Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
199-006
199-006 191-151 197-024 ESET# 38794 38795 38796 38794 199-006 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.14 14:22:30 -08'00' Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~ ~ - (..2~,¢, File Number of Well History File PAGES TO DELETE RESCAN [] DIGITAL DATA [] [] OVERSIZED Complete Color items - Pages: 12,. , ~,~, ~ 3, ~ , ~O~, ~C,~ Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: Other - Pages: Diskettes, No. Other, No/Type Logs of various kinds Other COMMENTS: Scanned by: Bevedy Mildred Damtha ~Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha~Lowell Date: 199-006-0 MELTWATER SOUTH 1 50- 287-20014-00 ARCO ALASKA 1NC Roll #1: Start: Stop Roll #2: Start Stop MD 08935 TVD 08377 Completion Date.~"~2/11/99 Completed Status: P&A Current: T Name D 9105 OH 3/9/99 3/15/99 L CMRT ~"~L 3500-8886 OH 3/15/99 3/15/99 L CST/GR ~,~I~L 3458-8839 CH 5 3/15/99 3/15/99 L DSI/GR ~/AL 2400-8900 OH 3/15/99 3/15/99 L MDT ~1~ 3500-8886 OH 3/15/99 3/15/99 L MUD ~,~~OCH 108-8935 OH 2 3/15/99 3/15/99 L PEX-AIT ~'~L 2535-8886 OH 3/15/99 3/15/99 L PEX-CN/TDDT/GR ~ 2400-8886 OH 3/15/99 3/15/99 R SRVY CALC ~ 0-8935 Oil 3/12/99 3/15/99 Interval Sent Received T/C/D ~1~ SPERRY MPT/GR/EWR4/CNP/SLD Thursday, February 01,2001 Page 1 of 1 STATE OF ALASKA AL~ OIL AND GAS CONSERVATION COI~I~.~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well ' Classification o! Service Well ' · . Oil r'l Gas ri.. suspended ri' Abandoned I~1 ' · Service D 2. Name ol Operator 7. Permit Number ' ARCO Alaska, In(=. , 99-006 , 3. Address 8. APl Number P, O. Box 100360, Anchorage, AK 99510-0360 50-287-20014 - 4. Location of well at surface ~ ~. 9. Unit or Lease Name . 671' FNL, 1748' FWL, Sec. 33, 'rTN, R7E, UM "lt.U~;~fK,~!~lm~r..mr. ! N/A At Top Produdng Interval~ 10' Well Number 337' FNL, 759' FEI., SEC. 32, TTN, R7E, UM. ~ ~ Meltwater South #1 ' :,{~, ~ 11. Field and Pool At Total Depth 306' FNL, 817' FEI., SEC 32, 'I'TN, R7E, UM Tam Exploration 5. Elevation in feet (indicate KB, DF, etc.) 16, Lease Designation and Serial No. ' RKB 28 . feet.I ADL 389047 ALK 4994 ' 12. Date Spudded 13. Date T.D. Reached 14. Dale Comp., Susp. Or Aband.115.Water Depth, il offshore 16, No. of Completions January 26, 1999 February 6, 1999 2/11/99 P&A I N/A ., feet MSL 0 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Direotlonal Su'wey '120. Depth where SSSV set 21. Thickness of Permafrost 8935' MD / 8377' TVD surfac~ ' YES [] No DI N/~, feet MD 1420' 22. Type'Electrio or Other Log~'Run " ' - . . Platform Express/CMR, 'Dipole Sonic ' ' ' CA~ING, LINER AND cEMENTING RECORD 23. , SETTING DEPTH MD .. I · CASING SIZE WT. PER FT. GRADE TOP BO'FrOM HOLE SIZE CEMENTING RECORDI AMOUNT pULLED. , 16" 62.5# H-40 · . Surface · 118' 24" 9 cu yds High Early i ii i 9.625" 40~ L-80 Surface '- 2549' 12.25" 520 sx AS III, 340 sx Class G '- ,,, , cement retainer O 2498' , " refer to page #2 i;)r cement plug summmy · , 24. Perforations open to Production (MD + TVD ~f Top an~l Bottom and 25. TUBING I~ECORD . ,, interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) , N/A . 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. N/A DEPTH INTERVAL (MD) . AMOUNT & KIND OF MATERIAL USED · ,,, . · . · 27. PRODUCTION' TEST Date First Production Method of Operation (Flowing, gas lift, etc.) · · N/A Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE lC, AS-OIL RATIO Test Pedod >I Row Tubing Casing Pressure. .. Calculated OIL-BBL GAS-MCF' WATER-BBL OIL GRAVITY - APl (con') ' · 24.HOur Rate > . , , 28. CORE DATA Brief deecdption of Iithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. · · $~ ^tt~¢hm~nt · · . · . ^laska Oil & ~as Cons, ¢Ommissioa .. Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in .duplicate NAME Top West Sak Base West Sak C-80/K-10 C40/K-5 Top Bermuda SS K-3 GEOLOGIC MAR~ MEAS. DEPTH 1785' 2444' 3376' 4484' 72O6' 7567' TRUE VERT. DEPTH 31. LIST OF A'R'ACHMENTS Summary of .Daily Operations, Directional Survey, Core Description; Mud Logs 32. I hereby certify that the following Is true and correct to the best of my knowledge. Paul Mazzollnl FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Tests: MDT - Settoo112 times from 7154'-8772' MD. Had 5 dry tests and lost seal 7 times. No samples were recovered. Refer to attachment for details. cement plug #1: 8935'-7120' cement plug #2: 4000'-3700' cement plug #3: 3570'-337O' cement plug #4: 2398'-2658' cement plug #5: 300'-surface INSTRUCTIONS Preparecl t~y Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, .water supply for injection, observation, injection for in~situ combustion. Item 5: Indicate which elevation is used as reference (where not otherWise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than oneinterval (multiple completion), so state in item 16, and in item 24'show the producing intervals for 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.).. Shut-in, Other-explain. Item 28: If no cores taken, indicate 'none'. Form 10-407 Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection,' Gas Injection, RECEIVED ^l~sk~ Oil & G~s Cons. Commission Anchorage Client: ARCO ALASKA, INC. Field: WILDCAT Well: MELTWATER SOUTH #1 Run date: 6-FEB-1999 Tool: MRPS 1- Probe Type: Conventional probe Gauge: BQP1 Gauge Resolution: 0,010 psi Test File Depth TVD Drawdown Mud Pressure Last read Formation Test Type Mobtllty Before After build-up Pres Pressure FT FT MD/CP PSIA PSIA PSIA PSIA 2 9 2800.05 2619.02 0,50 1405.57 1405.14 966.23 966.23 Volu metric Pretest 4 lO 2918.07 2'3'22.73 121.97 1460.77 1460.50 999.50 999.50 Volumetric Pretest 5 11 3163.11 '.2-~]37.63 1576,08 1576.04 Lost Seal 7 12 3164.17 29'38.55 32.56 1576.4,4 1576.18 1136.44 1136.44 Volumetric Pretest 9 13 3194.15 .~,~2964.77 18.09 1590.85 1590.67 1589.93 1589.93 Volu metric Pretest · 10 14 3193.15 *~2963. ~0 9.58 1589.91 1589.75 1149.62 1149.62 Volu metric Pretest 11 15 3423.10 3164:' ~1 1697,97 1697.56 21.15 Dry Toot 12 16 3429.08 3169'.'51 1700,57 1707.26 25.06 Dry Test 13 18 4697 .O7 ~2 8i~,~i,3 2298.27 2298.25 Lost Seal 2 24 7154,.03 6592,,54 3520.18 3518.89 29.70 Dry Test 3 25 7119,13 655.~.'~8~2 3500.91 3501.50 Lost Seal ,~ 26 7256.07 669&:;',~.2 3572.40 3572.43 Lost Seal 5 27 7257.39 6695'~;44 3572.56 3572.97 Lost Seal 6 28 7303.20 : 674,1~D8 3596.29 3596.66 Lost Seal 7 29 7302.64 6740.53 3595.23 3596.27 Lost Seal 8 30 7318.21 6756.04 3604.21 3603.85 53.09 DryTest 9 31 7368.22 6805',.89 3629,53 3629.25 38.41 Dry Tgst 10 32 7405.16 6842 ..'12 3648.25 3649.17 Lost Seal 11 33 7408.19 6845.75 3649.98 3649.88 33.40 OryTest 13 36 877,~.02 8210.07 1392.74 4354.56 4354.88 Lost Seal 14 37 8772.92 8208.97 4352.76 4352.49 594.'32 Dr/Teat ........ PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Paul Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 March 7, 2001 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: Meltwater South #1 (Permit 99-006) Revised Completion' Report Dear Mr. Commissioner: Phillips Alaska, Inc., as operator of the Meltwater South #1 exploration well, submits the enclosed revised "Well Completion Report" (AOGCC form 407). This revision will correct the original completion report sent May 14, 1999. There.are two corrections: 1) one completion string was noted on the original in box 16 when in effect, there was none, and 2) a MDT test was run and noted in box 30 of the form. The Commission is requested to keep confidential the enclosed information due to the exploratory nature of this well. If you have any questions regarding this matter, please contact me at 263-4603 or Tom Brassfield at 265-6377. Sincerely, Paul Mazzolim Exploration Drilling Team Leader PAI Drilling PAM/TJB/skad RECEiV h Alaska Oil & Gas Cons. Commission Anchorage TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERYATION COmPreSSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 8, 1999 Jim Ruud, Manager Land Department, ATO 1470 ARCO Alaska, Inc. P O Box 100360 Anchorage, Alaska 99510-0360 Re~ Location Clearance, Three North Slope Wells- Meltwater South # 1 and Fiord wells ~4 & #5 Dear Mr. Ruud: On August 3, 1999 DNR/DOL's Natural Resource Officer, Leon Lynch inspected three North Slope locations for closure. He recommended closure for the following three North Slope exploratory wells: Well Name PTD No. Meltwater South # 1 ~9,~~ Fiord #4 99-016 Fiord #5 99-020 Final Location Clearance is hereby approved for the three above listed ARCO North Slope exploratory wells. The Commission will require no additional work on subject wells; however, ARCO remains liable if problems with the wells occur in the future. Sinj:ereJy,// ,, . Robert N. Christenson Chairman cc: Blair Wondzell Leon Lynch, DNR/DOL Lcar3ns99.DOC · Re: Well Inspections Subject: Re: Well Inspections Date: Tue, 07 Sep 1999 08:34:00 -0800 From: Blair Wondzell <blair ~vondzell@admin.state.ak.us> Organization: State of Alaska, Dept ~fAdmin, Oil & Gas To: Leon Lynch <leonl@dnr.state.ak.us> Thanks for your memo. Blair Leon Lynch wrote: > > > > > All the sites were acceptable to DNR for closure as they were free of trash and debris. As I understand it, the Commission also checks to see if P/A wells have sufficient mounding around well cellar to prevent ponding. This requirement was satisfied at Meltwater South and Fiord 5. Fiord 4 was drilled on a tidal flat and subject to wave action- no mound was located. Red Dog was suspended. Please cal me if you have any further questions. Blair Wondzell wrote: > > Leon, > Thanks for the photos of the well inspections you did in early August. > Could you please find the date of the inspection trip. If I understand > the wording in your letter to me, your found all sites acceptable to > DNR; Red Dog for suspension and Meltwater South, Fiord 4, and Fiord 5 > for a P&A location acceptance - please confirm. > > Leon, I appreciate your help. > > Thanks, Blair 9/2/99 I of I 9/7/99 8:34 AM PLUGGI_N*~~ LOCATION CLE~~CE REPORT .~o=a cas/-nq si=e, w=, da.~h, c=: vol, & ~: ~.: /~_ // ~ '//7 ' ?~~ Liner: Review the well file, and-c~-~,-_~: cn plugging, well head and !oca=icn clearance - .ur:vide loc. clear, code. ' ~ ~1 Meltwater South #1 ~ RIH WITH 5" DP TO 8,935'. CIRC AND CONDITON MUD TO SPOT ABANDONMENT PLUG. PJSM. SPOT BALANCE CEMENT PLUG#1 IN THREE STAGES. FIRST STAGE F/8,935' - 8,335' 197 SX CL "G" @ 15.8 PPG., 41 BBLS SLURRY. LD 19 JTS 5" DP.