30' 9100' 7600' +200 sx G , 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 7500' feet Plugs (measured) true vertical 7500' feet Effective depth: measured feet Junk (measured true vedical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 8 0' 2 0" 350 sx AS I 1 1 0' 110' Surface 1735' 13-3/8" 350 SX AS III 1765' 1765' Liner Pedoration depth: measured NoneFEB2 71995 true vedical ...... ~,~ ~i~ ~. Ra.~ Cons. ColTIfflissio~ 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch _ Drillin'~r~l~gr~'r:n,.,,,--~ch0ra.:~'~' Drilling fluid program ~ Time vs depth plot ~X Refraction analysis _ Seabed report __ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ % Titlle KRU DS Development Supervisor Date'7~'(//':7~ /~'~' Sit, ned ? Commission Use Only PermiLNumber I APInumber ~ Approv.aJ, date ._ ~t._~z.}~...e See cover letter for ?,~'-- ..~ ~ 50-/4:~,~~ .~.,~_~_/z//... ~_/, -"~.~.,...~ ~' other requirements Conditions of approval Samples required ~ e s__ N o Mud log required s __ N o Hydrogen sulfide measures __ Y e s ~ N o Directional~,s~prvey required ,,.,~'Yes __ N o Required working pressure forBOPE __2M; __ 3M; J,% 5M; __ 10M' __ 1 5M Other: Original SigneO By by order of ~__~,... ~.~ ._ ,~/..__~? ~ David W, Johnston Approved by Commissioner the commission Date ~-- Form 10-401 Rev. 7-24-89 Submit in triplicate Created by ' jones For: F JOHNSON ~ Dote plotted : 27-Feb-95 Plot Reference is Alpine #lB Version #3. Coordinates are in feet reference slot #1 True Vertical Depths ore reference RKB. Baker Hughes INTEQ 1200_ - 1500_ 1800_ 2100_ - 2400_ 2700~ 3000_ -I---- (~ 3300_ _ ~ 3600. 3900_ 4200. 4500_ 4800 5100 L ~__ - 5400_ - V 6000_ 6300 _ 6600_ 6900_ 7200_ 7500_ - 7800_ 13 3/8" Casing KOP J2 2.91 5.89 Structure : Alpine #1 Well : lB Field : Exploration Location : North Slope, Alaska S 21.46 DEG E 3842' (TO TARGET) · **PLANE OF PROPOSAL*** AVERAGE ANGLE 39.87 DEG Point KOP End of Build Target WELL PROFILE DATA MD lnc Dir TVD North East Deg/lO0 1875 1.10 129.65 1875 -8 15 O.OO 3172 39.87 158.79 3067 -420 181 3.00 8453 39.87 158.79 7120 -3576 1406 0.00 ............ East -- > 250 500 750 1000 1250 1500 1750 I II II II II II I 250 500 750 RECEIVED FEB 27 1995 Alaska Oil & Gas Cons. Commission Anchora? TARGET 3oo o soo 600 900 12 0 15 0 1soo 21 0 24 o 3 o 3 oo z6 o 3 oo 4500 Scale 1 : 150.00 Vertical Section on 158.54 azimuth wHh reference 0.00 N, 0.00 E from slot #1 25o ~ g 1250 _1500 Cf~ 0 - _1750 - _2000 - I _2250 I - _2500 V -- 2750 _3000 3250 3500 3750 4000 ARCO ALASKA, Inc. Alpine #1 18 slot #1 Exploration North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : Alpine #lB Version #3 Our ref : prop1165 License : Date printed : 27-Feb-95 Date created : 17-Feb-95 Last revised : 27-Feb-95 Field is centred on n70 28 24.450,w148 49 2.487 Structure is centred on nTO 19 59.612,w151 0 37.253 Slot location is n70 19 59.612,w151 0 37.253 Slot Grid coordinates are N 5972482.257, E 375455.044 Slot local coordinates are 0.00 N 0.00 E Reference North is True North RECEIVED FEB 2.7 1995 Oil & Gas Cons. Commissio~ Anchora:;:'~ ARCO ALASKA, Inc. Alpine #1,1B Exploration,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : Alpine #lB Version #3 Last revised : 27-Feb-95 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 1875.00 1.10 129.65 1874.85 8.39 S 14.92 E 0.00 1900.00 1.79 141.70 1899.84 8.84 S 15.34 E 3.00 2000.00 4.73 152.85 1999.67 13.74 S 18.19 E 3.00 2100.00 7.72 155.42 2099.07 23.52 S 22.87 E 3.00 2200.00 10.71 156.56 2197.77 38.16 S 29.36 E 3.00 13.26 KOP #2 13.85 19.44 30.26 46.26 2300.00 13.71 157.21 2295.50 57.62 S 37.65 E 3.00 2400.00 16.71 157.63 2391.98 81.85 S 47.71 E 3.00 2500.00 19.71 157.92 2486.96 110.78 S 59.52 E 3.00 2600.00 22.71 158.14 2580.18 144.32 S 73.05 E 3.00 2700.00 25.71 158.31 2671.38 182.40 S 88.25 E 3.00 67.40 93.63 124.87 161.04 202.04 2800.00 28.70 158.45 2760.30 224.90 S 105.09 E 3.00 2900.00 31.70 158.56 2846.72 271.70 S 123.52 E 3.00 3000.00 34.70 158.66 2930.38 322,69 S 143.49 E 3.00 3100.00 37.70 158.74 3011.06 377.72 S 164.94 E 3,00 3172.32 39.87 158.79 3067.43 419.94 S 181.35 E 3.00 247.76 298.06 352.82 411.88 457.18 EOC 3500.00 39.87 158.79 3318.91 615.79 S 257.35 E 0.00 4000.00 39.87 158.79 3702.64 914.63 S 373.31 E 0.00 4500.00 39.87 158,79 4086.37 1213.47 S 489.27 E 0.00 5000.00 39.87 158.79 4470.10 1512.31 S 605.22 E 0.00 5500.00 39.87 158.79 4853.82 1811.15 S 721.18 E 0.00 667.25 987.80 1308.34 1628.89 1949.44 6000.00 39.87 158.79 5237.55 2109.99 S 837.14 E 0.00 6500.00 39.87 158.79 5621.28 2408.83 $ 953.10 E 0.00 7000.00 39.87 158.79 6005.01 2707.67 $ 1069.06 E 0.00 7500.00 39.87 158.79 6388.74 3006.51 S 1185.02 E 0.00 8000.00 39.87 158.79 6772.47 3305.35 S 1300.98 E 0.00 2269.98 2590.53 2911.08 3231.62 3552.17 8452.83 39.87 158.79 7120.00 3576.00 S 1406.00 E 0.00 8500.00 39,87 158.79 7156.20 3604.19 S 1416,94 E 0.00 9000.00 39.87 158.79 7539,93 3903.03 S 1532.90 E 0.00 9078.27 39.87 158.79 7600.00 3949.81 S 1551.05 E. 0.00 3842.47 TARGET 3872.71 4193.26 4243.44 TD RECEIVED FED 2T 1995 ~.~;~ska Oil & Gas Cons. Commissio~ Anchom ::;~ All data is in feet unless otherwise stated Coordinates from slot #1 and TVD from RKB (38.00 Ft above Mean Sea Level). Vertical section is from wellhead on azimuth 158.54 degrees. Declination is 0.00 degrees, Convergence is -0.95 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO ALASKA, Inc. PROPOSAL LISTING Page 2 Alpine #1,1B Your ref : Alpine #lB Version #3 Exploration,North Slope, Alaska Last revised : 27-Feb-95 Comments in wellpath MD TVD Rectangular Coords. Coherent 1875.00 1874.85 8.39 S 14.92 E KOP #2 3172.32 3067.43 419.94 S 181.35 E EOC 8452.83 7120.00 3576.00 S 1406.00 E TARGET 9078.27 7600.00 3949.81S 1551.05 E TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 1874.85 8.39S 14.92E n/a 1874.85 8.39S 14.92E 13 3/8" Casing n/a 1874.85 8.39S 14.92E 9078.27 7600.00 3949.81S 1551.05E 7" Casing Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised #lB Rvsd 27-Feb-95 not specified 7120.00 3576.00S 1406.00E 17-Feb-95 RECEIVED FEB 2 T 1995 ^laska. Oil & ~as Cons, Commissio~ Anchora ALL data is in feet unless otherwise stated Coordinates from slot #1 and TVD from RKB (38.00 Ft above Mean Sea Level). Bottom hole distance is 4243.44 on azimuth 158.56 degrees from wellhead. Total Dogleg for wellpath is 38.92 degrees. Vertical section is from wellhead on azimuth 158.54 degrees. Declination is 0.00 degrees, Convergence is -0.95 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ AI~SI~A OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHO RAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 23, 1995 Mike Zanghi, Drlg Engr Supv ARCO Alaska Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Alpine #1B ARCO Alaska Inc 95-2O 1465'FSL, 2250'FWL, Sec 1, T11 N, R4E, UM 2106'FNL, 1619'FEL, Sec 12, T11N, R4E, UM Dear Mr Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The repod should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. DavidW Johnston ~ -"-'- .... ~ BY ORDER OF THE COMMISSION Ijb/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl ARCO Alaska, Inc. !~,:: ~-= ='~, '~',i,3,:~ February 22, 1995 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill ARCO Alpine #lB (Sidetrack) Dear CommiSsioner Johnston, Attached is a revised Application for Permit to Drill and directional plan for the ARCO Alpine #lB. Please replace the original permit page and the directional plan in the application with these revised, permit pages. The bottom-hole location of this planned directional well has been moved approximately 1130' to the west of the original location to 2106' FNL, 1619' FEL, Sec 12, T1 IN, R4E, UM. The bottom hole location has been changed to better tie into the seismic data. This location move does not effect any of the geologic data or drilling plans as presented in the original Permit to Drill application. If you have questions or require additional information, please contact Fred Johnson at 265-1492 or myself at 265-6206 in our Anchorage office. Sincerely, Mike Zanghi Supervisor Kuparuk Drillsite Development R£C£IV D FEB 2:5 1995 ~iaska Oil & Gas Cons. Commission Anchora" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill ~ Redrill I lb. Type of Well Exploratory X.~._ 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, In(;:, KB ht abQve sea level;40 feet Wildcat 3. Address 6. Property Designation P. O. Box 100360, Anchora(.:je, AK 99510-0360 ADL-380075 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1465' FSL, 2250' FWL, Sec. 1, T11N, R4E, UM N/A St~t~wid~ At top of productive interval 8. Well number Number 1900' FNL, 1700' FEL Sec. 12, T11N, R4E, UM Alpine #lB #U30610 At total depth 9. Approximate spud date Amount 2106' FNL, 1619' FEL, Sec. 12, T11N, R4E, UM 2-26-95 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD ancl TVD) property line 1619 feet 0.70 Miles (Alpine #1) 4376 Lease Acres 8700' MD~ 7400'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 1900 feet Maximum hole anc~le 40° Maximum sudace 1146 psig At total depth (TVD) 3557 psl~ 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casinc~ Weic~ht Grade Couplin~ Lenc~th MD TVD MD TVD tinclude stac~e data1 2 6" 20" 94# B pI:R 8 0' 3 0' 3 0' 110' 110' Permafrost cement 16" 13.375" 68# L-80 BTC 1735' 30' 30' 1765' 1765' ±350 sxASIII , +600sx AS1 8'5" 7" 29.0# L-80 BTC 8670' 30' 30' 8700' 7400' ±200 sx G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 7500' feet Plugs (measured) true vertical 7500' feet Elfective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' 20' 350SXASlII''0sx^S' ,,o. Intermediate 650SXASl Production Liner FEB ,r.. 5 '!995 Perforation depth: measured None true vedical .i~'!~.,S'~(.~. 0i, t & Gas C0[ts. Oommissi0r~ An~hnr.':.. .... 20. Attachments Filing fee ~ Property plat ;~ BOP Sketch _~ Diverter Sketch _ Drilling program X Drilling fluid program X Time vs depth plot X Refraction analysis _ Seabed report 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Sicjned,.~,~~r~ ,~,~/¢~'//¢ ~¢,,v'~:/'// Titlle KRU DS Development Supervisor Date ¢ Commission Use Only ~be I APl number I AP'~°71c~a~ See cover letter for Permit . r~o 50- [(~O~. ~O"~ ~ ' C)'~ / ~ ~ other rec~uirements Conditions of approval Samples required ~..Y e s ~ N o Mud log requir~,d .~ Y e s ~ N o Hydrogen sulfide measures~ Y e s _~ N o Directional survey required ~.~Yes ~ N o Required working pressure forBOPE ~2M; ~ 3 M' ~ 5 M · ~ 1 0M' ~ 1 5 M Other:Original Signed By 9av,d W, J0hnst0n by order of / Approved by Commissioner the commission Date ~ c~hmit in trir~li~'~t~ Form 10-401 Rev. 7-24-89 I Created by : jones Dote plotted : 22-Feb-95 Plot Reference is Alpine #lB Version #2. Coordinates ore in feet reference slot #1. True Vertical Depths ore reference RKB. Baker Hughes INTEQ 2400_ 2700 - 3300_ _ - _ - 4800_ _ 54O0 57~ - _ 7200 7500 Ix 13 3/8 Casing KOP #2 2,91 5.89 8.88 ARCO ALASKA, Structure : Alpine #1 Field : Exploration Point Well : lB Location : North Slope, Alaska KOP End of Build Target End of Hold WELL PROFILE DATA MD Inc Dir WD NoAh East Deg/lO0 1875 1.10 129.65 1875 -8 15 0.00 5110 38.00 158.69 3019 -383 167 3.00 8314 38.00 158.69 7120 -3368 1332 0.00 8669 38.00 158.69 7400 -3572 1412 0.00 ~o,~,:,~.~ East--> 200 0 200 400 600 800 1000 1200 1400 160 RECEIVED FEB 2 3 1995 A~aska Oil & Gas Cons. Commission Anch0ra,'" 300 0 300 600 900 1200 15 18 0 21 2 0 2700 3 0 3300 3 a 3900 4 0 Scale 1 : 150.00 Vertical Section on 158.42 azimuth with reference 0,00 N, 0.00 E from slot #I 8OO 1aa0 _32OO ARCO ALASKA, Inc. Alpine #1 lB slot #1 Exploration North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : Alpine #lB Version #2 Our ref : prop1165 License : Date printed : 22-Feb-95 Date created : 17-Feb-95 Last revised : 22-Feb-95 Field is centred on n70 28 24.450,w148 49 2.487 Structure is centred on n70 19 59.612,w151 0 37.253 Slot location is n70 19 59.612,w151 0 37.253 Slot Grid coordinates are N 5972482.257, E 375455.044 Slot local coordinates are 0.00 N 0.00 E Reference North is True North Anchor:' ARCO ALASKA, Inc. Alpine #1,1B Exploration,North Slope, Alaska Measured Inclin. Azimuth True Vert. Depth Degrees Degrees Depth 1875.00 1.10 129.65 1874.85 1900.00 1.79 141.67 1899.84 2000.00 4.73 152.80 1999.67 2100.00 7.72 155.37 2099.07 2200.00 10.72 156.51 2197.77 PROPOSAL LISTING Page 1 Your ref : Alpine #lB Version #2 Last revised : 22-Feb-95 R E C T A N G U L A R Dogleg Vert C 0 0 R D I N A T E S Deg/lOOFt Sect 8.39 S 14.92 E 0.00 8.84 S 15.34 E 3.00 13.74 S 18.19 E 3.00 23.52 S 22.88 E 3.00 38.15 S 29.39 E 3.00 13.28 KOP #2 13.87 19.47 30.28 46.29 2300.00 13.71 157.15 2295.50 2400.00 16.71 157.57 2391.98 2500.00 19.71 157.86 2486.96 2600.00 22.71 158.08 2580.18 2700.00 25.71 158.25 2671.38 57.60 S 37.70 E 3.00 81.82 S 47.78 E 3.00 110.74 S 59.62 E 3.00 144.27 S 73.18 E 3.00 182.33 S 88.43 E 3.00 67.43 93.66 124.90 161.08 202.08 2800.00 28.71 158.39 2760.30 2900.00 31.70 158.50 2846.71 3000.00 34.70 158.60 2930.38 3100.00 37.70 158.68 3011.06 3109.75 38.00 158.69 3018.76 224.81 S 105.31 E 3.00 271.60 S 123.79 E 3.00 322.57 S 143.81 E 3.00 377.57 S 165.32 E 3.00 383.15 S 167.50 E 3.00 247.79 298.10 352.85 411.91 417.90 EOC 3500.00 38.00 158.69 3326.29 4000.00 38.00 158.69 3720.30 4500.00 38.00 158.69 4114.32 5000.00 38.00 158.69 4508.34 5500.00 38.00 158.69 4902.36 606.97 S 254.82 E 0.00 893.73 S 366.70 E 0.00 1180.49 S 478.57 E 0.00 1467.26 S 590.45 E 0.00 1754.02 S 702.33 E 0.00 658.14 965.95 1273.76 1581.58 1889.39 6000.00 38.00 158.69 5296.38 6500.00 38.00 158.69 5690.40 7000.00 38.00 158.69 6084.41 7500.00 38.00 158.69 6478.43 8000.00 38.00 158.69 6872.45 2040.78 S 814.20 E 0.00 2327.55 S 926.08 E 0.00 2614.31 S 1037.96 E 0.00 2901.07 S 1149.83 E 0.00 3187.84 S 1261.71 E 0.00 2197.20 2505.01 2812.82 3120.63 3428.44 8314.13 38.00 158.69 7120.00 8500.00 38.00 158.69 7266.47 8669.45 38.00 158.69 7400.00 3368.00 S 1332.00 3474.60 S 1373.59 3571.78 S 1411.50 E 0.00 3621.83 TARGET E 0.00 3736.25 E 0.00 3840.57 TD RECEIVED ALL data is in feet unless otherwise stated Coordinates from slot #1 and TVD from RKB (38.00 Ft above Mean Sea Level). Vertical section is from wellhead on azimuth 158.42 degrees. Declination is 0.00 degrees, Convergence is -0.95 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO ALASKA~ Inc. PROPOSAL LISTING Page 2 Alpine #1,1B Your ref : ALpine #lB Version #2 Exploration,North Slope, Ataska Last revised : 22-Feb-95 Comments in we[[path MD TVD Rectangutar Coords. Co~ent 1875.00 1874.85 8.39 S 14.92 E KOP #2 3109.75 3018.76 383.15 S 167.50 E HOC 8314.13 7120.00 3368.00 S 1332.00 E TARGET 8669.45 7400.00 3571.78 S 1411.50 E TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD RectanguLar Coords. Casing n/a 1874.85 8.39S 14.92E n/a 1874.85 8.39S 14.92E 13 3/8" Casing n/a 1874.85 8.39S 14.92E n/a 7400.00 3571.78S 1411.50E 7" Casing Targets associated with this we[[path Target name Position T.V.D. Local rectangular coords. Date revised ALpine #lB Rvsd 22-F not specified 7120.00 3368.00S 1332.00E 17-Feb-95 FEB 2 3 1995 ~Jit & Gas Co~s. Oommissio~ Anchom ~' All data is in feet unless otherwise stated Coordinates from slot #1 and TVD from RKB (38.00 Ft above Mean Sea Level). Bottom hole distance is 3840.57 on azimuth 158.44 degrees from wellhead. Total DogLeg for we[[path is 37.04 