- CIRC AND COND MUD @ 8,335' - 9.9 PPG.. "" SPOT SECOND STAGE PLUG#1 F/8,335' - 7,735' - 201 SX CL "G" @ 15.8 PPG, 42 BBLS SLURRY. GARRY SCHULTZ WITH ADNR ON LOCATION. POOH TO 7,735'. CIRC AND CONDITION MUD- 9.9 PPG. SPOT THIRD STAGE OF PLUG#1 - FROM 7735'-7120'- 222 sx CI "G" @ 15.8 ppg. POOH TO 7000'. CIRC AND COND MUD- 9.9 PPG. POOH TO 4180'. Circ and cond. Spot 22 bbl hi vis pill from 4180'-4000'. Spot cement plug #2 f/4000'-3700' - 155 sx CI "G" @ 15.8 ppg. Circ out contaminated mud. Lou Grimaldi with AOGCC on location to witness top plugs. SPOT 14 BBLS HI-VIS PILL FROM 3,700' - 3,570'. LD 4 JTS 5' DP. SPOT CEMENT PLUG #3 - FROM 3,570' - 3,370 - 105SX CL "G" @ 15.8 PPG - 22 BBLS. STAND BACK 10 STANDS 5" DP. CIR BTMS UP TO CLEAN UP DP - SLUG DP. POOH LAYING DOWN 5"' DP AND 3.5" TUBING. MU HOWCO SETTING TOOL AND 9 5/8" EZSV RETAINER. RIH. SET RETAINER @ 2,498'. CIRC AND COND MUD - 9.9 PPG. STING INTO RETAINER.SET 30K ON RETAINER. PRESS CSG TO 1,000 PSI. ESTAB. PUMP IN RATE 3 BBP - 550 PSI.PUMPED PLUG #4 FROM 2,398' - 2,658' - 89 SX CL "G" @ 15.8 PPG - 18.5 BBLS -BELOW RETAINER.STUNG OUT AND DUMPED 38 SX CL "G" ON TOP OF RETAINER. LD 9 JTS CIRC - CLEAN UP DP. POOH WITH SETTING TOOL LAYING DOWN DP. PULLED WEAR RING AND MOUSE HOLE N.D. BOP'S 11" 5M SS head. RIH WITH 3.5" TUBING TO 300'. DISPLACE HOLE WITH WATER. SPOI-rED PLUG #5 F/300'. 33'. 155 sx AS1 @ 15.7 ppg - 23 bbls. POOH - LD tubing, well P&A'd. Clean out cellar and finish cleaning pits. Released rig @ 2200 hrs. 2/11/99. Location cleaned after rig #141 demob complete. Surface plug & location condition witnessed by Lou Grimaldi of AOGCC. Cap welded in place. ARCO, Meltwater South #1 & APl# 50-287-20014. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 March 16, 2001 Howard Okland State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED MAR 2 0 2_001 Alaska 0il &eas Cons. Commission Anchorage Subject: Core Description for Meltwater South #1 (Permit #99-006) Dear Mr. Oldand: Phillips Alaska, Inc. submits the attached core description for Meltwater South #1. This is additional data for this well that we sent earlier. If you have any questions regarding this matter, please contact me at 263-4603. Sincerely, P. Mazzolini Drilling Team Leader PAI Drilling PM/skad PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax.' (907) 265-6224 March 14, 2001 Howard Okland State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Core Description for Meltwater South #1 (Permit//99-006) Dear Mr. Okland: Phillips Alaska, Inc. submits the attached core description for Meltwater South #1. If you have any questions regarding this matter, please contact me at 263-4603. Sincerely, P. Mazzolini Drilling Team Leader PAI Drilling PM/skad RECEIVED ~AR 1 5 2001 Alaska 0il & Gas Cons. Commission Anchorage SUIARY OF VER~CAL PERMEAblY Ccxe Depth,Overburden, IoAlrt e~berg~ Number leer psi lV 7280.2 800 0.0489 0.0223 1800 0.0304 0.0132 3,500 0.0220 0.0104 2V 7283.2 800 0.0021 0.0008 1800 0.0009 0.0003 8500 0,0005 0.0001 3V 7286.2 800 0.0173 0.0088 1800 0.0087 0.003.5 8500 0.00.54 0.0021 4V 7289,2 800 0.0059 0.0028 1800 0.0029 0.0011 ~500 0.0016 0.0005 5V 7292.2 800 0.0221 0.0117 1800 0.0084 0.0031 8500 0.0052 0.0020 6V 7298.2 800 0.0102 0.0068 1800 0.0057 0.0023 8,500 0,0082 0,0012 7V 7301.2 800 0.0038 0,001,5 1800 0.0017 0.0006 8,500 0.0009 0.0003 8V 7304.2 800 0.0974 0.0532 1800 0.0682 0.0273 8500 0.0500 0.0212 9V 7307,2 800 0.042,5 0.0240 1800 0.0285 0.0101 8500 0.0170 0.0070 IOV 72.10.2 800 0.0044 0.0018 1800 0.0027 0.001 8500 0.0018 0.0006 11V 7313.2 800 0.0307 0.01,52 1800 0.0127 0.0067 8500 0.00,51 0.0019 12V 7316.2 800 0.0t60 0.0075 1800 0.0091 0.0039 8,500 0.0061 0.0024 13V 7319.2 800 0.0761 0.0439 1800 0.0462 0.0194 8500 0.0365 0.0150 14V 7331,2 800 0.0557 0.0421 1800 0.0261 0.0109 8500 0.0184 0.0078 15V 73&,5,2 800 0.0802 0.0147 t800 0.0178 0,0092 ,~500 0.0120 0.0063 RECEIVED MAR I 5 2001 Alaska Oil & Gas Cons. Co~nission Anchorage SUMMARY OF VERTICAL PERMEABILITY A~co AJ~ska, Inc. Fie: DAL-99036 Mellwater Soulh 1 16V 7357.2 800 0.0051 0.0021 1800 0.0020 0.0007 3500 0.0010 0.0008 1 17V 7340.2 800 0.0041 0.0016 1800 0.0017 0.0006 3600 0.0009 0.000~ 1 18V 7842.2 800 0.0018 0.0007 1800 0.OOO7 0.OOO2 8~00 0.0008 0.0001 I 19V 7~46.2 800 0.0S47 0.0285 1800 0.0170 0.0068 ,,',~00 0.0121 0.00~8 1 20V 7~9.2 800 0.0049 0.0027 1800 0.0018 0.0006 ~500 0.0010 0.0008 1 21V 7~,2.2 800 0.00`54 0.0022 1800 0.0080 0.0011 3500 0.0019 0.0007 1 22V 7~.2 800 0.0166 0.007,5 1800 0.0102 0.0044 8~00 0.00,59 0.0028 RECEIVED MAR 1 5 ZOO1 Naska Oil & Gas Cons. Commission Anchorage SUMMARY OF VERTICAL PERMEABIUTY A;co AJasica, Inc. File: DAL-99036 lytel Soulh Cere Deplh,Oved~den, loNr, I Klk~kenberg~ Number leel psi nt~idalcys 23V 735S.2 ~0 0.0033 0.0013 1600 0.0015 0.0005 3500 0.0010 0.0003 24V 7361.2 800 0.0021 0.0007 1800 0.0006 0,0002 25V 7364.2 800 0.0074 0.0032 1800 0.00~6 0.0018 3500 0.0031 0.0012 26V 7367.29 800 O.O0~t 0.0037 1800 0.00~7 0,0019 3500 0.0025 0.0010 27V 7370.2 800 0,0033 0,0013 1800 0.0016 0.0006 3500 0.0010 0.0005 27V 7370.2 800 0,0062 0.0026 1800 0.0019 0.0007 ~500 0.0011 0.0003 2 28V 7373.2 800 0.06~0 0.0373 1800 0.0~65 0.0205 3500 O.C~O0 0.0176 2 29V 7376.2 800 0.0C~2 0.0017 1800 0.0019 0.0007 3500 0.0011 0.0004 2 30V 7379.5 800 0,0090 0.0039 1800 0.0053 0,0021 3500 0,0034 0,0013 2 3tV 7382.2 800 0.0042 0,0017 1800 O,O01g 0.0007 5500 0,0011 0.000~ 2 $2V 7385.2 800 0.0035 0.001-~ 1800 0.0015 0.0005 3500 0.0009 0.0003 2 33V 7389,29 800 0.0037 0.001,5 1800 0.0014 0.0005 3500 0.0007 0.0002 2 34V 7391.2 800 0.002,5 0.0009 1 $00 0.0009 0.0005 3500.00 * * * Samples to light lot Pem'~abllily Measuremenls RECEIVED MAR Alaska Oil & Gas Cons. Commission Anchorage SUMMARY OF VERTICAL PERMEABILITY C,~'e Del)Ih, Overburden, !o Alr~ JK]nkenl~rJj~ Number ieel psi lV 7280.2 800 0.0489 0.0228 1800 0.0804 0.0182 3500 0,0220 0,0104 2V 7283.2 800 0.0021 0.0008 1800 0.0009 0.000~ 3500 0.0005 0.0001 8V 7286.2 800 0.0178 0.0088 1800 0.0087 0.0035 350(] 0.0054 0.0021 4V 7289.2 800 0.0059 0.0028 1800 0.0029 0.0011 3500 0.0016 0.0005 6V 7292.2 800 0.0221 0.0117 1800 0.0084 0.0081 8500 0.0052 0.0020 6V 7298.2 800 0.0102 0.0068 1800 0.0057 0.0028 3500 0.0082 0.0012 7V 7801.2 800 0.0088 0.001-5 1800 0.0017 0.0006 3500 0,0009 0.0008 8V 7804.2 800 0.0974 0.0,532 1800 0.0652 0.0278 8~00 0.0500 0.0212 1 9V 7807.2 800 0.042-5 0.0240 1800 0.0235 0.0101 3500 0.0170 0.0070 1 10V 7810.2 800 0.0044 0.0018 1800 0.0027 0.001 3500 0.0018 0.0006 1 1 lV 7818.2 800 0.0807 0.01-52 1800 0.0127 0.0067 3500 0.0051 0.0019 1 12V 7816.2 800 0.0160 0.007-5 1800 0.0091 0.0089 8500 0.0061 0.0024 1 15V 7819.2 800 0.0761 0.0439 1800 0.0462 0.0194 3500 0.0565 0.01-50 1 14V 7881.2 800 0.0557 0.0421 1800 0.0261 0.0109 3500 0.0184 0.0078 1 1-5V 7835.2 800 0.0802 0.0147 1800 0.0178 0.0092 3500 0.0120 0.0068 RECEIVED MAR I 5 ZOO1 Alaska Oit & Gas Cons. Commission Anchorage SUMMARY OF VERTICAL PERMEABILITY C,(xe Depth,Overburden,to AIr~ Kinkenberg 16V 7`337.2 800 0.0051 0.0021 1800 0.0020 0.0007 ~ 0.0010 0.0003 17V 7540.2 800 0.0041 0.0016 1800 0.0017 0.0006 3,500 0.0009 0.0003 18V 7342.2 800 0.0018 0.0007 1800 0.0007 0.0002 8600 0.0008 0.0001 19V 7846.2 800 0.0547 0.0233 1800 0.0170 0.0068 8,500 0.0121 0.00,38 20V 7849.2 800 0.0049 0.0027 1800 0.0018 0.0006 8500 0.0010 0.000,3 21V 7352.2 800 0.0054 0.0022 1800 0.00,30 0.0011 3500 0.0019 0.0007 22V 73,5,5.2800 0.0166 0.0075 1800 0.0102 0.0044 3500 0.00,59 0.0028 RECEIVED MAR i 5 ?_001 Alaska Oil 8, Gas Cons. Commission Anchorage SUMMARY OF VERTICAL PERMEABILITY 1800 0.0016 0.0005 3~00 0,0010 0.~ 24V 7~1,2 ~ 0,~21 0,~7 I8~ 0.~6 0.~2 25V 7364,2 800 0.0074 0,0032 1800 0.0046 0.0018 8600 0.0031 0,0012 26V 7367.29 800 0.0084 0.0037 1800 0.0047 0,0019 3600 0.0028 0.0010 27V 7370.2 800 0.0033 0.0013 1800 0.0016 0.0006 5500 0,0010 0.0003 27V 7370.2 800 0.0062 0,0026 1800 0,0019 0.0007 8600 0,0011 0,0008 2 28V 7873.2 800 0.0640 0.0873 1800 0.0465 0,0208 3600 0.0400 0.0176 2 29V 7876,2 800 0.0042 0.0017 1800 0.0019 0.0007 ,%500 0.0011 0,0004 2 80V 7879,6 800 0.0090 0,0089 1800 0.0058 0,0021 3,500 0,0084 0,0018 2 81V 7882,2 800 0,00~2 0,0017 1800 0,0019 0.0007 ~600 0.00t 1 0,0004 2 82V 7385.2 800 0.0035 0,0014 1800 0.0018 0.0005 ~00 0,0009 0.0003 2 33V 7389.29 800 0,0087 0,0016 1800 0,0014 3,500 0.0007 0.0002 2 34V 7391.2 800 0.0026 0.0009 1800 0,000~ 0,0008 3500,00 , , Samples Io llghl Io,- Permeability Measurements RECEIVED MAR i 5 2001 Alaska Oil & Gas Cons. Commission Anchorage Arco Alaska, Inc. Meltwater South Sample Number Sample Depth, meters Dean Stark Water Out, CC O1-1 C1-2 Cl-3 C1-4 C1-5 O1-6 C1-7 C1-8 Cl-9 C1-10 C1-11 C1-12 C1-13 C1-14 C1-15 C1-16 C1-17 C1-18 C1-19 Cl-20 Cl-21 Cl -22 Cl-23 C1-24 C1-25 Cl-26 Cl-27 C1-28 C1-29 C1-30 C1'31 C1-32 C1-33 C1-34 C1-35 C1-36 C1-37 C1-38 C1-39 C1-40 C1-41 C1-42 7278.20 7279.14 7280.10 7281.10 7282.10 7283.10 7284.10 7285.10 7286.10 7287.10 7288.10 7289.10 7290.10 7291.10 7292.10 7293.10 7294.10 7295.10 7296.25 7297.10 7298.10 7299.10 7300.10 7301.10 7302.10 7303.10 7304.10 7305.10 7306.10 7307.10 7308.10 7309.10 7310.10 7311.10 7312.10 7313.10 7314.10 7315.10 7316.10 7317.10 7318.10 7319.10 Total Weight Before, ~jrams Thimble Weight ! Thimble Weight Before, I After grams I grams 4.42 188.351 82,284 82,347 5.52 184:185 78.939 78.941 5.39 185.907 80.16 80.158 4.92 188.655 81.891 81.891 4.72 181.331 79.423 79.423 4.54 185.061 78,007 78.005' 4.33 188.357 77.597 77.597 4.54 187.399 79.505 79.505 3.85 187.720 77.465 77.465 4.39 186.569 79.575 79.575 5.59 188.634 83.123 83.013 2.90 189.235 78.020 78.016 5.03 188.303 82.857 82.855 4.71 189.692 83.400 83.400 4.36 189.986 83.339 83.339 4.15 187.340 79.492 79.491 4.14 186.519 7'7.394 77.394 4.43 188.294 78.783 78.777 4.25 183.446 75.768 75.768 4.06 192.103 83.944 83.943 4.25 184.454 77.319 77.328 4.90 187.977 85.054 85.055 4.55 184.001 80.285 80.289 3.91 189.040 79.240 79.239 4.85 185.176 78;996 78,996 4.42 184.989 78,105 78,103 4.70 181.911 78,412 78.403 4.00 187.628 79,865 79.858 4.27 186.940 83,274 83.267 4.52 184.110 78.246 78.245 4.58 182.523 78,295 78.415 4.23 186.940 82.010 82.009 4.15 188.163 77.597 77.597 3.38 189.023 78.669 78.67 4.42 181.217 77.577 77.583 4.44 193.362 84.458 -84.45 1 5.46 183.696 76,763 76.77 4.31 183.382 78,834 78.835 3.96 187.432 79.257 79.259 3.99 181.460 77.978 78,076 4.24 181.662 78.946 78.946 5.03 185.607 78,506 78.506 dry After, s ds water o Weight, grams grams 183,492 0.440 4.859 178,594 0.067 5.591 180.215 0;304 5.692 183.565 O. 173 5.090 176'.161 0.446 5.170 180.21'9 0.299 4.842 183.921 0.104 4.436 182.533 