degrees. Vertical section is from wet[head on azimuth 158.42 degrees. Declination is 0.00 degrees, Convergence is -0.95 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Febmary 20, 1995 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill ARCO Alpine giB (Sidetrack) Dear Commissioner Johnston, ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory well, the ARCO Alpine giB (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 proposed sidetrack will be drilled from the same surface location as the Alpine #1 well. The bottom hole location is approximately .75 mile southeast of the ARCO Alpine #1 well. Attached. find the information required by 20 AAC 25.005(c), and 20 AAC 25.061. All waste drilling mud and. cuttings generated during the drilling of Alpine #lB 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. The Commission is requested to keep confidential the following attachments to this permit application which are drawn from research and data proprietary to ARCO Alaska, Inc.: Pressure Information Proposed Drilling Fluid Program Pressure Analysis Proposed Drilling Program RECEIVED FEB 2 1 1995 ,Alaska 0ii & Gas Cons. Commission gr~chora ~. ARCO Alaska, Inc... ;~.~ c' .~_~ .: · '~ .ii::. 3 i:i .::: i ..~i:.,~. :!'. ~' j Finally, the following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Weekly Status Report Fred Johnson, Drilling Engineer 265-1492 2) Completion Report (20 AAC 25.070) Fred Johnson, Drilling Engineer 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. Sincerely, Supervisor Kuparuk Dfillsite Development (las Cons. Commission Anchora,!,~ A'~,3B-6()03-93 242- 2(;03 PROPOSED DRILLING PROGRAM ALPINE #lB (Per 20 AAC 25.005(c)(10)) 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) 11) 12) 13) Alpine #1B - General Procedure Application for Permit to Ddll February 20, 1995 Dress off cement plug with 12-1/4" bit. Test BOP if required. 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_+1900'. Orient motor and sidetrack out of odginal hole. Drill 8-1/2" hole to TD as per directional plan. If LWD log results are favorable, run and cement 7" casing. Nipple down BOP, nipple up tubing head, nipple up and test BOP. Run cased hole logs Pressure test 7" casing to 3500 psi. Freeze protect 13-3/8" x 7" annulus. Run in hole with the completion type test string, space out and land tubing hanger. Nipple up and pressure test 5000 psi tree, tool stdng and manifold. Perforate well under balance using tubing conveyed guns. Flow up the tubing and through surface testing facilities. Test liquids will be stored in tanks on location and pumped back into the reservoir or hauled back to Kuparuk and processed through Kuparuk facilities. Gas will be flared. Testing will involve alternating flow periods and shut-in pedods. Individual intervals may be tested separately or concurrently. For long term flow testing, the rig will be moved off prior to perforating and will be moved to the Fiord #3 location. Kill well. Freeze protect tubing and annulus. Install tubing plug and back pressure valve. Well may be left with operations temporarily suspended and long term flow testing may be resumed the following winter season Clean and abandon location and access road. -1000 -2000 -3000 -4000 -5000 -6000 -7000 -8000 -9000 -10000 -11000 ALPINE #1, lA, lB DRILLING OPERATIONS -,,o .,,, .,o .,, o ~ ~o'"RECElVb~ ~o -25 DAYS FE~ 2 1 ~995 Aiaska Oil & Gas Cons. Commission Anchor~.,',, PROPOSED DIRECTIONAL PROGRAM ALPINE #lB (SIDETRACK) (Per 20 AAC 25.050) Gas Cons. Cornm~ss~o~ Anchor's- '" ARCO Alaska, ino. ~[ ¢~~KUPARUK r'~ ,....,..,,~ plRBl NKS ANCi-tORAGE FEB 2 69' 6~' EXPLOEATORY WBJ. [ Subaidlory of Atlantic Richfield company PERMIT EXHIBIT ] ! LK6,01166 12/29/9~ , D~ ~ NSK 6.01 d166 .... _~ oF z 1 ...... [_ II__l!ll_l ~L IL ..... I _ SENT BY:ARCO ALASKA ;12-29-94 ; 17'32 ; KPS/WELLS/CNST/PROJ~ 907 265 6224;# 4/ 4 ~ ,~.~, · /-dh y-./; ~,~_ ~ ~:~.. ~ ~ ~ ~::::::~ "~:~:~:~ .~UMIAT MERIDIAN ~ ~ ~ J-'~ ,LONG' : 151' 00' 57' ~ ,_~, ~, ~,'!_~,~ ~]~ ~~ // ~ ,~'~ ~o .o . _'~~v ". ~ ' ~ ..l.....~ ~ c ~.. ~ ........ Subsldlory of AtMntic Richfield ~mpany ~ ~s~ Oil & Gas Cons. ' An~hor~', P~MIT ~HIBIT ~"~"~' .... ! ....... I~""~' !=~=' l~ ~6o1166 12/29/9~ _~ N~ 6.01 d166 , ICE PAD LIMITS I ALPINE #1 -- 33.5' ~ ~ , Scale 1"= 2 Miles , ' cUrnNC___, ~ STORAGE ALPINE #1 I I 252' ! i LOCA~D ~IN PRO~AC~D ~ ~f SEC. ~, ~. ~ N., RCE. 4 E. ~ ~ UMIAT MERIDIAN LAT. = 70' 19' 59.612" ~ ~ LONG. = 151' 00' 57.25~" ~ 1,468' F.S.L, 2,248' F.W.L. Y = 5,972,482.25 X = 575,455.05 GROUND ELEV.= 6' TOP ICE PAD ELEV.= 7.6' NOmS 1. BASIS OF HORIZONTAL LO¢A~ON AND ~VA~ON IS U.S.~.S. ~ONUMEN~ ~AR ~ B~. Z COORDINA ~S SHO~ ARE A~SKA STA~ P~NE ZONE 4, N.A.D. 27. ~ 4. ~VA ~ONS SHO~ ARE ~,,~,,,~ I H~Y ~~ ~AT I AM PROP~LY RE~S~ED AND ~ ~_ ,., ,., ~ m DONE BY ME OR UND~ MY DIRECT SUP~ON AND N LOUNSBURY F~B 2 ~ ]995 ~ ~ ASSOrtS, ~C. M~ska, ~i~ & Gas Cons, Com. ission ~~~~ ~~ ~o~ ~[ A~NE ~ ~LOR~TOEY " CONDUCTOR ~ ICE PAD Subsidiary of Atlantic Richfield Company AS-BUILT C~D R~ NO. ! DRA~NG N~ ! SHE~: REV: ~601172 1/16/95 CEA-MIXX-601D172 OOl o~ ~ o t .i UTP! ~ AHC 1 5~ WHTE (- 1 o.~5o) HUNT 5.75053a RW RES 3.78= 372105 AAI 2.5~. (CC tALK47 ~ 5 , ADL 25538 APC 20.0: 1 -31 ALPINE #1 B SURFACE LOCATION 25558 AAI '72.5,' 6UTP APC 20.0x 1 - 32~_-75 (COND) // ALPINE #1 B l,~ TD LOCATION UIP APC 20x 3-31-98 ALK4553 (+1o,35o) AN 80.3O8= ALK ADL ;,4.4 14.538~ ..,x4..25~ UTP 19.692~ ,HUNT RW R~S AAI UTP 572107 ,PC (COND) ADL 25557 AAI' UTP 16.1x APO 20.Ox ALK4551 ' ADL ,372095 AAI 63.9~ UTP 16.1~ APC 20x ADL 372096 : 11;55x HUNT 3.36= 3-31-98 AAI ALK4557 ADL ,372106 AAI 83.9= UTP 16,1s ALK4559 ADL372108 AP~ '36 1i BP 6U'T 11- Per 20 AAC 25.005(c_)(3): DIAGRAM AND DESCRIPTION OF EQUIPMENT TO BE USED BOP (As required in 20 AAC 25.035(a)(1)) AND INFORMATION ON MAXIMUM PRESSURES (As required in 20 AAC 25.035(d)(2)) RECEIVED FEB 2'] 1995 Og & Gas Cons. Commissior~ Anchor's, BOP SCHEMATIC POOL RIG #6 ALPINE #lB 13-5/8", 10,000 PSI 4 I I I I 5 I I I. 7 I I I I Commission RECEIVED See listing of individual components on following page Revised 1/31/95 BOP COMPONENTS ALPINE #1 B POOL RIG #6 13-5/8, 10,000 PSI Diverter System: 1. . , NOTE: DIVERTER NOT APPLICABLE TO SIDETRACK 21-1/4", 2000 psi WP, Hydril Type MSP annular preventer with companion flange to diverter spool. 21-1/4", 2000 psi WP diverter spool with one 16" outlet. 16", 200 psi WP FNW knife valve with hydraulic actuator on diverter outlet. BOP Stack; 4. 13-5/8", 5000 psi WP, Hydril Type GK annular preventer with companion flange to bell nipple. 5. Single 13-5/8", 10,000 psi WP, Hydril type MPL ram blowout preventer fitted with pipe rams. 6. Single 13-5/8", 10,000 psi WP, Hydril type MPL ram blowout preventer fitted with blind rams. 7. Single 13-5/8", 10,000 psi WP, Hydril type MPL ram blowout preventer fitted with pipe rams. 8. 13-5/8", 10,000 psi WP drilling spool with one 3"and one 4" 10,000 psi WP outlets Choke Valves: 9. 4", 10,000 psi WP McEvoy Type E gate valve with hydraulic actuator 1 0. 4", 10,000 psi WP McEvoy Type E manual operated gate valve Kill Valve: 1 1. 3", 10,000 psi WP McEvoy Type E manually operated gate valve 12. 3", 10,000 psi WP McEvoy Type E gate valve with hydraulic actuator Revised 1/31/95 PRESSURE INFORMATION ALPINE #1 B The following presents data used for calculation of anticipated surface pressures (ASP) during drilling for the Alpine #lB well: Casing Pore Casing Setting Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressure D r i I ling ~in.