0.327 4.866 183.800 0.066 3.920 181.790 0.389 4.779 183.044 0.001 5.590 186.215 0.118 3.020 183.030 0.241 5.273 184.558 0.421 5.134 185.285 0.340 4.701 182.990 0.196 4.350 182.246 0.129 4.273 183.676 0.185 4.618 179.11'8 0.076 4.328 187.806 0.240 4:297 179.974 0.226 4.480 182.798 0.275 5.179 179.370 0.084 4.631 184.936 0.189 4.104 180.119 0.208 5.057 180.214 0.354 4.775 177.003 0.205 4.908 183.548 0.076 4.080 182.404 0,269 4.536 179.297 0.293 4.813 177.574 0.368 4.949 182.445 0.261 4.495 183.772 0.241 4.391 185.328 0.31.3 3.695 176.560 0.240 4.657 188.819 0.099 4.543 178.209 0.027 5.487 178.758 0.310 4.624 183.212 0.259 4.220 177.414 0.055 4.046 177.143 0.278 4.519 180;245 0.332 5.362 Arco Alaska, Inc. Meltwater South Sample Number Sample Depth, meters Dean Stark Water Out, CC C1-43 C1-44 C1-45 C1-46 Cl-47 C1-48 C1-49 C1-50 C1-51 C1-52 C1-53 C1-54 C1-55 C1-56 C1-57 C1-58 C1-59 C1-60 C1-61 C1-62 C1-63 C1-64 C1-65 C1-66 C1-67 C1-68 C1-69 C1-70 C1-71 C1-72 C1-73 C1-74 O1-75 C1-76 C1-77 CI -78 Ci -79 C! -80 O1-81 Ci -82 C! -83 Ci -84 7320.10 7321.10 7322.10 7323.10 7324.10 7325.10 7326.10 7327.10 7328.10 7329.10 7330.10 7331.10 7332.10 7333.10 7334.10 7335.10 7336.10 7337.10 7338.10 7339.10 7340.10 7341.10 7342.00 7343.00 7344.10 7345.10 7346.10 7347.10 7348.10 7349.10 7350.10 7351.10 7352.10 7353.10 7354.10 7355.10 7356.10 7357.10 7358.10 7358.89 7360.10 7361.20 4.72 3.98 3.97 3.94 4.56 4.12 4.90 4.63 4.09 4.93 4.37 4.10 4.39 5.12 3..85 4.56 3.98 4.80 3.98 4.14 4.10 2.56 3.11 3.90 3.91 3.91 4.37 4.41 4.62 2.42 4.70 3.90 3.14 4.29 4.71 4.82 4.03 5.12 4.12 4.23 3.67 3.74 Total Weight Before, grams 182.129 185.902 190.696 192.878 184.775 188.594 187.278 187.139 185.291 192.408 185.545 183.565 182.7O9 184.199 183.415 188.436 188.434 186.568 188.594 187.783 191.889 155.245 189.923 185.662 187.294 186.665 188.546 185.085 186.332 192.257 184.193 189.429 161.557 184,483 190.906 189.354 185.666 185.005 191.818 190~254 188.254 186.024 dry Thimble Weight I Thimble Weight I Total Weight Before, I After I After, grams I grams I grams 78.237 78.236 177.034 78.654 78.669 ' 181.679 82.355 82.356 186.604 81.740 81.743 188.733 77.992 77.992 180.115 79.186 79.187 184.355 82.011 82.012 182.297 82.458 82.455 182;299 78.677 78.684 181.088 85.073 85.073 187.203 77.558 77.557 180.998 78.269 78.269 179.036 78.569 78.575 178.312 81.667 81.667 179.012' 78.796 78.794 179.202 83.384 83.568 183.601 79.482 79.484 184.218 79.136 79.399 181.600 78. 727 78. 732 184.499 80.122 80.306 183.403 82. 866 83.02 187.505 80.897 80.898 152.594 82.864 82.953 186.625 80.012 80.066 181.540 79.670 79.855 183.215 77.618 77.646 182.532 80.'107 80.126 183.872 78.978 78.17 180.591 78.018 78.053 181.536 80.043 80.076 189.731 77.051 77.22 179.358 78.807 80.934 185.315 78.714 78.769 158.376 77.471 77.472 180.053 81.106 81.201 186.171 80. 788 80.902 184;441 78.538 78.743 181.547 77.356 77.349 179.807 82.151 82.251 187.640 82.496 82.634 186.016 79.395 79.436 184.555 79.1 04 79.125 182.153 J total wt los/ Delta Weight, Is ds water ouJ grams 0.376 0.238 0.123 0.203 0.105 0.116 0.083 0.214 0.115 0.275 0.173 0.432 0.006 0.065 0.366 0.271 0.236 0.170 0.112 0.237 0.280 0.091 0.183 0.220 0.169 0.219 0.305 0.088 0.179 0.109 0.135 0.217 0.045 0.142 0~030 0.092 0.086 0.080 0.057 0.004 0.028 0.133 5.095 4.223 4.092 4.145 4~660 4.239 4.981 4.840 4.203 5.205 4.547 4.529 4.397 5.187 4.213 4.835 4.216 4.968 4.095 4.380 4.384 2.651 3.298 4.122 4:079 4.133 4.674 4.494 4.796 2.526 4.835 4.114 3.181 4.430 4.735 4.913 4.119 5.198 4.178 4.238 3.699 3.871 Arco Alaska, Inc. Meltwater South Sample Number C~ -85 C' -86 C' -87 C1-88 C~ -89 C1-90 C1-91 Cl-92 Cl -93 C2-94 C2-95 C2-96 C2-97 C2-98 C2-99 C2-100 C2-101 C2-102 C2-103 C2-104 C2'105 C2-106 C2-107 C2-108 C2-109 C2-110 C2-111 C2-112 C2-113 C2-114 C2-115 C2-116 C2-117 C2-118 C2-119 C2-120 C2-121 C2-122 C2-123 C2-124 C2-125 C2-126 Sample Depth, meters 7362.10 7363.10 7364.10 7365.10 7366.10 7367.10 7368.10 7369.10 7370.10 7371.10 7372.10 7373.10 7374; 10 7375.10 7376.10 7377.10 7378.29 7379.39 7380.10 7381.20 7382.10 7383.10 7384.20 7385.10 7386.10 7387.29 7388.10 7389.20 7390.20 7391.10 7392.29 7393.10 7394.29 7395.10 7396.10 7397.10 7398.10 7399.10 7400.20 7401.10 7402.10 7403.50 Dean Stark Water OUt, cc 3.85 3.93 4.59 4.57 4.31 4.52 3.91 3.78 2.20 2.03 5.16 4.51 4.14 4.35 4.53 4.50 4.72 5.20 4.37 4.31 4.21 4.47 3.96 3.43 3.72 3.79 4.19 4.09 4.13 3.82 3.67 3.67 3.75 4.04 3.49 3.84 2.45 3.70 3.49 3.83 3.50 4.12 Total Weight Before, ~lrams 190.433 180.642 185.044 187.031 191.117 185.972 187.498 189.657 194.346 194.255 188.114 187.969 190.987 190.604 191.422 193.054 188.459 187.809 196.396 191.704 193.661 197.291 197.303 193.839 188.873 194.626 192.305 190.827 189.360 190.690 196.264' 191.342 197.504 195.877 200.110 189.903 195.128 196.178 188.329 196.470 196.440 195.833 IThimble Weight Before, grams 8'1.776 84.775 80.749 78.396 80.363 78.623 79.247 83.307 80.165 79.288 78.309 77.943 81.518 79.566 80.501 80.718 78.294 77.854 84.876 78.332 82,591 84.998 84.447 81.345 76.565 80.441 80.407 79.264 75.459 77.856 82.'183 78.463 82.452 82.337 85.159 76,807 80.880 81.410 76,156 83,515 81.564 83,374 Thimble. gramsAfterWeight[ 82.125 84,877 80.744 78.384 80.36 78.6 79.276 83,296 80.16 79.288 78,316 77.937 81,542 79.623 80.501 80.718 78.295 77,853 84.861 78.339 82.596 85.002 84.447 81.335 76.632 80.75 80.499 79.269 75.461 77.864 82.183 78.464 82.453 82.337 85.159 76.801 80.883 81.403 76.171 83.513 81.564 83.522 dry Total Weight After, grams 186.482 176.573 180.354 182.269 186.660 181.341 183.562 185.815 192.028 192.077 182.855 183.335 186.810 186.197 186.642 188.420 183,697 1.82.549 192.021 187.325 189.192 192.467 193.320 190.200 185.119 190.619 187.941 186.637 185.199 186.645 192.466 187.580 193.659 191.793 196.570 185.681 192.371 192.150 184.452 192.290 192.828 191.580 total wt los J Delta ! Weight, is ds water ou~ / grams 0.099 0.135 0.096 0.189 0.151 0:111 0.028 0.067 0.120 0.148 0.096 0.128 0.033 0.060 0.248 0.130 0.040 0.061 0.005 0.072 0.263 0.349 0.018 0.209 0.039 0.222 0.178 0.102 0.033 0.229 0.131 0.094 0.092 0.043 0.050 0.383 0.310 0.333 0.386 0.347 0.107 0.129 3.951 4.069 4.690 4.762 4.457 4.631 3.936 3.842 2.318 2.178 5.259 4.634 4.177 4.407 4.780 4.634 4.762 5.260 4~375 4.379 4,469 4.824 3.983 3.639 3.754 4.007 4.364 4.190 4.161 4.045 3.798 3.762 3.845 4.084 3.540 4.222 2.757 4.028 3.877 4.180 3;612 4.253 File: DAL-99036 DS Dry I GVDry Weight,I Weight, grams grams 104.357 104.244 91.696 91.453 99.610 99.274 103.885 103.520 106.300 106.148 102.741 102.462 104.286 104.059 102.519 100.904 111.868 111.592 112.789 112.649 104.539 104.220 105.398 105.111 105.268 105.143 106.574 106.375 106.141 105.935 107.702 107.396 105.402 105.114 104.696 104.414 107.160 106.942 108.986 108.892 106.596 106.353 107.465 107.195 108.873 108.689 108.865 108.624 108.487 1'08.343 109.869 109.583 107.442 107 ~306 107.368 107.167 109.738 109.390 108.781 108.581 110.283 110.134 109.116 108.815 111.206. 111.055 109.456 109.136 111.411 111.1 37 108.880 108.619 111.488 111.217 110.747 110.531 108.281 108.137 108.777 108.468 111.264 111.013 108.058 107.902 IDelta (DS-GV) Weight, ~lrams Pore Volume, CC 0.113 0.243 0.336 0.365 0.152 0.279 0.227 1.615 0.276 0.140 0.319 0.287 0.125 0.199 0.206 0.306 0.288 0.282 0.218 0.094 0.243 0.270 0.184 0.241 0.144 0.286 0.136 0.201 0.348 0.200 0.149 0.301 0.151 0.320 0.274 0.261 0.271 0.216 0.144 0.309 0.251 0.156 4.011 4.572 4.741 4.911 4.719 5.089 4.196 4.878 3.137 2.622 5.966 5.149 4.762 4.789 4.873 4.832 5.080 5.450 4.505 4.733 4.958 5.109 4.167 3.937 4.259 4.420 4.585 4.351 4.466 4.187 4.038 4.109 4.398 4.458 3.889 4.826 3.649 4.276 4.405 4.489 3.933 4.515 Ambient Water Saturation, percent 96.0 85.8 :96.6 92.8 91.1 88.6 92.9 76.2 69.9 77.4 86.3 87.3 86.9 90.6 92.8 92.9 92.7 95.1 96.8 90.9 84.6 87.4 95.0 86.9 87.1 85.4 91.2 93.8 92.1 91.0 90.7 89.0 85.2 90.4 89.5 79.4 66.9 86.3 79.1 85.2 88.9 91.2 Oil Saturation, percent 3.3 3.9 2.8 5.0 4.2 3.0 1.1 1.9 5.0 7.2 2.2 3.3 1.1 1.8 6.6 3.6 1.2 1.6 0.4 2.1 6.8 8.8 0.8 6.9 1.4 6.5 5.1 3.2 1.2 7.1 4.3 3.1 2.8 1.5 1.9 10.'1 10:8 10.0 11.2 9.9 3.6 3.8 Fluid Saturation, percent 99.3 89.7 '99.4 97.8 95.4 91.5 94.0 78.1 74.9 84.6 88.5 90.6 88.0 92.4 99.4 96.6 93.9 96.8 97.2 93.1 91.5 96.1 95.8 93.8 88.5 91.9 96.3 97.0 93.3 98.0 95.0 92.1 88.1 91.8 91.4 89.5 77.7 96.2 90.3 95.0 92.5 95.0 ~yringe Wgt / grams / grams Arco Alaska, Inc. Meltwater South Sample Number Sample Depth, meters Dean Stark I Total Weight Water Out,I Before, cc grams C2-127 C2-128 C2-129 02-130 C2-131 7404.25 7405.10 74O6.10 7407.10 7408.10 4.15 191.218 4.38 196.529 3.89 194.043 3.65 195.856 3.91 195.393 IThimble Weight Before, grams 81.199 82.997 82.763 83.481 81.518 ThimblegramsAfter Weight J 81.199 83.015 -82.767 83.487 81.528 dry Total Weight After, grams 186.626 192.066 189.854 191.900 191. '198 J total, wt los JWeight,Delta rs ds water ol grams 0.440 0.083 0.297 0.306 0.280 4.592 4.463 4.189 3.956 4..195 File: DAL-99036 DS Dry GV Dry Weight, Weight, grams grams 105.427 105.217 109.051 108.821 107.087 106.778 108.413 108.181 109.670 109.402 IDelta (DS-GV)I Weight, I ilmms I 0.210 0.230 0.309 0.232 0.268 Pore Volume, CC Ambient Water I Oil Saturation, Saturation, percent pement / Fluid ! Full / Dry Saturation, ~yringe Wgt~;yringe Wgt percent / grams / grams 4.906 84.5 11.4 95.9 4.552 96.0 2.5 98.6 4.574 84.8 8.3 93.2 4.310 84.5 9.1 93.6 4.502 86.7 8.0 94.7 File: DAL-99036 DS Dry I GVDry Weight,I Weight, grams . grams 98.798 98.436 103.010 102.555 104.248 104.043 106.990 106.596 102.123 101.986 105.168 105.094 100.285 99.947 99.844 99.547 102.404 102.131 102.130 101.853 103.441 103.182 100.767 100.427 99.737 99.529 97.345 96.949 100.408 100.153 100.033 99.812 104.734 104.519 102.201 102.052 105.767 105.550 103.097 102.868 104.485 104.312 71.696 71.533 103.672 1'03.569 101.474 101.308 103.360 103.239 104.886 104.745 103.746 103.509 102.421 102.247 103.483 103.313 109.655 109.354 102.138 101.933 104.381 104.219 79.607 79.413 102.581 102.409 104.970 104.793 103.539 103.227 102.804 102.679 102.458 102.282 105.389 105.144 103.382 103.136 105.119 104.808 103.028 102.858 Delta (DS-GV)I Weight, ~lrams 0.362 0.455 0.205 0.394 0.137 O.O74 0.338 0.297 0.273 0.277 0.259 0.340 0.208 0.396 0.255 0.221 0.215 0.149 0.217 0.229 0.173 0.163 0.103 0.166 0.121 0.141 0.237 0.174 0.170 0.301 0.205 0.162 0.194 0.172 0.177 0.312 0.125 0.176 0.245 0.246 0.311 0.170 Pore Volume, CC 6.282 4.944 5.117 4.31 O7 4.8418 4.399 5.799 6.326 5.672 5.4347 4.8491 6.2669 6.1856 5.8106 6,050 5.996 4.4095 5.4049 4.475 4.509 4.752 2.865 3.577 4.469 5.020 4.305 4.949 4.896 5.572 3.113 5.517 4.405 3.410 4.664 5.050 5.486 4.974 5.503 4.578 '4.516 3.842 4.379 Ambient Water Oil Saturation, Saturation, percent percent 74.9 80.2 77.4 91.1 93.9 93.7 84.2' 72.9 71.9 9O.5 90.0 65.2 70.8 87.8 63.4 76.0 9o.1 88.6 88.8 91.7 86.2 89.1 87.0 87.2 77.8 90.8 88.1 89.8 82.7 77.4 85.0 88.3 91.7 91.8 93.0 87.6 81.0 92.8 89.8 93.5 95.3 85.2 7.7 6.2 3.2 6.1 3.0 3.5 2.0 4.4 2.7 6.6 4.7 8.8 0.3 1.6 7.7 5.8 6.9 4.2 3.4 '6.8 7.6 4.2 6.6 6.4 4.4 6.6 7.9 2.5 4.2. 