~ ~ft. TVD~ ~lbs/gal) (lbs/gal) (psi~ (psi) 20" 110' 11.4 8.6 49 53 - Diverter 1 3-3/8" 1765' 14.6 9.0 842 1146 - BOP 7" 7600' 16.2 9.0 3557 2721 - BOP Procedure for Calculatina AnticiDated Surface Pressure ~ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.11]D where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.11 = Gas gradient in psi/ft D = True vertical depth of casing seat in ft RKB 2) ASP = FPP - (0.11 x D) where: FPP = Formation Pore Pressure at the next casing point ASP Calculations 1. Drilling below conductor casing (20") ASP = [(FG x 0.052) - 0.11]D [(11.4 x 0.052) - 0.11] x 110 53 psi ASP = ..-- FPP - (0.11 x D) 842 - (0.11 x 1800) 644 psi RJECEIVJED FE~ 2 1 1995 ;~,!~ska. ~jit & Gas Cons, C0~mlssio~ Anchor~' '- 2. Drilling below surface casing (13-3/8") ASP : [(FG x 0.052) - 0.11]D : [(14.6 x 0.052) - 0.11] x 1765' = 1146 psi ASP: FPP - (0.11 x D) = 3557 - (0.11 x 7600) = 2721 psi Casing Performance Properties Size Weight Grade Cnxn (in) (Ib/ft) 20" 94 B PEB 13-3/8" 68 L-80 BTC '9-5/8" 53.5 L-80 BTC 7" 29 L-80 BTC * Contingency intermediate casing string Casing Setting DeDth Rationale 20" 110' MD / 110' TVD 13-3/8" 1765'MD/1765'TVD 9-5/8" +_3000' MD / 3000' TVD ,, 9100' MD / 7600' TVD Internal Collapse Tensil Strength Yield Resistance Joint Body (psi~ (psi) (1000 lbs) Conductor Casing 5020 2270 1556 1556 7930 6620 1329 1244 8160 7020 746 676 Conductor casing to provide sufficient anchor and fracture gradient for diverter system. Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling to next casing setting point. Contingency intermediate casing that could be set if high mud weights are required to drill the K- 10 and K-5 intervals. This intermediate casing would provide sufficient fracture gradient and well control while drilling to next casing setting point. Production casing to cover all open hole and all previously set casing to allow comprehensive testing of the well. This casing will not be set if logs indicate the well is a dry hole. RECEIVED FEB 21 1995 0ii & Gas Cons. Commission Anch0r~ PROPOSED CASING AND CEMENTING PROGRAM ALPINE #1B (Per 20 AAC 25.005(c)(4)) NOTE: ALPINE #lA IS A SIDETRACK BELOW SURFACE CASING, THE 20" CONDUCTOR AND 13-3/8" SURFACE CASING HAVE ALREADY BEEN SET. RECEIVED FE8 2:t ],995 ~t~sk~. Oi~ & 8as Cons. Com~issio~ A~chor~ ,~ ALPINE #lB (SIDETRACK) WELLBORE SCHEMATIC 16" HOLE 8-1/2" HOLE 5000 PSI WELLHEAD EC UIPMENT 20" CONDUCTOR AT 11 O' RKB 13-3/8" 68 LB/FT L-80 BTC SURFACE CSG SET AT 1765' RKB RECEIVED FEB 2't '~995 Oii & Gas Coas. Commission Ancl~m,,~ · 7" PRODUCTION CSG AT TD +9100' NOTE: 20" CONDUCTOR AND 13-3/8" SURFACE CASING ARE ALREADY SET FJ 2/12/95 Cementing PrQgre_m 13-3/8" Surface Casino - Casing Size: 13-3/8", 68#, L-80 Hole Size: 1 6" Depth: 1765' MD, RKB Top of Cement: Surface Excess Calculated: 100% Lead, 25% Tail BHT (Static): 45°F BHT (Circ): 60°F Note: 13-3/8" has already been run Slurry Comoonents and Properties- Preflush' 20 bbls water Arcticset III with 1/4#/sx D29 (cellophane flakes) (800' to surface) Slurry Weight Slurry Yield Thickening time 12.1 ppg 1.94 cu. ft./sk 6+ hours @ 60° F BHT Arcticset 1 with 1/4#/sx D29 + .05% D13 retarder (1800' to 800') Slurry Weight Slurry Yield Thickening Time 15.7 ppg .93 cu. ft./sk 2-1/2+ hours at 60° F BHT Cement Volume Calculations (Based on 16" gauge hole): Top West Sak, TMD Design lead from 200' above the Top of West Sak Annular area Lead length * Annulus area Excess factor Cement volume required Yield for Permafrost Cmt Lead Cement volume required 1000 ft 800 ft 0.4206cf/If 336 cf 100% 673 cf 1.94 350 sxJ TMD shoe TD - 200' above West Sak) * (Annulus area) Length of cmt inside csg Internal csg volume Cmt required in casing Total cmt Excess factor Cement volume required Yield for Class G cmt Tail Cement volume required 1,8OO ft 420 cf 80 ft 0.8406 cf/If 68 cf 488 cf 25% 610 cf .93 656 sxI RECEIVED FEB 2, Oit & Gas Corts. Commission Anchor~ ... Cementina Proaram-cont. _ -- 7" Production Casing Size: Hole Size: Depth: Top of Cement: Excess Calculated: BHT (Static): BHT (Circ): Casing 7", 29#, L-80 8-1/2" 9100' MD, RKB 500' MD above top of J-4 Jurrasic target (7950' 50% 150OF 125OF MD) Slurry Comoonents and Pro_oerties: Preflush: 20 bbls Water Preflush 50 bbls ARCO Spacer (weighted to 1.0 ppg over mud wt.) Slurry: Class G with 0.15 gps D47 (defoamer) +3.0% D53 (gypsum) + 0.65% D65 (dispersant) +0.1gps D135 (latex stabilizer) + 1.0 gps D600 (latex) + 0.07% D800 (retarder) Slurry Weight Slurry Yield Thickening Time 15.8 ppg 1.19 cu. ft./sk +4 hours at 130° F BHT Cement Volume Calculations (Based on 8-1/2" gauge hole): TMD = 9100 ft Top of Target, TMD = 8450 ft Want TOC 500' above top of J-4 target = 7950 ft Annulus area= 0.1268 (TD-TOC)*Annulus area = 146 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2085 Cmt required in casing = 17 cf Total cmt = 163 cf Excess factor = 5 0 % Cement volume required = 244 cf Yield for Class G cmt = 1.19 Cement volume required =1 205 sx Note: Actual cement volume will depend on open hole and caliper log interpretation RECEIVED O[J & Gas Co~s. Commissio~ Anch0r~' PROPOSED DRILLING FLUID PROGRAM and DRILLING FLUID SYSTEM DESCRIPTION ALPINE #1 B (Per 20 AAC 25.005(c)(6)) RECEIVED /a~,ska {~i~ & Gas Co~lso Com~Jssio~ Anchor~- -, ARCO ALPINE #lB ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT -1000 CASING 1765' -2000 - ~,,, i,,,,,~ ~,, ~-----= --~- · .... - ................... ~ ............................ ' .... ~- '-'-'-' ' _- .................................................................... J ...................... ~ _~ ..... - ~ L~- ' 1~=.~ ~ .,-~ ................ = ............. .... ...... .... .................. == ........ .... ...... ~ ~ ... ~ ............ ......-~ ............ ~;[i[i[i = ,~: =; = = = = : = .... ~iXX~, i__,,_.. ~ ................. ~.. ......... ,.....~..., .... .~....~ ........ , ..... ~ ....... , ........ ,...= .......... ::ili _~,...~.__._~...~.......~....._. ~,,~w~,~.~! i i .i ,.., ! i:] ~----:---------.i...-----------'--',--! ...... .~ ................. 1 ..... l..~_x .... 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N ........ ..-'-'"'"" .... r-..i--.~ ,, ~ ~, ~ ........ ~ ,~ , ~ ~ , , , , ~ , [ii]i'"~~~ .............. i"'?i'"i"" i ..... '''''''-:': .... .... .... ..... ..... ............ t ........... 1 ..... i~ ......... f ....... i'Tf'"[ .............. i .......... i ............ I ........ -3OOO -4000 -5000 -6000 -7OOO -8000 -9000 -10000 8 9 10 11 12 13 14 15 16R EQUIVALENT MUD WEIGHT (LB/GAL) E C E'z~V E b8 FEB 2~ t995 Gas Cons. Commissioe FEB-13-gB NON 15:39 B~ROID DRLG FLUIDS t-fiX NO, 90724853@0 ?, Ol/OZ February 13, 1995 To: Fred Johnson - ARCO (265-6224) From: John Rose - Baroid Subject: Mud Program (Alpine #1 Sidetrack) As the Alpine #1 will be sidetracked (8 1/2" hole) just below the current 13 3/8" surface casing set at 1764' to a new TD at @10,000' (50 degree sidetrack), please note the following suggestions. This sidetracked interval will be drilled with a fresh water Gel/PAC system treated ~ required to TD for effective filtrate control and rheological stability as opposed to ~he rigid "Bland Mud" ~estric~ions which applied to the original well. 1. P&A the old well and lay the kick-off plug with the 10.5 ppg fresh water mud currently in the well. High viscosity gelled pills can be used to support the P&A plugs as well as the final kick-off plug set just below the surface casing. To improve the support for the kick-off plug, one may consider spotting a 16-18 ppg weighted mud pill from the top P&A plug up to the KOP to improve support for that plug. 2. After spotting the kick-off plug, kick-off the well with current fresh water mud. ~re-treat for cement contamination with bicarb and thinner based upon the calculated