4.6 3.3 6.4 1.9 4.0 1.0 2.3 2:4 2.1 1.8 0.4 1.2 4.0 Fluid Saturation, percent 82.5 86.5 80.6 97.2 96.9 97.2 86.2 77.3 74.6 97.0 94.7 73.9 71.2 89.4 71.1 81.8 97.0 92.8 92.2 98.5 93.8 93.4 93.6 93.5 82.2 97.4 96.0 92.3 87.0 82.0 88.3 94.7 93.6 95.8 94.0 89.9 83.4 94.9 91.6 93.9 96.4 89.2 ~yringe Wgt grams. )0.877 Dry ~yringe Wgt grams 7,827 File: DAL-99036 DS Dry GV Dry Weight, Weight, grams ~lrams 101.145 100.803 99.653 99.319 100.057 99.701 101.674 101.216 96.738 96.402 102.214 102.006 106.324 106.129 103.028 102.582 106.335 106.127 102.215 101.848 100.031 99.712 108.199 107.985 100.175 99.830 101.1 58 100.869 101.946 101.681 103.499 103.306 104.852 104.635 104.899 104.647 103.350 103.007 103.863 103.531 102.646 102.323 97.743 97.385 99.081 98.773 105.697 105.424 101.123 100.809 102.111 101.908 98.600 98.400 103.690 103.505 99.137 98.739 101.052 100.811 99.159 98.844 100.436 100.195 106.175 105.996 106.658 106.455 98.977 98.633 104.368 104.081 101.439 101.079 99.923 99.652 103.953 103.952 99.338 99.036 98.197 97.764 101.739 101.394 Delta (DS-GV) Weight, grams Ambient Pore Water Oil Volume, Saturation, Saturation, cc percent percent 0.342 0.334 0.356 0.458 0.336 0.208 0.195 0.446 0.208 0.367 0.319 0.214 0.345 0.289 0.265 0.193 0.217 0.252 0.343 0.332 0.323 0.358 0.308 0.273 0.314 0.203 0.200 0.185 0.398 0.241 0.315 0.241 0.179 0.203 0.344 0.287 0.360 0.271 0.001 0.302 0.433 0.345 6.658 66.1 8.4 6.119 90.0 1.6 6.153 87.2 6.4 5.554 88.1 4.1 6.850 68.7 8.3 5.037 90.0. 7.7 4.803 90.0 3.0 5.557 81.3 7.5 4.140 92.9 2.2 5.887 74.3 8.4 6.395 87.1 0.3 3.194 90.7 4.8 6.053 82.9 5.2 6.148 76.4 8.7 5.331 81.6 8.2 4.515 91.8 5.7 4,404 93.9 3.9 4.723 93.6 5.1 4.711 90.0 2.2 4.451 90.9 7.0 4.690 90.4 6.2 6.927 70.5 5.1 6.393 70.9 1.8 4.248 91.9 5.8 5.396 89.6 5.1 5.673 77.8 8.0 6.534 71.8 4.1 4.367 91.5 2.4 6.328 67.2 5.5 5.058 89.1 7.5 6.474 70.5 7.3 5.778 73.1 5.8 4.852 85.4 6.4 4.120 81.9 9.7 6.330 69;5 4.9 4.776 92.8 2.8 6.293 86.5 0.8 6.024 71.4 6.6 5.577 71.0 6.0 6.2723 63.4 1.3 6.6044 63.9 5.4 6.730 74.5 6.3 Fluid Saturation, percent 74.6 91.6 93.6 92.2 77.0 97.7 93.0 88.9 95.2 82.7 87.4 95.5 88.0 85.2 89.8 97.5 97.8 98.8 92.2 97.8 96.7 75.7 72.7 97.7 94.6 85.8 75.9 93.9 72.6 96.6 77.8 78.9 91.8 91.6 74.5 95.6 87.2 78.0 77.0 64.7 69.3 80.'8 - yringe Wgt grams 11.894 10.892 11.652 11.548 11.198 Dry iyringe Wgt grams 7.895 7.793 7.697 8.066 '7.697 Oil Density 0.8 GRAV WATER OUT OBSERV WATER OUT DELTA I FullI Dry WATER ISyringe Wgt.,ISyringe Wgt., OUT .grams I grams Observed Toluene, CC 0.000 4.420 0.001 12.183 3.999 5.759 0.235 9,480 3.099 5.369 - 0.019 9,978 0.000 4.960 0.043 12.531 0.000 4.860 0.136 12.661 0.000 4.620 0.077 12.572 0.000 4.350 0.018 12.012 0.000 4.910 0.371 12.471 0.000 4.130 0.276- 11.624 0.000 4.520 0.130 12.153 3.955 5.605 0.016 9.255 0.000 2.750 - 0.152 10.965 0.000 5.070 0.038 12.774 0.000 4.960 0.247 12.493 0.000 4.620 0.259 12.301 0.000 4.780 0.626 12.149 0.000 4.410 0.266 11.896 0.000 4.750 0.317 12.461 0.000 4.570 0.318 12.167 0.000 4.490 0.433 12.006 0.000 4.620 0.366 12.032 0.000 4.850 - 0.054 12.933 0.000 4.620 0.073 12.534 0.000 4.640 0.725 11.561 0.000 5.000 O. 151 12.792 0.000 4.610 O. 189 12.075 0.000 4.550 - 0.153 12.594 0.000 4.410 0.406 12.006 0.000 4.270 0.003 12.084 0.000 4.620 0.100 12.199 0.000 4.1 O0 - 0.481 12.420 0.000 4.270 0.036 11.822 0.000 4.620 0.470 11.9113 0.000 3.410 0.028 11.321 0.000 4.570 0.153 12.083 0.000 4.660 0.216 12.249 3.482 5.332 - 0.128 9.927 0.000 4.360 0.046 12.142 0.000 3.680 0.281 11.767 0.000 3.850 0.141 11,729 0.000 4.240 0.001 11.976 - 3.501 5.121 0.091 9.286 7.774 7.967 7.701 7.625 7.947 8.039 7.690 7.942 7.778 7.773 7.633 8.069 7.753 7.790 7.950 8.004 7.761 8.038 7.924 7.958 7.787 8.040 7.997 7.655 7.954 7.664 7.901 8.01.1 7.826 7.689 7.849 7.597 7.769 7.946 7.676 7.815 7.961 7.837 7.815 7.747 7.744 7.768 JWater Weight, grams 4.409 5.512 5.376 4.906 4~714 4.533 4.322 4.529 3.846 4.380 5.577 2.896 5.021 4.703 4.351 4.145 4.135 4.423 4.243 4.048 4.245 4.893 4.537 3.906 4.838 4.411 4.693 3.995 4.258 4.510 4.571 4.225 4.141 3.375 4.407 4.434 5.448 4.305 3.952 3.982 4.232 5.019 Calc. Water Vol., cc 4;419 5.524 5.388 4.917 4.724 4.543 4.332 4.539 3.854 4.390 5.589 2.902 5.032 4.713 4.361 4.154 4.144 4.433 4.252 4.057 4.254 4.904 4.547 3.915 4.849 4.421 4.703 4.004 4.267 4.52O 4.581 4.234 4:150 3.382 4.417 4.444 5.460 4.314 3~961 3.991 4.241 5.030 JInitial.'Flask J and Toluene Weight, grams Oil Density 0.8 Initial Flask GRAV OBSERV DELTA Full Dry Observed' Water Calc. - and Toluene · WATER WATER' WATER Syringe Wgt., Syringe Wgt., Toluene, Weight, Water Vol., Weight, · OUT OUT OUT grams grams cc grams cc grams 0.000 4.960 0.241 12,457 7.748 4.709 4.719 0.000 4.220 0.235 11,664 7.688 3.976 3.985 0.000 3.860 - 0.109 11.862 7.902 3.960 3.969 0.000 4.210 0.268 11,61 5 7,682 3.933 3.942 0.000 4.650 0.095 12,298 7,753 4,545 4:555 0.000 4.410 0.287 12.002 7.888 4.114 4.123 0.000 5.020 0.122 12,739 7,852 4.887 4.898 0.000 4.920 0.294 12.304 7,688 4.616 4.626 0.000 4.300 0.212 11.795 7.716 4.079 4.088 0.000 4.750 - 0.180 12,663 7,744 4.919 4.930 0.000 4.490 0.116 12.179 7,815 4.364 4.374 0.000 4.120 0.023 11..938 7.850 4.088 4.097 0.000 3.710 - 0.681 12,100 7.719 4.381 4.391 0.000 4.780 - 0.342 12.860 7.749 5.111 5.1.22 0.000 3.600 - 0.247 11,670 7.831 3.839 3.847 0.000 4.870 0.306 12.251 7.697 4.554 4.564 0.000 4.410 0.430 11.841 7.870 3.971 3.980 3.050 5.130 0.332 9.522 7.785 4.7-87 4.798 0.000 4.240 0.257 11,903 7.929 3,974 3.983 0.000 4.260 0.117 11.936 7,802 4.134 4.143 0.000 4.240 0.136 11.868 7.773 4.095 4.104 0.000 2.800 0.240 10.327 7.773 2.554 2.560 0.000 3.350 0.235 10.916. 7.808 3.108 3.115 0.000 4.030 0.128 11.818 7.925 3.893 3.902 0.000 3.870 - 0.040 11,915 8.014 3.901 3.910 0.000 4.190 0.276 11.576 7,671 3.905 3.914 0.000 4.480 0.111 12,084 7,725 4.359 4.369 0.000 4.640 0.234 12.183 7.787 4.396 4.406 0.000 4.630 0.013 12.343 7.736 4.607 4.617 0.000 2.420 0,003 10.212 7.800 2.412 2.417 0.000 4.620 - 0.080 12.445 7.755 4.690 4.700 0.000 3.970 0,073 '11.638 7.750 3.888 3.897 0,000 3.350 0.214 11.006 7.877 3.129 3.136 0.000 4.350 0.062 12,009 7.730 4.279 4.288 0.000 4.490 0.215 12.654 7.959 4.695 4.705 0.000 4.730 0.091 12,665 7.855 4.810 4.821 0.000 3.810 - 0.223 11.785 7.761 4.024 4.033 0.000 4.880 - 0.238 13.124 8.017 5.107 5.118 0.000 4.030 0.091 11.839 7.727 4.112 4.121 0.000 4.010 0.224 12.053 7.828 4.225 -4.234 0.000 3.360 - 0.311 11.316 7.653 3.663 3.671 0.000 3.350 - 0.388 11.441 7,711 3.730 3.738 Oil Density 0.8 Initial Flask GRAV OBSERV DELTA Full Dry Observed Water Calc. 'and Toluene WATER WATER WATER Syringe Wgt., Syringe Wgt., Toluene, Weight, Water Vol., Weight, OUT OUT OUT grams grams cc gramS cc grams 0.000 3.600 0.252 11.545 7.701 0.000 3.570 0.364 11.672 7.747 0.000 4.340 -0.254 12.403 7.819 0.000 4.530 -0.043 12.342 7.779 0.000 4.260 -0.046 12.093 7.796 0.000 4.450 0.070 12.250 7.740 0.000 3.750 -0.158 11.618 7.719 0.000 3.680 0.095 11.619 7.852 0.000 2.240 0.042 9.942 7.749 0.000 2.130 0.100 9.937 7.911 0.000 5.030 -0.133 12,943 7.791 0.000 4.370 -0.136 12,286 7.790 0.000 3.950 -0.194 11.933 7.798 0.000 4.810 0.463 12.047 7.710 0.000 4.650 0.118 12.263 7.741 0.000 4.470 -0.034 12.295 7.801 0.000 4.620 -0.102 12.634 7.922 0.000 5.020 -0.179 12.992 7.804 0.000 4.180 -0.190 12.198 7.838 0.000 4.500 0.193 12.124 7.826 0.000 4.660 0.454 12.022 7.825 0.000 4.560 0.085 12.320 7.855 0.000 4.100 0.135 11.702 7.746 0.000 3.730 0.300 11.220 7. 798 0.000 3.630 -0.085 11.425 7.718 0.000 3.770 -0.015 11.627 7.850 0.000 3.980 0.206 11.924 7.747 0.000 3.920 -0.168 11.960 7.881 0.000 4.110 -0.018 11.869 7.750 0.000 3.730 0.086 11,696' 7.888 0.000 3.000 -0.667 11.366 7.707 0.000 3.710 0.042 8.544 4.884 O. 000 4,000 O. 247 8.652 4.907 0.000 4.220 0.179 8.896 4,864 0.000 3.320 -0.170 8.343 4.861 0.000 4,010 0.171 8.703 4.872 0.000 2.560 0.113 7.319 4.877 0.000 3.700 0.005 8.599 · 4,912 0.000 3.550 0.059 8.383 4.900 0.000 3.890 0.057 8.730 4.905 0.000 3.400 -0.105 8.380 4.883 0.000 3.870 -0.254 9.023 4.908 3.844 3.925 4.584 4.563 4.297 4.510 3.899 3.767 2.193 2.026 5.152 4.496 4.135 4.337 4.522 4.494 4.712 5.188 4.360 4.298 4.197 4.465 3.956 3.422 3.707 3.777 4.177 4.079 4.119 3.808 3.659 3.660 3.745 4.032 3.482 3.831 2.442 3.687 3.483 '3.825 3.497 4.115 3.852 3.934 4.594 4.573 4.306. 4.520 3.908 3~775 2.198 2.030 5.163 4.506 4.144 4.347 4.532 4.504 4.722 5.199 4.370 4.307 4.206 .4.475 3.965 3.430 3.715 3.785 4.186 4.088 4.128 3.816 3.667 3.668 3.753 4.041 3.490 3.839 2.447 3.695 3.491 3.833. 3.505 4.124 Oil Density 0.8 GRAV WATER OUT OBSERV WATER OUT DELTA WATER OUT 0.000 0.000 0.000 0.000 0.000 4.040 4.020 4.080 3.440 3.960 Dry Full I Syringe Wgt.,I Syringe Wgt.,I · grams I grams I 0.112 9.015 4.872 0.360 9.264 4.894 0.188 8.760 4.877 0.210 8.504 4.862 0.045 8.811 4.905 Observed Toluene, CC Water Weight, grams 4.143 4.370 3.883 3.642 3.906 Calc. Water Vol., CC 4.152 4.380 3.892 3.650. 3.915 Initial Flask and Toluene Weight, grams Flask nd Toluen Weight, grams I Flask Weight, grams 0.9978 Toluene Tracer Analyses, ppm Wti Wto Wo 0.00 0.00 0.45 0.00 0.00 0.08 0.00 0.00 0.32 0.00 0.00 0.18 0.00 0.00 0.46 0.00 0.00 0.31 0,00 O. O0 O. 11 0.00 0.00 0.34 0.00 0.00 0.07 0.00 0.00 0.40 0.00 0.00 0.01 0.00 0.00 0.12 0.00 0.00 0.25 0.00 0.00 0.43 0.00 0.00 0.35 0.00 0.00 0.20 0.00 0.00 0.14 0.00 0.00 0.20 0.00 0.00 0.09 0.00 0.00 0.25 0.00 0.00 0.24 0.00 0.00 0.29 0.00 0.00 0.09 0.00 0.00 0.20 0.00. 0.00 0.22 0.00 0.00 0.36 0.00 0.00 0.22 0.00 0.00 0.08 0.00 0.00 0.28 0.00 0.00 0.30 0.00 0~00 0.38 0.00 0.00 0.27 0.00 0.00 0.25 0.00 0.00 0.32 0.00 0.00 0.25 0.00 0.00' 0.11 0,00 0.00 0.04 0.00 0.00 0.32 0.00 0.00 0.27 0.00 0.00 0.06 0.00 0.00 0.29 0.00 0.00 0.34 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.'0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 Sol #REF! #REF~ #REFI #REF! #REF! #REFI #REFI #REF! #REFI #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REFI #REFI #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF~ #REF~ #REF! #REF! Flask nd Toluen Weight, grams Flask Weight, grams 0.9978 Toluene Tracer Analyses, ppm Wti Wto Wo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.39 0.00 0.25 0.00 0.13 0.00 0.21 0.00 0.11 0.00 0.13 0.00 0.09 0.00 0.22 0.00 0.12 0.00 0.29 0.00 0.18 0.00 0.44 0.00 0.02 0.00 0.08 0.00 0.37 0.00 0.28 0.00 0.25 0.00 0.18 0.00 0.12 0.00 0.25 0.00 0.29 0.00 0.10 0.00 0.19 0.00 0.23 0.00 0.18 0.00 0.23 0;00 0.31 0.00 0.10 0.00 0.19 0.00 0.11 0.00 0.14 0.00 0.23 0.00 0.05 0.00 0.15 0.00 0.04 0.00 0.10 0.00 0.09 0.00 0.09 0.00 0.07 0.00 0.01 0.00 0.04 0.00 0.14 0.0000 0.0000. 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0,0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 Sol #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REFI #REF! #REFI #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REFI #REFI #REF! #REF! #REF! #REFI #REFI #REF! #REF! #REF! #REFI Flask nd Toluen Weight, grams Flask Weight, ~lrams 0.9978 Toluene Tracer Analyses, ppm. VVti 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0~00 0.00 0.00 0.00 0.00 0.00 Wto 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Wo 0.11 0.14 0.11 0.20 0.16 0.12 0.04 0.07 0.13 0.15 0.11 0.14 0.04 0.07 0.26 0.14 0.05 0.07 0.01 0.08 0.27 0.36 0.03 0.22 0.05 0.23 0.19 0.11 0.04 0.24 0.14 0.10 0.10 0.05 0.06 0.39 0.31 0.34 0.39 0.36 0.11 0.14 0.0000 0~0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000- 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 Sof #REF! #REF! #REF! #REF! #REF! #REF! #REFI #REF! #REF! #REF! #REF! #REF! #REFI #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REFI. #REF! #REF! #REF! #REF! #REF! #REF! #REF! Flask nd Toluen Weight, grams Flask Weight, grams 0.9978 Toluene Tracer Analyses, ppm Wti Wto Wo Sol 0.00 0.00 0.45 0.00 0.00 0.09 0~00 0.00 0.31 0.00 0.00 0.31 0.00 0.00 0.29 0.0000 0.0000 0.0000 0.0000 0.0000 #REF! #REF! #REF! #REF! #REF! Mud Values Core 1 Core 2 Top Bottom Top Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Filtrate Tracer Analyses, ppm 93 93 96 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom BOttom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom BottOm Filtrate Tracer Analyses, ppm 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 .87 87 Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom BOttom- Bottom Bottom Bottom Bottom Bottom' Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom 'Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom Bottom BOttom Bottom Bottom Filtrate Tracer Analyses, . ppm 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 87 BolIom BoIIom Bollom BolIom Bollom FiltrateI Tracer Analyses, ppm 87 87 87 87 87 Average Filtrate Tracer Analyses, ppm 93 92 Average Filtrate Tracer Analyses, ppm Average Filtrate Tracer Analyses, ppm Average Filtrate Tracer Analyses, ppm Arco Alaska, Inc. Meltwater South File: DAL-99036 Sample Number Sample Depth, feet C1-1 C1-2 C1-3 C1-4 C1-5 C1-6 C1-7 C1-8 C1-9 C1-10 C1-11 C1-12 C1-13 C1-14 C1-15 C1-16 C1-17 C1-18 C1-19 C1-20 C1-21 C1-22 C1-23 C1-24 C1-25 C1-26 C1-27 C1-28 C1-29 C1-30 C1-31 C1-32 C 1-33 C1-34 C 1-35 C1-36 C1-37 Cl-38 Cl-39 C1-40 7278.20 7279.14 7280.10 7281.10 7282.10 7283.10 7284.10 7285.10 7286.10 7287.10 7288,10 7289.10 729O. 10 7291.10 7292,10 7293.10 7294.10 7295.10 7296.25 7297,10 7298,10 7299.10 7300.10 7301.10 7302,10 7303,10 7304,10 7305.10 7306.10 7307.10 7308.10 7309.10 7310.10 7311.10 7312.10 7313.10 7314.10 7315.10 7316.10 7317.10 Dry Weight, gm 100.803 99.319 99.701 101.216 96.402 102.006 106.129 102.582 106.127 101.848 99.712 107.985 99.83 100.869 101.681 103.306 104.635 104.647 103.007 103.531 102.323 97.385 98.773 105.424 100.809 101.908 98.4 103.505 98.739 100.811 98.8,4,4 '100.195 105.996 106.455 98.633 104.081 101.079 99.652 103.952 99.036 Grain Volume, CC 36.9969 36.8087 36.8601 37.2442 35.5253 38.1456 38.8328 37.6033 38.9719 37;6934 36.832 39.9664 36.9427 37.1742 37.5648 38.2649 38.3999 38.5547 37.9741 38.2432 38.1424 36.1269 36.5918 38.9742 37.6131 37.8127 36.561 38.1775 36.7281 37.6514 36.5081 37.2279 38.4384 39.3811 36.4695 38.6606 37.2333 36.9378 38.3166 36.8032 Grain Density, gm/cc 2.725 2.698 2.705 2.718 2.714 2.674 2:733 2.728 2.723 2..702 2.70.7 2.702 2.702 2.713' 2.707 2.700 2.725 2.714 2.713 2.707 2.683 2.696 2.699 2.705 2.680 2.695 2,691 2.711 2.688 2.677 2.707 2.691 2.758 2.703 2.705 2.692 2.715 2.698 2.713 2.691 Length, cm 3.911 3.85 3.862 3.851 3.793 3.868 3.936 3.858 3.873 3.902 3.867 3.851 3.851 3.878 3.834 3.851 3.847 3.899 3.847 3.838 3.84 3.844 3.841 3.887 3.843 3.857 3.825 3.845 3.854 3,828 3.909 3.839 3.854 3.854 3.827 3.892 3.868 3.842 3.869 3.828 Diameter, cm . Area, cm2 3.767 11.145 3,761 11.110 3.762 11.115 3.766 11.139 3,771 11.169 3.761 11.110 3,762 11.115 3.765 11.133 3.765 11.133 3.77 11.163 3.769 11.157 3,768 11.151 3,77 11.163 3.77 11.163 3.768 11.151 3,746 11.021 3,757 11 .O86 3.763 11.121 3.76 11.104 3,766 11.139 3.761 11.110 3.769 11.157 3.768 11.151 3;761 11.11 0 3,767 11.145 3.783 11.24O 3.783 11.24O 3.76 11.104 3,771 11.169 3.764 11.127 3.72 10.869 3.769 11.157 3,779 11.21 6 3.784 11.246 3.769 11.157 3,762 11.115 3.782 11.234 3,771 11.169 3.785 11.252 3.772 11.175 Core Laboratories Arco Alaska, Inc. Meltwater South File: DAL-99036 Sample Number C1-41 C1-42 C1-43 C1-44 C1-45 C1-46 C1-47 C1-48 C1-49 C1-50 C1-51 C1-52 C1-53 C1-54 C1-55 C1-56 C1-57 C1-58 C1-59 C1-60 C1-61 C1-62 C1-63 C1-64 C1-65 C1-66 C1-67 C1-68 C1-69 C1-70 C1-71 Sample Depth, feet 7318.10 7319.10 7320,10 7321,10 7322,10 7323.10 7324,10 7325.10 7326.10 7327.10 7328.10 7329.10 7330.10 7331.10 7332.10 7333.10 7334.10 7335.10 7336.10 7337.10 7338.10 7339.10 7340.10 7341.10 7342.00 7343,00 7344,10 7345,10 7346.10 7347.10 7348.10 Dry Weight, gm 97.764 101,394 98.436 102.555 104.043 106.596 101.986 105.094 99.947 99.547 102.131 101.853 103.182 100.427 99.529 96.949 100.153 99.812 104.519 102.052 105.55 102.868 104.312 71.533 103.569 101.308 103.239 1 04.745 103.509 102.247 103.313 Grain Volume, CC 3&2814 37.2374 36.3914 37.8631 38,1731 39.1374 38,0062 38,6647~ 37,3047 36,8891 37.7376 37.8038 38.031 37.2603 36.908 36.3517 37.1543 36.8958 38.377 37.5906 38.8803 37.8203 38.3213 26,3368 38.0853 37.6843 38,0502 38.7508 38.1202 37,5815 38,1781 Grain Density, gm/cc 2.695 2.723 2.705 2.709 2.726 2.724 2.683 2.718 2.679 2.699 2.706 2.694 2.713 2.695 2.697 2.667 2.696 2.7O5 2.723 2.715 2.715 2.720 2.722 2.716 2.719 2.688 2.713 2.7O3 2.715 2.721 2.706 Length, ca 3,822 3.922 3.811 3.822 3.856 3.867 3.842 3.839 3.863 3.866 3.876 3.872 3.839 3.89 3.839 3,779 3.847 3.843 3.818 3.865 3.863 3.797 3.848 2.609 3.797 3,776 3.847 3.868 3.873 3.803 3.891 Diameter, cm Area, cm2 3.771 11.169 3.77 11.163 3.769 11.1 57 3.766 11.139 3.771 11.169 3.78 11.222 3.765 11.133 3.779 11.21 6 3,767 11.145 3.753 11 .O62 3.769 11.157 3,763 11.121 3,765 11.133 3.77 11.163 3.771 11.169 3,767 11.145 3,772 11.175 3.767 11.145 3,787 11.264 3.764 11.127 3.774 11.186 3.766 11.139 3.763 11.121 3;767 11.145 3.762 11.115 3.77 11.163 3,767 11.145 3.768 11.151 3,768 11.1 51 3.782 11.234 3.781 11.228 Core Laboratories A~CO Alaska., Illc. Fie: DAL-090~ 14elwaler Soulh ~ '"-'-, I 800~ I ~ I 800p.. I 000~ I 800p, I 800p.~ I 868~ I 1600p., I 1900~ I 1800p~ I tsoop-, t 3500p~ 8500~ I 3500p~ I 3500p~ 1,,.~1 cc 01-1 7278.20 0.0449 0.0985 15.3 6.7 66.1 8.4 74.6 0,035 0.0774 6.4658 0.0267 0.0613 14.5 6.2891 100.803 36.99692.72 01-2 7279.14 0.0331 0.0569 14,3 &l 90.0 t.6 91.6 0.0122 0.0283 5.8398 0.0072 0.0177 13.2 5.6183 99,319 36.80872.70 01-3 7280.10 0.0192 0.0436 t4~ 62 672 6.4 93.6 0.0059 0.0209 5.9043 0.0057 0.0167 13.4 5.7099 99.701 36.86012.70 Cl-4 7281.10 0.1843 0.244 13.0 5.6 88.1 4.1 92~. 0.0367 0.0652 5.2400 0.0095 0.024 1t.9 5.0295 101,216 37.24422.72 01-5 7282.10 0.054 0.1147 1&2 6.6 68.7 8~ 77.0 0.0375 0.0837 6.5976 0.0275 0.0639 152 6.3801 96.402 36.52632.71 01.6 7283.10 0.0185 0.0~49 11,7 5.0 96.0 7.7 07.7 0.0066 0.0159 4.7329 0.0022 0.0078 105 4.4745 102.006 38.14562.67 c1-7 7284.10 21.3 21.8 11,0 4.8 go.o 3.0 93.0 10.3 10.7 4.4601 4.18 4.42 9.8 4.2318 106.129 38.63282.73 G1-8 7285.10 0.0126 0.0277 12.9 5.6 81.3 7.5 88.9 0.0074 0.0145 5.1857 0.003 0.0089 11.5 4.9039 102.582 37.60332.?'3 01-g 7286.10 0.0222 0.0348 9,6 4.1 92.g 2.2 952 0.0041 0,009 3.8331 0.001 0.0029 8.4 3.5770 106,127 38.97192.72 01.10 7287.10 0.0246 0.059 13.5 5.9 74.3 0.4 82.7 0.0197 0.0467' 5.6838 0.0147 0.0359 12.8 5.5194 101.848 37.69342.70 c1-11 7288.10 0.0361 0.0809 14.8 6.4 67.t 0,3 67.4 0.0208 0.0329 6.2108 0.0137 0.0369 14.1 6.0370 99.712 36.832 2.71 c1-12 7289.10 0.007 0.0146 7.4 3,-~ 90.7 4.8 95.5 0.003 0.0071 2.9455 0.0013 0.00~5 6.4 2.7303 107.985 39.96642.70 01.13 7290.10 0.0361 0.076 14.1 6.1 62.9 52 86.0 0.0209 0.0499 5.8460 0.0132 0.0347 13.3 5.6725 99.8336.94272.70 01-14 7291.10 0.0311 0.0698 14.2 6.1 76.4 8.7 85.2 0.0203 0.0502 5.9679 0.0147 0.0378 13.5 5.7967 100,869 37.17422.71 01.15 7292.10 0.0274 0.0559 12.4 5.3 81.6 82 86.8 0.0102 0.0262 5.0627 0.0042 0.0142 11.5 4.8576 101.681 37.56482.71 01.16 7293.10 0.016 0.0304 10.6 4,5 91.8 5.7 97.5 0.004 0.0099 4.2240 0.0016 0.0044 9.4 3.9927 103.306 38.26492.70 01-17 7294.10 0.0179 0.033 10.3 4.4 gG.9 3.g 67.8 0.0054 0.0122 4.0930 0.0019 0.0051 9.2 3.8851 104.635 38.39992.72 01-18 7295.10 0.0399 0.1423 10.9 4.7 93.6 5.1 98.8 0.0408 0.0468 4.3102 0.0106 0.0156 9.6 4.1058 104.647 38.55472.71 C1-19 7296.25 38.9 46.4 11.0 4.7 90.0 2.2 62.2 16.4 18.0 4.3877 4.57 4.83 g.8 4.1111 108.007 87.97412.71 01.20 7297.10 0.0127 0.0274 10.4 4,5 g0.6 7.0 67.8 0.0033 0.0097 4.1913 0,002 0.0053 9.4 3.9726 103.531 38.24322.71 Ot-21 7298,10 0.0458 0.0735 10.9 4.7 60.4 6.2 96.7 0.0388 0.0199 4.3981 0.0023 0.0075 g.9 4.1848 102,323 38.14242.68 01-22 7299.10 0.0876 0.1547 16.1 6.g 70.5 5.1 75.7 0.0751 0.1307 6.7032 0.0629 0.1101 15.3 6.5162 97.385 36.12692.70 OI-23 7800.10 0.0874 0.0824 14.9 6.4 70.6 1.6 72.7 0.0266 0.0625 6.2128 0.0205 0.0494 14.2 6.0450 98.773 36.59182.70 (~1.24 7301.10 0.0065 0.0137 6.8 4.2 91.9 5.8 67.7 0.0022 0.0054 3.9697 0.0008 0.0023 8.8 3.6880 105.424 38.97422.70 O1-?.5 7302.10 0.0174 0.0358 t2.5 5.4 69.6 5.1 94.6 0.0065 0.0183 12.0 5.1805 0.0054 0,0134 11.6 4.9240 100.809 87.61312.68 C1.26 7308.10 0.0292 0.0585 13.0 5.7 77.8 8.0 85.8 0.0133 0.0359 12.7 6.4863 0.0142 0.03 12,3 5.3197 101.908 37.81272.70 C1-27 7304.10 0.0935 0.1668 t5.2 8.5 71.8 4.1 75.9 0.0574 0.1122 14.7 6.3124 0.0414 0.0844 14.4 6.1383 98.4 36.56t 2.6~ 01-28 7305.t0 0.0196 0.0389 10.3 4.4 91.5 2.4 93.9 0.0077 0.0169 9.8 4.1678 0.002 0.007 g.5 4.0002 103.505 38.17752.71 Ct.29 7306,10 0.0662 0.1262 14.7 6.3 67.2 5,5 72.6 0.0537 0.1037 14.3 6.1857 0.0458 0.0878 14.0 5.9762 98.739 36.72812.89 OI.30 7807.10 0.0159 0.0339 11.8 5.1 89.1 7.5 96.6 0.0058 0.0171 11.3 4.7878 0.0381 0.0104 10.9 4.5831 100.811 37.65142.6~ 01-31 7808.10 0.039 0.0759 t5.1 6.5 70.5 7.3 77.8 0.0172 0.0449 14.8 6.2448 0.0127 0.0844 14.2 6.0496 98.844 36.50812.71 O1-32 7309.10 0.0357 0.077 13.4 5.8 7'3.1 5.8 78.9 0.0254 0.0578 13.1 6.6061 0.0185 0.0446 12.8 5.4514 100.195 87.22792.6~ Ot-33 7310.10 0.0024 0.0059 11.2 4.g 85.4 6.4 91.8 0.0028 0.0066 10.8 4.5795 0.0017 0.0043 10.3 4.4145 105.996 38.43842.78 C1-34 7311.10 0.0162 0.0318 9.5 4.1 81.g g.7 91.6 0.0035 0.0122 g.0 3.9103 0.0026 0.0082 8.7 3.7509 106,455 39.38112.70 G1-35 7812.10 0.0641 0.1232 14.8 0.3 68,5 4.9 74.5 0.0529 0.1025 14.4 6.1267 0.0441 0.0869 14.1 6.9689 98.633 36.46952.70 O1-38 7313110 0.0128 0.0272 11.0 4.8 92.8 2.8 05.