volume of cement to be drilled. AS THIS IS A HIGH SOLIDS MUD, ANTICIPATE SOME PROBLEMS IN THIS AREA AND BE PREPARED TO CONTROL T~R SYSTEM AS REQUIRED. Also when drilling out, run water as required to minimize chemical treatments to the mud system for the cement contamination. HOWEVER, DO NOT LET THE MUD WEIGHT FALL BELOW 9.5 PPG WHILE SIDETRACKING THE WELL. 3. After the well has been successfully sidetracked and 10-20' of new hole has been drilled, shut down and prepare to displace the well to a new fresh water Gel/PAC system from the Bariod Prudhoe Mud Plant as formulated below: On9 Barrel Formulation .934 bbls Fresh Water .1 ppb Soda Ash 6.0 ppbAquagel .02 ppb X-Tend II 2.0 ppb PAC-L .1 ppb caustic Soda .25 ppb Aldacide-G 87.0 ppb Baroid Initial Pro_p.e~ties Weight - 10.0 ppg vis - 45-50 sec/qt PV - 15-25 cps YP - 15-25 lbs/100 sq. ft. API Filt. - 6-8 cc's pH - 8.5-9.5 Gels - 5/12 MBT - 6 Note: Approximately 800 bbls of mud will be require for the displacement and to insure sufficient surface volume to begin drilling ahead. Arrange to have a certain amount of the new mud delivered and stored in the rig storage tank with the remaining volume coming directly off the vacuum trucks during the actual displacement. 4. Prior to displacement, circulate and condition the mud in the hole to acceptable theology to insure an efficient displacement. When satisfied with the condition of the mud in the hole, dump and clean the surface pits and equipment THOROUGHLY. 5. Bring in 'the new mud and displace the well (with bit on the bottom with conventional circulation) pumping at high rates (500-600 bpm) while rotating and reciprocating the drill string. Lead the displacement with a high viscosity spacGr formulated with 50 bbls of the ne_~ mud treated with Page - 7 FEB-13-95 MON 15:40 BARO1D DP, LG FLUIDS No, Uutz ob3uu .UZ/Oz Barazan (target a 60-80 YP). Rout the old mud from the hole for disposal returning the new mud to the pits as observed at the flowline. 6. Drill ahead in ~he new 8 1/2" hole with the Gel/PAC system t~eating as required as follows: Viscosity__- When drilling ahead, increase the viscosity as required with ~dditional bentonite or PAC-R treatments as required. Target an initial viscosity in the 45 sec/qt range with a PV/YP in the 15/15 range as drilling begins in the 8 1/2" hole (Note: New fluid f/mud plan~ will exhibit higher rheology until final shea~ through bit). Adjust the viscosity as required based upon the hole cleaning requirements of this high angle 50 degree sidetrack. Flow rates ~hould be kept in the 500-550 gpm range. (Note: ~OLE CLEANING ISSUES SHOULD GET A LOT OF ATTENTION ON T~IS 50 DEGREE SIDETRACK. US~ BARAZAN AS REQUIRED TO PROVIDE EFFECTIVE LOW SHEAR RATE VISCOSITY TO INSURE ~FFECTIVE ~OLE CLEANING RESULTS. A LSR-YP OF 5-8 S~OULD ALSO BE TARGETED.) To thin the mud, dilution with fresh water supplemented with Therma-Thin and/or Desco CF treatments should be considered. Treat the system as required to avoid excessive viscosity and gel structures. Filtrable Conrad1 - Control the A PI filtrate in the 6-8 cc range fo~ drilling in the initial $ 1/2" hole (Note: The new mud from the mud plant ~hould have an AP1 filtrate of @6-8 cc range). Continue with ~AC treatments as required while drilling ahead in the intermediate 8 1/2" hole down to the top of the HRZ or #1 Core Point whichever comes first (see ARCO representative for exact depths). At the top of the HRZ or #1 Core Point (whichever comes first) reduce the API filtrate to 4-5 cc's and the HTHP to 15 cc's at 200 degrees with additional PAC treatments and 1-3 ppb of Baranex. This filtrate control should be maintained to well TD. Mud Weioht - Currently the new mud is designated to be built to 10.0 ppg. Hold this mud weight while drilling to TD weighting up as dictated by hole conditions (SEE ARCO WELL PROGRAM FOR SPECIFIC MUD WEIGHT VERSUS DEPTH DETAILS). Concerns - *Continue with aggressive 5-10 gal/tour Aldacide-G to control bacteria. *Consider Barotrol/Boreplate (2#/2#) treatment for wellbore stability if required on this high angle well. *Maximize solids control efforts (mechanical separation and dilution) to keep LGS <60 ppb and MBT <25 ppb. *CONFIRM THE NEED FOR THE NABR TRACER TO BE RUN PRIOR TO ANY POTENTIAL CORING OPERATIONS. *Keep pH in the moderate 8.5-9.5 range with caustic soda. *Treat with lime as required to control alkalinities. *Use Barazan as required to provide effective theology for good hole cleaning. RECEIVEb Page- 8 ;~,~.zs~',~. ~Ji~ &. Gas Oons, Commission Ancflo~" POOL ARCTIC ALASKA RIG #6 DRILLING FLUID SYSTEM RECEIVED g~,~,sk:~, i}i~ & gas Co~s. ~o~]missio~ Anchor:~ '. RECE[VEg Oil & Gas Cons. OJL~-U. A- t 700PT OILWEI.L E-2000 - / Oil & Gas ~;on~.~ Anchor~ PRESSURE ANALYSIS ALPINE #1 B (Per 20 AAC 25.005(c)(7), as required in 20 AAC 25.033(e)) ARCO ALPINE #lB -1000 CASING 1765' -2000 -3000 -4000 -5000 -6000 -7000 -8000 -9000 -10000 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT ......... , ......... ~- ....... - .................. P-~ ~:" '--?': .................... r---, ....... ............. .~.~ .... < i ................. : ..... , ........ ~--- ~ [ ! ~ ALPINELOT 14.6 ..... ?'" i"" i---':= ............. ~= .................I i---~ .... i' ....... -i ....... i .... ~ ............. ~ ....... ~ .... i---' -':,,%'~'-'~--',"-'1 .... ~ ........ , : ~. ~ i -[ .... [ 'i' "- I---r ..... [ ..... ~, -i--n -- ._~_~ ...... ,., ~_ : ~ ......... t ~ : ,~ .......... , ....... ..... , ........ ; , , · ~,,,,~,,,,'.---4,;-.~ ~'"',,,,~ ~,"'~ ~ ~=-~,,,~,,,,-,~,,, ~ .......... k;=. .... ! .... ~- ...... - ..... 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[Zi ..... , ~----'~:~ ..... ~ , ................. ..................................................... ~ .... [~-~[-;-'[ F-~~--] ........ ~--~ [---~ "'L.~...~...~ ........ ~ZZ"'ii'"['] [7 ['[Zi~ ,, : E']] ~::[;;;; ..... "'"~"'~ ..... ~ ............ ~.. .......... ::::::: ..... .... ;4 ........ ~ ~: ............... q .................. ............. ~.~ ~ [ ............. i i i , i ~ , ] , r , i i i i i i i r r 8 9 10 11 12 13 14 15 16 17 18 EQUIVALENT MUD WEIGHT (LB/GAL) ARCO ALPINE #1 MUD WEIGHT CURVE 0 ................. '-'i ........ ["~ -'-! "": ........... [ ....... .................. ~----i ....... .................. i: ............. ~ [ :.~,..;: .................. " ......... ~ .......... :....i:...:. ...... '! .... i:;~ ........... :"- i ! i : i ! i i .......... ! .... i ...... '~--lq ...... ~ ....... i-'i-l-i---i ..... i-i [ i~ .... -';;i ........... ~"i .... '"'i'" ..... '"i"" ....... i---! i - ......... 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Commission '&n~,l~nr_-, .", ARCO BERGSCHRUND - 1 000 -2000 -3000 -4000 -5000 -6000 -7000 -8000 MUD WEIGHT CURVE 8 g 10 11 12 13 14 15 16 17 18 MUD WEIGHT LB/GAL R [~C[l~f[~o December 30, 1994 Subjecc To' From' Geopressure Prediction' for Alpine # 1 and Fiord #3 wells Fred Johnson Dean Gingrich Renee Harmon ATO- 1292 x1492 AND-790 x~5465 ,~qO- 774 x~5022 RECEIVED FE~, 2 "! i,995 weC,,~,~:,~, u t ~ as Cons. Corllllaiss~Qll The geopressure analysis for the Alpine # 1 and Fiord #3 us ~as bFn~or.?mpietea. Compared with the actual mud weight data used in the four nearby wells, Nechelik, Bergschrund # 1, Fiord #2, and Colville River # 1, the predicted pressure sections indicate no significant geopressure anomaly at the target interval. However, there is a low velocity anomaly in the shallow part of the section at the Alpine # 1 location (Figure 1, interval velocity of WKE92-02). There are no low velocity anomalies at the Fiord #3 location (Figure #2, interval velocity of WKE93-25). The purpose of this memo is to discuss potential causes of the shallow anomaly at Alpine # 1 and their likelihood. A. Accurate RMS velocity field prediction for the seismic line is crucial to the interval velocity and geopressure prediction work. Lateral velocity changes, poor signal to noise ratio in shallow seismic data, and very low CDP fold combine to degrade RMS velocities above 1 second on the seismic section. All of these problems are evident at the Alpine # 1 location and decrease the validity of using this data for accurate shallow (less than 1 second) pressure prediction. 