$ 0.0036 0.0128 10.4 4.4936 0.0326 0.0066 10.0 4.2739 104.081 38.66062.69 O1-37 7314.10 0.0279 0.059 14.5 8.3 86.5 6.0 87.2 0.0114 0.0328 14.0 6.0324 0.0072 0.0232 13.6 6.8580 101.079 37.23882.71 014.'.'.'~ 7316.10 0.0408 0.039 14.0 6.0 71.4 6.6 78.0 0.0299 0.0668 13.6 6.8328 0.0226 0.0525 13.3 5.6702 99.652 36.93782.70 01-39 7316.10 0,021 0.0476 12.7 5.6 71.0 6.0 ?7.0 0.0157 0.0374 12.1 6.2598 0.0123 0.0302 11.6 8.0445 108.952 38.31662.71 01-40 7317.10 0.0493 0.1 14.6 6.3 63.4 1,3 64.7 .0.0401 0.0821 14.1 6.0191 0.033 0,0688 13.6 5m8~8 99.036 36.80322.69 O1'41 7318.10 0.0966 0.1747 15.4 6.6 63.g 5.4 68.3 0.0732 0.1364 14.g 6.3763 0.0574 0.1094 14.6 6.1966 97,764 86.28142.68 01'42 7319.10 0.0274 0.0642 15.3 6.7 74,5 0,3 80.8 0.0192 0.0~89 14.9 6.5251 0.0148 0.039 14.5 6.3402 101.394 37.23742.72 01'43 7320.10 0.0332 0.0739 14.7 6,3 74.g 7.7 82.5 0.0211 0.0524 14,3 6.0700 0.0152 0.0393 13.9 5.8898 98.436 36.39142.70 01-44 7321.t0 1.37 1.38 11.6 4.9 80.2 0.2 86.5 0.3759 0.3824 11.0 4.6589 0.0426 0.0826 10.5 4.4640 102.,,~55 37.86312.71 O1-45 7822.10 0.0182 0.034 11.8 5.1 77.4 3.2 80.6 0.0065 0.0181 11,3 4.8728 0.0055 0.014 10.9 4.6935 104.043 38.17312.73 OI-46 7323,10 0.7164 0.885 g.6 4.3 gt.1 6.1 97.2 0.2686 0.388,5 9.4 4.0408 0.0507 0.0931 g.0 3.8832 t06.596 39.13742.72 01-47 7324.10 0.0311 0.0499 11.3 4.8 93.9 3.0 g6.g 0.008 0.0182 10.7 4.8700 0.003 0.0083 10.3 4.3780 101.986 38.00622.68 CI-48 7325.10 0.0403 0.0488 10.2 4.4 93.7 3.5 97.2 0.0378 0.0128 9.6 4.1029 0.0018 0.0038 g.1 3.8518 105.094 38.66472.72 OI-49 7326.10 0.0266 0.0315 13.5 5.8 84.2 2.0 86.2 0.0139 0.0806 12.g 6.6262 0.0138 0.0287 12.4 6.3027 99.947 37.30472.68 01-50 7327. t0 0.0345 0.0789 14.6 6.3 72.g 4.4 77.3 0.0228 0.0546 14.2 6.0967 0.015 0.039 13.8 5.8951 99.547 36.88912.70 01.51 7828.10 0.0324 0.057 13.1 5.7 7t.9 2.7 74.6 0.0124 0.0338 12.7 6.4747 0.0122 0.0277 12,3 5.3097 102.131 37.73762.71 C1-52 7329.10 0.0131 0.0292 12.6 5.4 90.5 6.6 97.0 0.0059 0.0142 12.0 5.1429 0.0017 0.0068 tl.5 4.8915 101.853 37.80382.68 01.53 7380.10 0.0115 0.0205 11,3 4.8 90.0 4.7 94.7 0.003 0.0102 10.7 4.5624 0.0322 0.0036 10.2 4.3389 103.182 38.031 2.71 C1-54 7331.10 0.0361 0.0814 14.4 6,3 65.2 8.8 ?3.9 0.0264 0.0614 14.0 6;0433 0.0194 0.0466 13.6 5.8525 100.427 37.26032.70 01-55 7332.10 0.0662 0.1274 14.4 6.2 70.8 0.3 7t.2 0.0526 0.1047 1:3.9 5.9667 0.0445 0.088 13.6 5.7878 99.529 86.908 2.70 C1-56 7333110 0.0247 0.0522 13.8 5.8 87.8 t.6 89.4 0.0103 0.0300 13.3 5.6769 0.0064 0.0202 12.9 5.3824 96,949 36:35172.67 C1.57 7334.10 0.0678 0.1315 ' 14.0 6.1 63.4 7.7 7t.1 0.0351 0.1089 13.6 5.0456 0.0446 0.09 13.3 5.6766 100.153 37.15432.70 Ct-58 7335.10 0.0278 0.0364 14.0. 6.0 76.0 5.8 81.8 0.0137 0.0335 13.5 6.7794 0.0077 0.0216 1:3.2 5.6982 99.812 36.89582.71 C1-59 7336.10 0.8107 0.8412 10.3 4.4 90.1 6.9 97.0 0.231 0.2473 9.7 4.1438 0.0274 0.0564 9.4 3.9698 104.519 88.877 2.72 01-~0 7337.10 0.0089 0.0192 12.6 5.4 88.6 4.2 92.8 0.003 0.008 12.0 5.1082 0.0019 0.0049 11.4 4.8487 102.052 37.59062.71 G1-61 7338.10 0.0056 0.0116 10,,~ 4.5 88.8 3.4 62.2 0.0028 0,0054 9.8 4.222,5 0.0008 0.0024 9,9 3.9765 105.55 38.88032.71 Gl-GE 7339.10 0.0095 0.0166 10.7 4.5 91.7 6.8 g8.5 0.0024 0.0052 g.g 4.1760 0.0006 0.002 g.2 3.8111 102.868 37.82032.72 GI-G~, 7340.10 0.0193, 0.038,5 11.0 4.8 86.2 7.6 g~.6 0.00,48 0,011a 10.9 4.4216 0.0013 0.0037 0.8 4.1,517104.312 38.32132.72 G1.64 7341.10 0.013 0.0223 0.8 2.6 89.1 4.2 g~.4 0.0027 0.0065 9.1 2.6508 0.0008 0.0024 8.7 2.4939 71.,.r~ 26.33682.72 Gl*.e6 7~42.00 84.8 90.6 8.6 9.6 87.0 6.6 g~.6 11.9 13.2 8.0 3.3293 0.872,5 1.11 7.7 3.17,56103.,569 38.08~ 2.72 G1.-66 7343.00 0.02,55 0.0484 10.6 4.5 87.2 6.4 g~.5 0,0088 0.0145 0.9 4.1506 0.0037 0.00~8 g.4 3.9097 101.308 37.6843, 2.6g Fie: DAL-gg036 G1-67 7344.10 ' 0.0076 0.0205 tl.7 5.0 77.8 4;4 82.2 0.0054 0.0146 11.0 4.7239 0.004 0.0109 10.6 4.5210 103.239 38.05022.71 61-68 7345. t0 0.1909 0.2089 16.0 4.3 g0.8 6.6 97.4 0.0302 0.0397 9.2 3.9371 0.0041 0.0076 8.7 3.6998 104.745 38.75082.70 7346.10 0.011 0.0263 4.9 88.1 7.g 06.0 0.007 0.0166 1t.t 4.7594 0.0033 0.0105 10.7 4.5876 103.509 38.12022.72 G1-69 tt.5 C1-70 7347.10 0.0143 0.0532 11.5 4.9 89.8 2.5 92.3 0.005 0.0152 11.0 4.6672 0.0029 0.0091 10.7 4.4869 102.247 37.58152.72 61-71 7348.10 0.0406 0.0736 12.7 5.6 82.7 4.2 87.0 0.0138 0.0332 12.2 5.3130 0.009 0.0214 11.g 5.1360 103.313 38.17812.71 61.72 7349.10 0.0152 0.0008 7.2 3.1 77.4 4.8 82.0 0.0049 O.OO84 6.5 2.8190 0.0005 O.OO26 6.O 2.6614 109.;354 40.27272.72 61.?'3 7850.10 0.0153 0.0374 12.9 5.5 85.0 3.3 88.3 0.0076 0.O227 12,4 5.3465 0.0057 0.0169 12.1 5.1878 101.933 37.64592.71 Cl-74 7351.10 19.1 19.6 10.2 4.4 88.3 6.4 04.7 4.28 4.54 9.6 4.0868 0,4567 0.6547 9.1 3.8792 104.219 38.68242.60 61-75 7352.10 0.O577 0.0673 10.4 3.4 01.7 1.9 93.8 0.013 0.0189 0.9 3.2291 0.0032 0.OO64 9.6 3.1045 79.413 29.39122.70 C1-76 7363.10 0.0056 0.0153 16.8 4.7 91.8 4.6 05;.8 0.0034 0.0056 10.2 4.3682 0.0021 0.0053 9.7 4.1168 102.409 38.36982.87 61-77 7354.10 0.0018 0.06~4 11.6 5.0 03.0 1.0 94.0 0.0114 0.0179 10.8 4.6408 0.0022 0.005~ 10.0 4.2783 104.793 38.33722.'/~ Ct-78 7365.10 0.0137 0.0261 12.6 5.5 87.6 2.3 09.9 0.0068 0.0164 12.1 5.2417 0.0027 0.0096 11.8 5.0715 103.227 37.96842.72 61-79 7356.10 0.0191 0.034 11.6 5.0 8t.0 2.4 83.4 0.0103 0.0212 11.1 4.7408 0.0092 0.0176 16.8 4.5710 102.679 37.87982.71 GI-80 7,,~7.10 0.009 0.0233 12.8 5.5 92.8 2,1 94.9 0.006 0.0152 12.2 5.2333 0.0048 0.0114 11.8 $.0150 102.282 37.,,',',',',',',',','~ 2.72 C1-81 7358.10 2.99 3.63 16.6 4.$ 89.8 1.6 61.6 0.2775 0.4170 9.9 4.2441 0.0196 0.0449 g.4 4.0269 105.144 38.70O32.72 61-82 78~8.89 1.10 1.43 10.7 4.5 93.5 O.4 g3.g O.0587 0.1532 10.0 4.2200 0.0118 0.0286 g.6 4.0131 103.136 37.83622.73 61.83 7360.10 0.1157 0.181 6.0 3.8 05.3 1.2 06.4 0.0326 0.061.5 8.3 3.5117 0.0102 0.0231 7.g 3.3082 104.808 38,73432.7t Cl-84 7361.20 3431. 3460. 10.4 4.4 85.2 4.0 89.2 63,5, 724. g.5 3.9740 151. 169, 8.9 3.6694 102.8~8 37.76962.72 C1-85 7362.10 0.8197 1.05 0.4 4.0 96.0 3.3 99.3 0.2725 0.28 8.7 3.6785 0.0419 0.08 8.2 3.4562 104.244 38.50252.7t Ct-86 7363.10 48.6 72.1 12.0 4.6 85.8 3.g 89.7 18.9 26.5 11.0 4.1583 5.38 7.16 10.4 3.8864 91.453 33.63222.72 C1-87' 7864.10 0.0141 0.0262 11.3 4.7 06.6 2.8 9O.4 0.0068 0.0135 10.7 4.4619 0.0023 0.007 10.2 4.2341 99.274 37.35442.~ CI-88 7365.10 0.0051 0.0138 tl.4 4.9 02.8 5.0 07.8 0.0052 0.0098 10.8 4.6102 0.0017 0.0045 t0.2 4.3569 103.52 38.26222.71 GI-89 7366.10 0.0349 0.0411 10.8 4.7 01.1 4.2 95.4 0.0054 0.0096 t0.1 4.3650 0.0012 0.0034 g.5 4.1011 106.148 39.01292.72 0t-90 7367.10 0.0136 0.0232 11.9 5.1 88.6 3.0 91.5 0.0053 0.0133 11.3 4.8286 0,0024 0.0081 10.9 4.6494 102.462 37.822 2,Z1 C1-91 7368.10 0.7253 0.9829 g.g 4.2 g2.g t.t 94.0 0.092 0.1534 g.2 .3.8793 0.0566 0.0636 8.8 3.6881 104.059 88.25642.72 61-92 7369.10 0.0274 0.0468 11.6 4.9 76.2 1.g 78.1 0.0089 0.0236 11.2 4.6980 0.0068 0.0186 10.g 4.6530 100.904 37.829 2.70 ct-gG 7370.10 0.0021 0.0052 7.1 3.1 80.9 S.0 74.g 0.0012 0.0032 6.5 2.8424 0.0007 0.002 6.0 2.5948 111.592 40.99222.72 G2-94 7371.10 0.002 0.0049 5.9 2.6 77.4 7.2 84.6 0.001 0.0027 5.4 2.3734 0.0005 0.0016 5.0 2.1708 112.649 41.50432.71 62-05 7872.10 0.0248 0.0,517 13.5 6.0 86.3 2.2 88.5 0.0106 0.0297 13.0 5.7,,~2 0.0076 0.0222 't2.7 5.5454 104.22 38.26,51 2.72 G2.06 7373.10 0.0128 0.0264 11.7 5.1 87.3 3.3 g0.6 0.0071 0.017 11.2 4.8831 0.0033 0.0105 10.8 4.6974 105.111 38.80292.7t C2-g'/'7374.10 81.6 83.9 11.0 4.8 86.9 1.1 85.0 15.1 15.7 10.1 4.3259 6.15 6,45 0.5 4.0740 105.143 ~8.59532.72 62-08 7375.10 0.0961 0.1566 10.9 4.8 90.6 1.8 92.4 0.0212 0.0428 10.3 4.4579 0.0129 0.0159 9.9 4.2700 106.875 39.01042.73 C2-09 7376.10 0.0092 0.0178 11.1 4.9 92.8 6.0 09.4 0.0026 0.0063 t0.4 4.5353 0.001 0,0028 g.8 4.2288 105.9~5 39.112 2.71 C2-100 7377,10 0.0442 0.0683 10.9 4.8 92.9 3.6 96.6 0.0138 0.0276 10.3 4.5351 0.0051 0.0122 0.0 4.3551 107.396 39.61 2.7t C2-101 7378.29 0.0576 0.0616 11.6 5.1 02.7 1.2 gg.g 0.0144 0.0265 10.9 4.7503 0.0048 0.0109 10.5 4.5362 105,114 38.68082.72 O2-102 7379.89 0.4361 0.5949 12.4 5.4 95.1 1.6 96.8 0.0566 0.102 tl.6 5.0825 0.0119 0.0277 11.2 4.8428 104.414 38.56122.71 C2-103 7380.10 1~15 1.46 10.3 4.5 96.8 0.4 97.2 0.3649 0.5152 g.6 4.1882 0.0786 0.1~51 g.2 8.9826 106.942 39.37732.72 C2-104 7381.20 0.4104 0.5653 10.6 4.7 g0.g 2.1 03.1 0.0292 0.0595 10.0 4.4167 0.0052 0.0136 9.6 4.2192 108.892 89.92692.73 C2-105 7382.10 0.012 0.0184 11.2 5.0 84.6 6.8 91.5 0.0023 0.0061 10.6 4.6494 0.001 0.003 10.1 4.3770 106.3~ 39.16592.72 C2-106 7383.10 5.96 7.24 11.4 5.1 87.4 8.8 96.1 2.24 2.79 10.7 4.7572 0.96 0.9931 10.3 4.~..'~09 107.195 39.61062.71 62-107 7364.20 0.0105 0.0174 9.4 4.2 05.0 0.8 05.8 0.0031 0,006 8.9 3.8877 0.0007 0.0023 8.3 3.6108 108.689 39.98042.72 62~108 7385.10 0.0057 0,0126 g.0 3.g 86.g 6.9 03.8 0.0024 0.0038 8.4 3.6486 0.0006 0.0018 7.7 3.3424 108.624 39.99832.72 C~-lOe 7386.10 416 425. 9.6 4.3 87.1 1.4 88.5 102. 105, 8.8 3.8615 9.24 17.7 8.4 3.6422 105.343 39.95212,71 G2-110 7887.29 0.0048 0,0093 g.9 4.4 85.4 6.5 91.g 0.0021 0.(]054 9.3 4.1113 0.001 0.0027. 8.7 8.8325 109.583 40.18732.73 C2-111 7388.10 59.2 66.7 10.5 4.6 01.2 5.1 g$,..q 26.9 80.0 9.7 4.2227 10.9 12.0 9.3 3.9950 107.306 89,14812.74 C2-112 7389.20 0.0076 0,0148 10.0 4.4 ~3.8 3.2 97.0 0.0021 0.0054 9.2 4.0119 0.0008 0.0024 8.7 3.7298 107.167 39.377 2.72 C2-113 7390.20 0.0094 0.0118 10.0 4.5 92.1 1.2 03.3 0.0021 0.0045 9.4 4.1610 0.0008 0.0023 8.9 3.8994 109.39 40.04942.73 62-114 7391.10 0.5303 0.728 9.5 4.2 91.0 7.1 98.0 0.0612 0.1098 8.8 3.8337 0.0114 0.0271 8.4 3.6335 105.581 39.85982.72 C2-115 7392.29 0.5631 0.7736 g.1 4.0 90.7 4.3 05.0 0.0487 0.0914 8.4 3.7328 0.0074 0.0188 8.1 3.6579 110.134 40.51192.72 G2-t16 7393.10 0.0043 0.0089 0.3 4.1 89.0 3.1 92.1 0.0014 0.0038 8.6 3.7824 0.0005 0.0017 7.g 3.4,530108.815 40.01722.72 O2.117 7394.29 0.2826 0.4174 g.7 4.4 85.2 2.8 88.1 0.0221 0.0469 9.0 4.0237 0.0059 0.0149 8.5 3.7953 111.055 40.79952.72 C2-118 7395.10 0.0045 0.0094 t0.0 4~5 g0.4 1.5 91.8 0,002 0.0052 g.4 4.1552 0.0009 0.0025 8.8 3.8763 109.136 40.18122.72 02-119 7896.10 0.0023 0.0045 8.7 3.9 89.5 1.g 91.4 0.0011 0.0029 8.0 3.5631 0.0006 0.0017 7.4 3.2772 111.137 40.98052.71 62-120 7397.10 0.0065 0.0187 10.8 4.8 70.4 10.1 80.5 0.0037 0.0071 10.1 4.,5124 0.0014 0.0038 g.6 4.2479 108,619 39.96152.72 62-121 7398.10 0.0038 0.0087 8.2 3.6 66.g 10.8 77.7 0.0011 0.003 7.2 8.1676 0.0004 0.0013 6.3 2.7807 111.217 41.02822.71 O2-122 7399.10 0.0096 0.0149 9.5 4.3 86.3 10.0 66.2 0.0022 0.0054 8.8 3.9528 0.0009 0.0026 8.3 3.6985 110.531 40.82622.71 G2.123 7400.20 1.04 1.07 10.0 4.4 70.1 11.2 g0.3 0.07~0 0.1262 9.1 3.9898 0.0159 0.0362 8.6 3.7598 108.137 39.78182.72 62-124 7401.10 0.2434 0.3593 10.1 4.5 85.2 g.g 08.0 0.029 0.0577 g.4 4.1472 0.0064 0.0189 g.0 3.9486 108.468 40.10092.70 02-125 7402.10 0,0064 0.0125 8.8 3.9 88.9 g.$ 92.5 0.0022 0.0058 8.2 8.6498 0.0012 0.0034 7.8 3.4305 111.013 40.59632.73 O2-126 7403.50 1.27 1.53 10.2 4.5 91.2 3.8 OS.0 0.4512 0.5871 9.5 4.1614 0.2597 0.2737 g.0 3.9378 107.902 39.84462.71 I nic~rc~ I rorody. I Vcim,o. I S~r~Uo,, I~.l ,~"r~. t mmd~y~ I Porody. I Vokm~. I ~ I roro~y. I ' I ~"Y iv~. D~,~, ~-127 7~.2~ 1.26 1.~ 11.0 4.0 ~ 11.4 ~.O 0.2612 0.~ tO: d.~2~ 0.~9 0.~77 0.7 d.2~ 1~.217 3g.8~ 2.~ ~-~2e ~.~o o.~ o.~ ~o: 4.e ~.o 2~ ~.e o.~ o.~7 e~ ~.l~ o.ol o.~6 e.o ~.~7~ ~.~2~ ~.~ 2.~ G2-129 7~.10 6.96 10.3 10.4 4.6 ~.8 6~ ~ 2.13 2.67 9.8 4.2~2 0.~114 0.~6 9.4 4.~1 1~.778 39.3937 2.71 ~-1~ 7~7.10 0.~ 0.~1 9.8 4~ ~ 9.1 ~.6 0.~8 0.~ 9.1 3.9~2 0.~18 0.~6 8.7 3.7891 1~.181 39.8~ 2.71 ~.lm 74~.10 0.~ 0.~ 10.1 4~ 66.7 8.0 04.7 0.~3 0.~ 9.4 4.1~ 0.~14 0.~7 9.0 3.97~ 1~.~ 40.1~9 2.72 1 ooo 10o lO O.Ol o. ool o. oool PERMEABILITY TO AIR VERSUS POROSITY MeltWater South Well 0 2 4 6 8 10 12 14 16 '18 20 Porosity, pement COre LabOratOries (31-1 C1-2 C1-3 C1-4 C1-5 C1-6 C1-8 C1-9 C1-10 C1-11 C1-12 C1-13 C1-14 C1'15 C1-16 C1-17 C1-18 C1-20 C1-21 Cl -22 C1-23 Cl-24 C1-25 Cl -26 (31-27 C1-28 C1-29 C1-30 C1-31 (31-32 C1-33 C1-34 C1-35 C1-36 C1-37 (31-38 (31-39 (31-40 Cl-41 C1-42 Cl-43 C1-44 C1-45 C1-46 C1-47 C1-48 15.25141 14.25512 14.30539 12.9777 16. i6466 11.66393 12.87465 9~602225 13.50877 14.79411 7.399401 14.0772 14.19202 12.42739 10.553.28 10.28907 10,91401 10.42441 10.9487 16.08911 14.87368 9.828448 12.54547 13.04509 15.16177 10. 26445 14.69777 11.84284 15.0612 13.43448 11.20718 9.470203 14.78983 10.99464 14.45781 14.02268 12.70488 14.56109 15.39995 15.30773 14.72083 11.55033 11.81938 9.921569 11.30003 .10.21442 0.098477 0.05689 0.04356 0.243967 O. 114738 0.034939 0.027661 0.034763 0.058959 0.080949 0.014635 0.076021 0.069751 0.055892 0.030427 0.032993 O. 142297 0.027424 0.073457 O. 154662 0.082423 0.013712 0.03576 0.058535 O. 166782 0,038883 0.126216 0.033857 0.075854 0.076988 0.005947 0.0318 O. 123229 0.027166 0.05898 0.088967 0.047552 0.099962 O. 174685 0.064207 0.073949 1.380997 0.033986 0.884957 0.049933 0.04878 Core Laboratories C1-49 C1-50 C1-51 C1-52 C1-53 C1-54 C1-55 C1-56 C1-57 C1-58 C1-59 C1-6O C1-61 C1-62 (31-63 C1-64 C1-66 C1-67 01-68 C1-69 C1-70 C1-71 C1-72 C1-73 Cl-75 C1-76 Cl -77 Cl-78 Cl-79 C1-80 C1-81 C1-82 C1-83 C1-85 C1-86 C1-88 C1-89 C1-90 C1-91 C1-92 C1-93 C2-94 C2-95 C2-96 C2-98 13.45428 14.63857 13.0657 12.56904 11.30842 14.39765 14.35393 13.78159 14.00349 13.9785 10.30588 12.57085 10. 32234 10. 65236 11.0326 9.809893 10. 60253 11.65613 9.997925 11.49057~ 11..52663 12.7369 7.1'74521 12.78136 10.39698 10. 83813 11.63904 12.62533 11.60662 12.78343 10. 578 10.66307 9.023795 9.433787 11,96654 11.3746 10.79118 11.860'1 9.883319 11.55715 7.109152 5.941146 13.49076 11.71599 10. 93445 0.051461 0.078924 0.05695 0,029221 0.020479 0.081388 O. 127408 0.052242 0.131524 0.05635 0.841204 0.01924 0.011648 0.016628 0.038461 0.022313 0.048419 0.020487 0.208885 0.026273 0.03316 0.073638 0.030838 0.03738 0.067286 0.015337 0.063426 0.02611 0.034011 0.023299 3.627311 1.429419 0.181004 1.063756 72.10124 0.013773 0.041097 0.023199 0.982935 0.046784 0.005174 0.004862 0.051652 0.026363 Core Laboratories 02-99 11.07902 C2-1 O0 10.87303 C2-101 11.60865 02-102 12.38282 02-103 10.26668 02-104 10.5976 02-105 11.23615 02-106 11.42433 02-1 O7 9.43843 02-108 8.961424 0.017803 0.068316 0.061607 0.594882 1.463585 0.565341 0.018424 7.24084 0.017427 0.012614 02-110 9.907866 0.009269 C2-112 9.951048 .0.014819 C2-113 10.03214 0.011772 C2-114 9.5064 0.727966 C2-115 9.063791 017736 C2-116 9.311753 0.008873 C2-117 9.7314'12 0.417382 C2-118 9.996936 0.009378 C2-119 8.6676'14 0.004528 C2-120 10.77586 0.013733 C2-12'1 8.167937 0.008738 C2-122 9.479711 0.01487 C2-123 9.968191 1.073514 C2-124 10.06752 0.359257 C2-125 8.833367 0.012519 C2-126 10.17807 1.530314 C2-127 10.96961 1.600634 C2-128 10,22783 0.151378 C2,129 '10.40308 10.29398 C2-130 9.751373 0.008124 C2-131 10.0717 0.007952 Core Laboratories £nNF!n WELL LOG TRANSMITTAL To: State of Alaska March 9, 1999 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MELTWATER SOUTH # 1, OSLoq. AK-MM-90071 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of~ Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-287-20014-00. RECEIVED !:!AR 1 5 't999 0il & Gas C~s. Com~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton ComDanv d ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 12, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Meltwater South #1 (Permit No. 99-006) Well Completion Report Dear Mr. Commissioner: ARCO Alaska, Inc., as operator of the exploration well Meltwater South #1, submits the enclosed "Well Completion Report" (form 407). Also included with the completion report is one blueline and one reproducible of the following logs: Compensated Neutron T.D. Density, Gamma Ray with Platform Express, Platform Express Array Induction, Modular Dynamics Tester Single Probe- Sample chambers MDT, Combinable Nuclear Magnetic Resonance Tool CMRT, Chronological Sample Taker - Gamma Ray CST-PGGT, and Dipole Shear Imager with GR/DSI/GR/AMS. The Commission is requested to keep confidential the enclosed information due to the exploratory nature of the well. If you have any questions regarding this matter, contact me at 263-4603. Sincerely, P. Mazzolini Drilling Team Leader AAI Driling PM/skad STATE OF ALASKA ALASKA~OOIL AND GAS OONS.ERVATION COMMI~N WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification Of Service Well · Oil [] Gas [] Suspended [] Abandoned [] Service [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 99-006 ,3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-287-20014 4. Location of well at surface ~ ..... ,~~ ~ 9. Unit or Lease Name 671' FNL, 1748' FWL, Sec. 33, T7N, R7E, UM ~ C0~.;~PLE'i'i0N I~~ f N/A At Top Producing Interval ' ,~ xJ~AT~ f - 5.i'!~~_'!' ' '! lO. Well Number 337' FNL, 759' FEL, SEC 32, T7N, R7E, UM ~ I Meltwater South #1 At Total Depth [/'E~j~,J.J~ED [~ . ~"-'~ i 11. Field and Pool 306' FNL, 817' FEL, SEC 32, T7N, R7E, UM -'~~ ......... i~ ~ Tarn Exploration 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. RKB 28 feetI ADL 389047 ALK 4994 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions January 25, 1999 February 6, 1999 2/11/99 P&AI N/A feetMSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 8935' MD / 8377' TVD surface YES [] No []I N/A feet MD 1420' · 22. Type Electric or Other Logs Run Platform Express/CMR, Dipole Sonic 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FI'OM HOLE SIZE, CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40' Surface 118' . 24" 9 cu yds High Early 9.625" 40# L-80 Surface 2549' 12.25" 520 sx AS III, 340 sx Class G cement retainer @ 2498' refer to page #2 for cement plug summary ' 24. Perforations open to Production (MD.+ TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) ~ SIZE DEPTH SET (MD) PACKER SET (MD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. I r' ~i~PTH INTERVAL (MD) AMOUNT & KIND oF MATERIAL USED N/ARECEIvcu lv -R i 5 19'99 · Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IOAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, pOrosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. · See Attachment Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE - Submit in duplicate 29. NAME Top West Sak Base West Sak C-80/K- 10 C40/K-5 Top Bermuda SS K-3 GEOLOGIC MARKERS MEAS. DEPTH 1785' 2444' 3376' 4484' 7206' 7567' TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. cement plug #1: 8935'-7120' cement plug #2: 4000'-3700' cement plug #3: 3570'-3370' cement plug #4: 2398'-2658' cement plug #5: 300'-surface 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Core Description, Mud Logs 32. I hereby certify that the following is true and correct to the best of my knowledge. ' ~J(1 Paul Mazzolini Title Drilling Team Leader Date ~ ~ Prepared by Sharon AIIsup-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 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 3/10/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:Meltwater South WELL ID: AX9909 STATE:ALASKA AREA/CNTY: EXPLORATION SPUD:01/25/99 RIG:DOYON 141 TYPE: DRILLING SECURITY: TIGHT API NUMBER: 50-287-20014-00 01/23/99 (D1) MW: 9.8 rISC: 105 PV/YP: 19/46 APIWL: 14.8 TD: 80'(80) PREPARING F/SPUD SUPV: R. W. SPRINGER Arrived on location w/all rig components. Rig up. Accept rig @ 1000 hrs. 1/23/99. 01/24/99 (D2) MW: 10.0 VISC: 80 PV/YP: 29/49 APIWL: 14.8 TD: 108'(0) WAITING ON WEATHER TO SPUD SUPV: R. W. SPRINGER Continue mixing spud mud. Pre-job safety meeting. Waiting on Phase III weather blow. Function test diverter. 01/25/99 (D3) MW: 10.0 VISC: 80 PV/YP: 25/30 APIWL: 9.5 TD: 1205'(1097) DRILLING @ 1690' SUPV: R. W. SPRINGER Continue preparing f/spud. Waiting on weather. Drill from 107' to 1205'. 01/26/99 (D4) MW: 10.2 VISC: 71 PV/YP: 27/25 APIWL: N/A TD: 2558'(1353) POH TO RUN CASING SUPV: R. W. SPRINGER Continue drilling surface from 1205' to 1730'. Survey. Circ Bttms up, flow check well, pump dry job. PJSM. Drill from 1730'-2558'. 