1. Figure 1 shows some lateral permafrost velocity changes caused by the lake adjacent to the Alpine # 1 location. (sp. 1280-1360, from 0 to 300 ms.) If the permafrost layer under the lake is slightly thinner or lower velocity than expected, the low velocity anomaly at the C30 horizon would be significantly less than that shown in Figure 1. 2. Due to the shallow depth of the C50 to C30 interval, the CDP fold is low which decreases the lateral stability of the velocity field, especially in the presence of lateral velocity changes near the lake. Therefore, horizontal changes less than 40 to 80 shot points in width are suspect. (i.e. the "green pipe" at the Alpine # 1 location on Figure 4) B. Log correlations of the shallow portion of the 4 nearby wells is shown in Figure 3. These correlations have been tied to the seismic data using synthetic seismograms. The corresponding seismic picks are shown in Figures 1, 2, 4, and 5. The interval between the C30 and C50 markers is a shale prone section ti_at is lower velocity than the overlong and underlying shaly-siltstones. As seen in figure 3, in DAG 1995 Geopressure December 30, 1994 the Bergschrund and Fiord #2 ~vells, the C30 to C50 interval is shalier and lower velocity than in the Nechetik and Colville River wells. If this trend continues to the southwest toward Alpine # 1, this lithology change would account for the lower velocity as seen in the transit time plot at Alpine # 1 (Figure 1). C. Shown on Figure 3 are the gas show zones in each well that occur immediately below the C30 marker. Encountering gas in this zone is common in Colville Delta drilling and is controlled with 10 to 10.6 pound mud weight. At the updip Alpine # 1 location, encountering a similar gas zone is expected. A slightly higher gas saturation in the rocks at the Alpine # 1 location than encountered at Bergschrund # 1 would also account for the low velocity anomaly as seen in the transit time plot on Figure 1. D. The transit time plots are converted into pore pressure in pounds per gallon equivalent mud weight plots (Figures 4 and 5). To do this it is assumed that there are no lateral lithology or pore fluid changes away from the calibration wells, Bergschrund # 1 and Fiord #2. Both of these assumptions could be wrong as per 2, and 3 above. Therefore, the low velocity and geopressure anomaly at the C30 level at the Alpine # 1 location on WKE92-02 is interpreted to be: 1. Less than that predicted by the pore pressure plot. Due to thinner than predicted permafrost under the lake (sp. 1280-1360) and poor seismic data quality (sp. 1360-1440). 2. Caused by lateral lithology and gas saturation changes. Due to the expected lateral velocity decrease caused by the increase in C50-C30 shaliness and the expected lateral increase in gas saturation immediately below C30. 3. Not an indicator of a shallow drilling hazard. By using a casing and mud weight program similar to that used in the nearby wells, the Alpine # 1 and Fiord #3 wells can be safelv drilled. cc. Renee Hannon (w/o plots) Mitch Honeycutt (w/o plots) Lih Kuo (w/o plots) Jerry Veldhuis Andrew Wu Chi Young ANO-774 ANO-786 ANO-990 ANO-798 ANO-992 PRC-D2623 DAG 1995 Geopressure t t I i '1 0 ~= 0 L~ Z o .,4 i ! 0.0 0.5 1.O ALPINE # 1 SWspFJEVE1275 ~. ?E~ ~r° 7 t9~5 1360 I40 1266 1~80 130~ 13~0-~ 1~46 136~ 1580 1400 1420 1440 I -t t INTERVAL TRANSIT TIME WKE92-02 1460 57 70 /7 98 11 FIGIII~E 'i 0.0 0.5 1.0 12~0 12~;0 12rio 1300 I LAKE 13~0 1340 ALPINE #1 SP 1360 1360 13B0 1400 1420 1440 1460 GEOPRESSURE PROFILE WKE92-02 ~.0 8.3 8.6 9.3 9.6 9.9 102 10 ',5 109 112 11 131 13 q 137 1,t / -1000 -2000 -3000 ALPINE #lB INTERVAL TRANSIT TIME VS DEPTH SP 1360 WKE 92-02 0 ........................................................................................................................................ ~ ............. ! .......... ! ........ ~ ....... ~ ...................... ~.-..;-.-.~.~.~.-.~, ......... : ................. 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' --~_.., ..~- ..................... -6000 ..................................................................................... · ................... ~ ......~ · - ................................................................ ~ .... ~ .................. ~.. -~ ................. , ........................... ,,. ........ ~ ............... ~- .. ~.~. _: ............. : ....... ::~::~__ ......................................... : ....... : ........... ·_.~ ~- -- · .... .,_ ..... ~_ -7000 ................................................................................................................................................................................................ : ...... : ................ .................................... - ...... .~::~., ~ r~. -~¢ ~-~ · -~ -~-~-. ,._..._. ~ ..-~. ~~-_--_~ .................... ~ ............................. , , 1 0 1 O0 1000 INTERVAL TRANSIT TIME MS/FT ¢~_¢ Z"~ cc ;.~k,aska (jk[ & Gas Cons. Commission Anchort ALPINE #1 B INTERVAL TRANSIT TIME VS DEPTH SP 1360 WKE 92-02 0 ..................... , ...... ~..~.... ..... ~. ~... ~.-:, ~.~--~-~.~ ..... ~ .... .,..~ ..... ~. :. ........................................................................ ,...~ ............. ~ ......... ............................ ~ ....... ? ................ ~, .-~, .......... : .......... ~ ..................... , ..... .,. .... ~ ................................................................................. ~ ...... : ................ ~ .................................................................. ,. .................................................. ~ ............... ~ ........................................... ~. . ..... ~ '--' ........... ~: ....... ~'~'~ ...... ' -~-'-~" ..... ~- ~'-'" ........... ~ .......... ~"-'~ ~'""~ ........................ -~k- ........ 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'. .............. ; , ~ ~ ........................... , .......... ;.. ........ _~. .~ -~. _~-~ ~ ................. ~~ ~..~ ~.~ ............... ~ ............................. ~..~ ....... ~.~ ..... ~.; .~-~.~--~-~,,. .... ,-~~ ~- .~ ~_ ';-~... ~-.-~. ~ .-~.~.~-~-~--~--~- ~-~~ ~ ~~-~ ~ .'.,.~ ............ ~. ......... ............. ~~_~ ~.,.,,.~ ~.,..v,.,w,.,,~ ~ ~ ~_ ....~: ~ ................................................ ~ ,,. .......... ~ .......... ~,,..wl ~..-~c_ .'r~-~. ... -- ~.~ .............................. ; .............. ~.~.~ ~..~ ..... ~.... :.~..~..~, ...................... ~.~.~.~.~.~...~..~...~ .................................. ~. .................................... ~ .......... --- . .... ~ ............................................ ~ ~., ....... ~~. ~ ..... ~.~ ........... . ....... ~ ...... ~ ................ , ........................... ~.....~.~.~..~...~.~.~ ~ ......... ,. ~ ......... ., ........ . ................... ~ ...................................................... ,. ..................................................... ..... ~.~ ............. . ................... ~ ~ ~ ~ ~ ~ ....... ~..~...~....~.~ ......... ~ ............... ~ ....~-.~.~ ............ . ...... ~.: ............. ~...~ ~.. , .~ .................................................................. .,. ......... ~ ......... ~ ..... , .,- ..... .. ......... ~ ................................. .~ ................... ~ ............. ~ ....... ~.... -..~.~.~ ~ ..... ~ .-,... ~.-.~-. .... .. ....................... ~ ......... ,,~.. ~.~..-~ ............................................ .,. ............. , ............................................ -1000 -2000 -3000 -4000 -6000 -7000 -8000 -go00 -10000 1 0 1 O0 1000 INTERVAL TRANSIT TIME MS/FT c,: 5 .~c~o~ I-- O. i~ -5OOO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend Alter casing _ Repair well Change approved program _ Operation Shutdown_ Re-enter suspended well_ Plugging _ Time extension Stimulate Pull tubing_ Variance_ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1465' FSL, 2250' FWL, Sec. 1, TI!N, R4E, UM At top of productive interval {, '''~ i~ "' ' ~ ~-~,~', ,;i ~ .... At effective depth At total depth 1451' FSL, 2270' FEL, Sec. 1, T11N, R4E, UM 12. Present well condition summary Total Depth: measured 7 5 0 0' true vertical 7 5 0 0' feet feet 6. Datum elevation (DF or KB) RKB 38' Above SL 7. Unit or Property name N/A 8. Well number ALPINE #1 9. Permit number 94-172 10. APl number 5o-103-20211 11. Field/Pool Wildcat feet Effective depth: measured true vertical feet feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size.,. . 8 0 20 "' ~ , , -' \1735'~ 13-3/8" ,,,? ',,. measured true vertical Tubing (size, grade, and measured depth Packers and SSSV (type and measured depth) Cemented 350 Sx AS I 350 Sx AS III & 650 Sx AS I Measured depth True vertical depth 110' 110' 1765' 1765' RECEIVED (':,,/,,, ..... '/¢:.~a, 4ka)~il,~: ~ Gas Co~. Commission 13. Attachments P&A wellbore. Description summary of proposal_ Detailed operation program BOP sketch 14. Estimated date for commencing operation February 15. 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas ~ Suspended Service 17. I here~y certi,ty that the foregoing is true and correct to the best of my knowledge. Signed~.,~,,~.~ ,~A' /¢~//~¢: ~,vx, l/I Title Area Drillincj Encjineer Cz FOR COMMISSION USE ONLY Mechanical Integrity Test Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance Subsequent form require 10-~ Approved by the order of the Commission Form 10-403 Rev 06/15/88 IApprova. L, No. '~," 7~ /ii-"~,1 ,,--, _¥ Commissioner Date SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST FIELD & POOL UNIT# PROGRAM: exp [] dev [] redrll/~ serv ON/OFF SNORE ADMINISTRATION ENGINEERING 1. Permit fee attached ................... 2. Lease number appropriate ................ 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ......... Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... Conductor string provided ................ Y Surface casing protects all known USDWs ......... Y CMT vol adequate to circulate on conductor & surf cng.. Y CMT vol adequate to tie-in long string to surf cng . . .~Y CMT will cover all known productive horizons ...... Casing designs adequate for C, T, B & permafrost .... Adequate tankage or reserve pit ............. ~ 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 21. If a re-drill, has a 10-403 for abndnmnt been approved..Y N 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. Y GEOLOGY 30. Permit can be issued w/o hydro~en sulfide measures .... .Y~N 31. Data presented on potential overpressure zones .... .~ N 32. Seismic analysis of shallow gas zones ......... N g3. Seabed condition surve7 (if off-shore) ......... ¥ 34. Contact name/phone for weekl7 progress reports .... [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: TAB ,,yELL PERMIT CHECKLIST , COMPANY INIT CLASS PROGRAM: exp~ dev [] redrll [] serv [] ADMINISTRATION ,-~, 1. Permit fee attached .................. ~ N 2. Lease number appropriate ............... ~ N 3. Unique well name and number .............. 4. Well located in a defined pool .............. Y 5. Well located proper distance from drlg unit boundary..~ N 6. Well located proper distance from other wells ..... ~ N ' 7. Sufficient acreage available in drilling unit ..... ~ N 8. If deviated, is wellbore plat included ........ ~ N 9. Operator only affected party .............. ~ N 10. Operator has appropriate bond in force ......... ~ N Il. Permit can be issued without conservation order .... ~ N 12. Permit can be issued without administrative approval. .~, N 13. Can permit be approved before 15-day wait ....... ~ N ENGINEERING 'D TE 15. Surface casing protects all known USDWs ......... Y 16. CMT vol adequate to circulate on conductor & surf csg.. Y 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ 21. If a re-drill, has a 10-403 for abndnmnt been approved..Y 22. Adequate wellbore separation proposed .......... ~ 23. If diverter required, is it adequate .......... ~ 24. Drilling fluid program schematic & equip list adequate . 25. BOPEs adequate ..................... ~ 26. BOPE press rating adequate; test to ~--O~ psig. ~ 27. Choke manifold complies w/API RP-53 (May 84) ....... :Y 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of ~2s gas probable ............. Y ~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures...~.Y~ N 31. Data presented on potential overpressure zones .... ~ N 32. Seismic analysis 9f shallow gas zones ......... N 33. Seabed condition survey (if off-shore) ......... ~,-~~ 34. Contact name/phone for weekly progress reports .... ~ N [exploratory only] GEOLOGY: ENGINEERING: COMMI SS ION: Comments/Instructions: Z 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. MWD RUN 9 6382.02 DOUG ELLIS DON McKELVEY Tape Subfile 2 is type- LIS TAPE HEADER EXPLORATION UNIT ~qD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 12 ALPINE #lB 501032021102 ARCO ALASKA INCORPORATED SPERRY-SUN DRILLING SERVICES 26-JUN-95 MWD RUN 10 MWD RUN 11 DoUG ELLIS DOUG ELLIS D. BUMGARNER D. BUMGARNER MWD RUN 13 MWD RUN 14 DOUG ELLIS DON McKELVEY DOUG ELLIS DON McKELVEY 1 liN 4E JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 38. O0 30.62 7.60 DOUG ELLIS D. BUMGARNER OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) DRILLERS DEPTH (FT WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 20.000 120.0 16.000 13.375 1768.0 8.500 8850.0 X=375455.03 MWD - DGR/EWR4/CNP/DSFD. LOCATION: Y=5972482.25 ALL DEPTHS ARE BIT DEPTHS REFERENCED TO DRILLERS TALLY. CRITICAL VELOCITIES ARE CALCULATED USING THE BINGHAM PLASTIC MODEL. ALL DATA WAS RECORDED DOWNHOLE WHILE DRILLING UNLESS OTHERWISE STATED. KICK-OFF POINT IS AT 1863' MD. NO DATA IS AVAILABLE FROM 2146' TO 2221' MD DUE TO TOOL MALFUNCTION. NO DEPTH SHIFTS WERE DONE AS THIS LOG IS THE DEPTH FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SErMMARY PBU TOOL CODE GR RP NPHI RHOB $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 1700.0 8803.0 1700.0 8781.0 7750.0 8788.0 7757.0 8795.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 9 1863.0 2239.0 10 2239.0 5060.0 11 5060.0 5997.0 12 5997.0 7804.0 13 7804.0 7891.0 14 7891.0 8850.0 MERGED MAIN PASS. NO DEPTH SHIFTS WERE APPLIED. MERGED DATA FOR ROUGHLY THE TOP 100' IS FROM THE PILOT HOLE, ALPINE - 1. CN WN FN COUN STAT : ARCO ALASKA INC. : ALPINE #lB : WEST COLVILLE EXPLOR : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units 1 GR MWD 68 2 RPX MWD 68 3 RPS MWD 68 1 AAPI 1 OHMM 1 OHMM API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 RHOB MWD 68 1 G/C3 4 8 ROP MWD 68 1 FPHR 4 9 FET MWD 68 1 HR 4 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 585 4 90 120 46 4 90 120 46 4 90 890 01 4 90 350 01 4 90 810 01 4 9O 180 01 36 Tape File Start Depth = 9000.000000 Tape File End Depth = 1700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 146011 datums Tape Subfile: 2 689 records... Minimum record length: Maximum record length: 46 bytes 1006 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 1771.0 EWR4 1764.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 2147.0 2139.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ 02-PLAR-95 2.19A/2.05 3.93 /1.37 MEMORY 2239.0 1863.0 2239.0 0 3.8 10.1 TOOL NUMBER P0345CRG6 P0345CRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN)' DRILLER'S CASING DEPTH (FT): 8.500 1768.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: BLAND 10.00 39.0 9.9 5OO 5.4 3.500 2.980 3.800 3.500 74.0 88.0 74.0 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 9. $ : ARCO ALASKA INC. : ALPINE #lB : WEST COLVILLE EXPLOR : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 ,2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 36 Tape File Start Depth = 2250.000000 Tape File End Depth = 1700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary- Rep Code: 68 8809 datums Tape Subfile: 3 101 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 4 is type' LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 10 DEPTH INCREMENT: .5000 FILE SLrMMARY VENDOR TOOL CODE START DEPTH DGR 2221.0 EWR4 2201.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 5029.0 5022.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ 04 -MAR- 95 2.19A/2.05 3.93 /1.37 MEMORY 5060.0 2239.0 5060.0 0 12.1 40.4 TOOL NUMBER P0345CRG6 P0345CRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 1768.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: BLAND 10.10 42.0 9.9 400 6.2 3.500 2.420 3.900 3.500 76.0 113.0 76.0 76.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) ' .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ)' .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 10. $ : ARCO ALASKA INC. : ALPINE #lB : WEST COLVILLE EXPLOR : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 2 RPX MWD 68 3 RPS MWD 68 4 RPM MWD 68 5 RPD MWD 68 6 ROP MWD 68 7 FET MWD 68 1 AAPI 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 FPHR 4 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 188 Tape File Start Depth = 5100.000000 Tape File End Depth = 2200.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 192420 datums Tape Subfile: 4 253 records... Minimum record length' 62 bytes Maximum record length: 998 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 5019.0 EWR4 5012.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 5956.0 5949.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ 05-MAR-95 2.19A/2.05 3.93 /1.37 MEMORY 5997.0 5060.0 5997.0 0 37.7 43.1 TOOL NUMBER P0345CRG6 P0345CRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 1768.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: BLAND 10.10 42.0 9.1 300 6.0 3.500 2.420 4.000 3.500 76.0 113.0 76.0 76.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 11. $ : ARCO ALASKA INC. : ALPINE #lB : WEST COLVILLE EXPLOR : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GR MWD 68 2 RPX MWD 68 3 RPS MWD 68 4 RPM MWD 68 5 RPD MWD 68 6 ROP MWD 68 7 FET MWD 68 1 AAPI 1 OHMM 1 OHMM 1 OHMM 1 OHMM 1 FPHR 1 HR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) Total Data Records:, 65 998 BYTES * Tape File Start Depth = 6000.000000 Tape File End Depth = 5000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary- Rep Code: 68 24818 datums Tape Subfile: 5 130 records... Minimum record length' Maximum record length: 62 bytes 998 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and' log header data for each bit run in separate files. BIT RUN NO: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 5956.0 EWR4 5949.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 7763.0 7756.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): 07-MAR-95 2.19A/2.05 3.93 /1.37 MEMORY 7804.0 5997.0 7804.0 0 35.0 43.1 TOOL NUMBER P0345CRG6 P0345CRG6 8.500 1768.0 BLAND 10.10 41.0 9.1 300 5.8 3.500 2.194 4.OOO 3.500 74.0 122.0 74.0 74.0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 12. $ : ARCO ALASKA INC. : ALPINE #lB : WEST COLVILLE EXPLOR : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GR MWD 68 2 RPX MWD 68 3 RPS MWD 68 4 RPM MWD 68 5 RPD MWD 68 6 ROP MWD 68 7 FET MWD 68 1 AAPI 1 OHMM 1 OHMM 1 OHMM 1 OHMM 1 FPHR 1 HR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) Total Data Records: 124 998 BYTES * Tape File Start Depth = 7810.000000 Tape File End Depth = 5900.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 222989 datums Tape Subfile: 6 189 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 7764.0 EWR4 7742.0 CNP 7750.0 DSFD 7757.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 7850.0 7829.0 7836.0 7843.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON DSFD DUAL SOURCE DENSITY DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT)' BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 07-MAR-95 2.19A/2.05 3.93 /1.37 MEMORY 7891.0 7804.0 7891.0 0 .0 .0 TOOL NUMBER P0335CRNDG6 P0335CRNDG6 P0335CRNDG6 P0335CRNDG6 8.5OO 1768.0 BLAND 10.10 41.0 9.1 30O 5.8 3.500 2.022 4.000 3 .~500 74.0 133.0 74.0 74.0 SANDSTONE 2.65 HOLE CORRECTION ~IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ)' REMARKS: MWD RUN 13. $ CN WN FN COUN STAT : ARCO ALASKA INC. : ALPINE #lB -: WEST COLVILLE EXPLOR : NORTH SLOPE : ALASKA .000 .0 0 * FORMAT RECORD (TYPE~ 64) ONE-.DEPTH PER.FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 2 RPX MWD 68 3 RPS MWD 68 4 RPM MWD 68 5 RPD MWD 68 6 NPHI MWD 68 7 RHOB MWD 68 8 ROP MWD 68 9 FET MWD 68 1 AAPI 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 PU-S 4 1 G/C3 4 1 FPHR 4 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 350 01 1 4 90 810 01 1 4 90 180 01 1 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 17 Tape File Start Depth = 7900.000000 Tape File End Depth = 7700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary' Rep Code: 68 28829 datums Tape Subfile: 7 86 records... Minimum record length: 46 bytes Maximum record iength~ 1006 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 7845.0 EWR4 7824.0 CNP 7831.0 DSFD 7839.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8803.0 8781.0 8788.0 8795.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON DSFD DUAL SOURCE DENSITY DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 09-MAR-95 2.19A/2.05 3.93 /1.37 MEMORY 8850.0 7891.0 8850.0 0 30.3 34.9 TOOL NUMBER P0335CRNDG6 P0335CRNDG6 P0335CRNDG6 P0335CRNDG6 8.500 1768.0 BLAND 10.10 41.0 9.0 3O0 4.6 2.400 1.420 2.800 2~400 74.0 129.2 74.0 74.0 SANDSTONE 2.65 HOLE CORRECTION tiN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 14. $ CN WN FN COUN STAT : ARCO ALASKA INC. : ALPINE #lB : WEST COLVILLE EXPLOR : NORTH SLOPE : ALASKA .000 .0 0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 2 RPX MWD 68 3 RPS MWD 68 4 RPM MWD 68 5 RPD MWD 68 6 NPHI MWD 68 7 RHOB MWD 68 8 ROP MWD 68 9 FET MWD 68 1 AAPI 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 PU-S 4 1 G/C3 4 1 FPHR 4 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 350 01 1 4 90 810 01 1 4 90 180 01 1 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 97 Tape File Start Depth = 9000.000000 Tape File End Depth = 7800.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 247000 datums Tape Subfile: 8 166 records... Minimum record length: Maximum record length: 46 bytes 1006 bytes Tape Subfile 9 is type: LIS 95/ 6/26 01 **** REEL TRAILER **** 95/ 7/10 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 10 JLY 95 1:28p Elapsed execution time = 18.29 seconds. SYSTEM RETURN CODE = 0