01/27/99 (D5) MW: 10.2 VISC: 50 PV/YP: 23/14 APIWL: 5.9 TD: 2558'(0) NIPPLING UP BOPE SUPV: R. W. SPRINGER Circ bttms up, flow check, pump dry job. Wiper trip to d. Clrs, hole in good condition. PJSM. Run 9-5/8" casing. Pump Cement. Bumped plugs. Floats held. N/D diverter system. 01/28/99 (D6) MW: 9.8 VISC: 44 PV/YP: 12/8 APIWL: 10.4 TD: 2558'(0) DRILLING 8.5" HOLE @ 2660' SUPV: R. W. SPRINGER PJSM. N/U BOPE and test. Valves upper pipe rams failed. Change out upper VBR rams. Continue testing BOPE. Change out Failed manual choke valve. Circulate cement contaminated mud (thick) from hole @ slow rate. 01/29/99 (D7) MW: 9.6 VISC: 60 PV/YP: 14/18 APIWL: 7.2 TD: 4110' ( 1552) WIPER TRIP SUPV: R. W. SPRINGER Drill hard cement thru shoe and 20' new hole to 2778'. Displace well to new 9.6 ppg mud. Perform LOT to 18.0+ ppg EMW. Drill from 2778' to 4110'. Volcanic ash stringers From 3900' on, balling of bit & stabilizers hard to keep Weight on bit. 01/30/99 (D8) MW: 9.6 VISC: 49 PV/YP: 15/16 APIWL: 6.0 TD: 5503'(1393) DRILLING 8.5" SUPV: R. W. SPRINGER Continue drilling from 4110'-4209'. Penetration very slow Due to balling of bit & stabilizers(volcanic ash stringers).. Circ sweep and clean hole, survey. Flow check well. Drilling From 4209' to 5503' 01/31/99 (D9) MW: 9.6 VISC: 47 PV/YP: 15/13 APIWL: 5.4 TD: 7019'(1516) MAKE UP BHA SUPV: R. W. SPRINGER/MIKE WHITELEY Drill from 5503'-5628'. Pump sweep around, circ bottoms up, Flow check, survey. Short trip to 4100', no problems. Drill From 5628' to 7019' 02/1/99 (D10) TD: 7278' (259) SUPV: MIKE WHITELEY MW: 9.6 VISC: 49 PV/YP: 15/17 LAY DOWN BHA APIWL: 5.1 Survey. Pump sweep around, circ hole clean. Flow check. POOH Hole in good shape. PJSM. MAD pass LWD from 8970' to 7019' Drill from 7019' to 7278'. 02/2/99 (Dll) TD: 7368'(91) SUPV: MIKE WHITELEY MW: 9.6 VISC: 46 PV/YP: 12/15 APIWL: 5.2 PREPARE CORE FOR TRANSPORT TO ANCHORAGE - WAIT ON ORDERS Circ for samples at 7275'. Drilling break from 7262'-7278'. Gas increased from 20 units to 325 units, no mud loss. POOH For core. PJSM. RIH, tight at 8956'. Wash and ream from 6950 To 7000'. Core Bermuda from 7278'to 7369' POOH with core Barrel. Hole tight from 7240'-7200' POOH. 02/3/99 (D12) TD: 7407'(38) SUPV: MIKE WHITELEY MW: 9.8 VISC: 56 PV/YP: 16/17 TESTING BOPS APIWL: 4.5 PJSM. Prepare cores for transport. RIH for core %2. Core Bermuda sand from 7369'-7407'. Core jammed after connection. Unable to restart. POOH with core barrel. PSJM. 02/4/99 (D13) MW: 9.8 VISC: 51 PV/YP: 15/14 APIWL: 4.6 TD: 7407'(0) DRILLING AHEAD AT 7600' SUPV: MIKE WHITELEY Test BOPs to 250/5000 psi. Bottom pipe rams leaked. Repaired And retested. RIH to 7050'. MAD pass LWD from 7060' to 7381'. 02/5/99 (D14) MW: 9.9 VISC: 50 PV/YP: 16/19 APIWL: 4.7 TD: 8832'(1425) CIRC AND CONDITION MUD AND HOLE FOR LOGS-@8935' TD SUPV: MIKE WHITELEY MAD pass with LWD's from 7381'-7407' Drill from 7407' to 8832'. 02/6/99 (D15) MW: 9.8 VISC: 51 PV/YP: 16/15 APIWL: 5.2 TD: 8935'(103) SUPV: MIKE WHITELEY RUNNING OH LOGS Drill from 8832' to 8935'. Pump sweep around. Circ hole Clean. POOH to 6680'. Hole in good shape. RIH tight @ 7770'. Pump sweep around. Circ hole clean. POOH to run OH logs, no problems. PJSM. Run platform express/CMR. 02/7/99 (D16) MW: 9.9 VISC: 57 PV/YP: 16/16 APIWL: 4.8 TD: 8935'( 0) RIH WITH DIPOLE SONIC @ 0600 HRS. SUPV: MIKE WHITELEY Finished running platform express/CMR. Tight from 6190'- 6130'. RIH with Dipole Sonic, tool stopped @ 6130'. Ledge Picked up OK. Wash and ream from 6100' to 6200' RIH w/ MDT. 02/8/99 (D17) MW: 9.9 VISC: 64 pV/yp: 18/15 APIWL: 4.1 TD: 8935'(0) RUNNING CHECK SHOT SUPV: MIKE WHITELEY RIH with MDT tool. Stopped at 4715'. RIH with Dipole Sonic. Tools stopped @ 4715'. Tools balled up with clay. Wash and Ream from 4630'-4780'. Ran Dipole Sonic from 8900'-5800'. 02/9/99 (D18) MW: 9.8 VISC: 57 PV/YP: 13/15 APIWL: 4.4 TD: 8935'(0) CIRC AND COND MUD TO SPOT CEMENT PLUG SUPV: MIKE WHITELEY Finish running seismic check shot survey. RIH with MDT. RIH W/CST for side wall cores. Core from 8839'-3470'. POOH. Recovered 30 cores. Run %2, CST side wall cores, took 24 Cores from 8785'-7135'. POOH. Recovered 23 cores. 02/10/99 (D19) MW: 9.9 VISC: 46 PV/YP: 17/16 TD: 8935'(0) MAKE UP 9-5/8" CEMENT RETAINER SUPV: MIKE WHITELEY APIWL: 4.0 Circ and condition mud to spot abandonment plug. PJSM. Spot balance cement plug %1 in three stages. First stage From 8935'-8335'. Spot second stage plug %1 from 8335'- 7735'. Spot third stage of plug %1 from 7735'-7120'. Spot cement plug %2 from 4000'-3700'. 02/11/99 (D20) MW: 9.9 VISC: 50 PV/YP: APIWL: TD: 8935'( 0) RIG RELEASED - MOVING RIG TO 2L PAD SUPV: MIKE WHITELEY Spot hi-vis pill. Spot cement plug %3 from 3570'-3370' Set retainer @ 2498'. Pump plug %4 from 2398'-2658'. Rih with 3.5" tubing. Spot plug %5 from 300'-33'. Well P&A'd. Release rig @ 2200 hfs 2/11/99. Customer Project Field Structure Wellhead Profile Alaska State Plane Zone 4 Prudhoe Bay Unit Meltwater South (~ ,. 0 Meltwater South #1 \~' Meltwater South #1 Creation Date 3/4/99 Profile Type Your Ref API-50272001400 Job Number AKMM 90071 Kelly Bushing Elev. 532.63 Print Date 3~4~99 MD (ft) Incl. Deg. Azim. Sub-Sea TVD Deg. (ft) (ft) Local N Co Local E Co Global N C Global E C Dogleg Vertical Section (ft) (ft) (ft) (ft) (deg/100ft) (ft) 0 108 185 278 369 462 554.04 646.65 741.04 828.45 920.94 1009.93 1104.13 1193.86 1286.49 1379.39 1472.27 1565.14 1657.65 1750.84 1843.44 1937.39 2029.91 2122.79 2215.46 0 0 1.09 1.13 1.1 0.49 3.62 5.73 9.03 11.69 13.74 14.43 16.27 18.53 19.8 21.54 23.26 25.21 26.21 26.18 27.23 27.51 27.1 28.12 28.17 0 -532.63 -532.63 0 -424.63 -424.63 107.87 -347.635 -347.635 94.54 -254.652 -254.652 98.17 -163.669 -163.669 167.49 -70.677 -70.677 262.5 21.301 21.301 271.64 113.599 113.599 273.36 207.195 207.195 275.94 293.172 293.172 278.96 383.39 383.39 281.33 469.705 469.705 281.32 560.541 560.541 280.95 646.159 646.159 280.4 733.654 733.654 279.14 820.571 820.571 275.25 906.444 906.444 271.87 991.13 991.13 271.31 1074.48 1074.48 275.56 1158.107 1158.107 276.33 1240.828 1240.828 277.14 1324.262 1324.262 277.69 1406.473 1406.473 278.22 1488.775 1488.775 278.26 1570.487 1570.487 0.37 -0.002 448791.1 5821655 0 0 0.37 -0.002 448791.1 5821655 0 0 0.145 0.695 448791.8 5821655 1.416 -0.72 -0.199 2.451 448793.5 5821654 0.28 -2.5 -0.394 4.21 448795.3 5821654 0.084 -4.27 -0.909 5.18 448796.3 5821654 1.112 -5.3 -1.673 2.383 448793.5 5821653 4.015 -2.62 -1.922 -5.138 448785.9 5821653 2.409 4.81 -1.353 -17.246 448773.8 5821653 3.504 16.89 -0.034 -32.904 448758.2 5821655 3.088 32.59 2.646 -53.076 448738 5821658 2.329 52.94 6.471 -74.388 448716.7 5821662 1.01 74.57 11.367 -98.838 448692.3 5821667 1.953 99.44 16.544 -125.165 448666 5821672 · 2.522 126.2 22.172 -155.048 448636.2 5821678 1.385 156.55 27.722 -187.364 448603.9 5821684 1.933 189.31 32.109 -222.465 448568.8 5821688 2.444 224.68 34.432 -260.499 448530.8 5821691 2.576 262.71 35.542 -300.615 448490.7 5821692 1.112 302.65 38.005 -341.653 448449.7 5821695 2.013 343.68 42.32 -383.041 448408.3 5821699 1.194 385.28 47.387 -425.934 448365.5 5821705 0.496 428.47 52.862 -468.02 448323.4 5821711 0.52 470.91 58.823 -510.65 448280.8 5821717 1.13 513.95 65.088 -553.912 448237.6 5821723 0.058 557.66 2309 2401.51 2486.35 2581.4 2674.37 2767.29 2860.34 2953.11 3046.61 3139.54 3232.79 3325.18 3423.07 3514.82 3608.35 3699.82 3793.2 3888.01 3979.24 4067.53 4159.96 4257.15 4350.58 4444.8 4535.67 4628.79 4721.91 4813.91 49O8.93 5001.77 5093.42 5183.14 5280.03 5372.99 5462.5 27.89 27.59 28.19 28.33 27.99 27.34 28.36 28.79 28.68 28.29 28.17 28.07 29.66 29.78 29.04 28.55 28.01 28.56 28.01 28.17 29.29 28.25 28.33 27.5 27.89 28.09 29.57 29.07 29.84 29.26 28.39 27.12 25.65 24.61 23.24 278.51 1653.055 1653.055 71.497 278.15 1734.933 1734.933 77.736 277.76 1809.918 1809.918 83.227 276.28 1893.64 1893.64 88.726 278.02 1975.607 1975.607 94.183 275.45 2057.906 2057.906 99.252 276.75 2140.178 2140.178 103.879 280.2 2221.654 2221.654 110.425 280.95 2303.64 2303.64 118.674 279.51 2385.321 2385.321 126.548 278.91 2467.479 2467.479 133.608 279.33 2548.964 2548.964 140.51 279.39 2634.689 2634.689 148.196 279.37 2714.37 2714.37 155.609 277.85 2795.847 2795.847 162.491 279.13 2876.007 2876.007 168.992 278.05 2958.242 2958.242 175.603 278.03 3041.732 3041.732 181.887 277.97 3122.069 3122.069 187.904 278.95 3199.959 3199.959 194.02 277.43 3281.01 3281.01 200.339 277.06 3366.202 3366.202 206.24 273.52 3448.479 3448.479 210.319 273.32 3531.735 3531.735 212.952 274.64 3612.195 3612.195 215.886 274.17 3694.423 3694.423 219.242 277.41 3776.004 3776.004 223.8 278.54 3856.219 3856.219 230.047 277.56 3938.956 3938.956 236.585 276.88 4019.72 4019.72 242.342 277.62 4100.014 4100.014 247.914 277.91 4179.41 4179.41 253.557 277.61 4266.204 4266.204 259.374 277.37 4350.364 4350.364 264.521 278.27 4432.181 4432.181 269.452 -597.399 448194.2 5821730 -640.004 448151.6 5821737 -679.308 448112.3 5821742 -723.972 448067.7 5821748 -767.502 448024.2 5821754 -810.337 447981.4 5821759 -853.556 447938.2 5821764 -897.426 447894.4 5821771 -941.613 447850.3 5821780 -985.225 447806.7 5821788 -1028.765 447763.2 5821795 -1071.759 447720.3 5821802 -1118.385 447673.7 5821810 -1163.263 447628.9 5821818 -1208.669 447583.5 5821825 -1252.243 447540 5821832 -1295.986 447496.3 5821839 -1340.471 447451.9 5821845 -1383.28 447409.1 5821852 -1424.398 447368 5821858 -1468.372 447324.1 5821865 -1514.774 447277.7 5821871 -1558.848 447233.7 5821875 -1602.879 447189.7 5821878 -1645.007 447147.6 5821881 -1688.581 447104 5821885 -1733.236 447059.4 5821890 -1777.85 447014.8 5821896 -1824.114 446968.6 5821903 -1869.537 446923.2 5821909 -1913.37 446879.4 5821915 -1954.768 446838 5821921 -1997.43 446795.4 5821927 -2036.57 446756.3 5821933 -2072.532 446720.4 5821938 0.325 0.371 0.739 0.752 0.956 1.462 1.276 1.838 0.403 0.85 0.33 0.24 1.625 0.131 1.124 0.861 0.797 0.58 0.604 0.553 1.447 1 .O86 1.798 0.887 0.8 0.32 2.311 0.811 0.956 0.722 1.026 1.423 1.523 1.124 1.584 601.6 644.65 684.34 729.34 773.21 816.34 859.8 904.14 949.01 993.27 1037.35 1080.87 1128.09 1173.54 1219.45 1263.49 1307.72 1352.64 1395.86 1437.42 1481.84 1528.62 1572.86 1616.87 1659.04 1702.69 1747.57 1792.61 1839.33 1885.11 1929.3 1971.08 2014.13 2053.61 2089.91 5560.48 5646.5 5739.79 5832.84 5925.93 6018.56 6115.46 6206.82 6300.78 6393.13 6486.03 6579.16 6671.83 6760.22 6858.02 6951.59 7049.24 7139.64 7234.77 7320.57 7409.77 7504.15 7598.99 7694.68 7785.92 7877.41 7969.31 8063.92 8155.45 8248.31 8339.72 8433.83 8526.11 8615.16 8709.13 21.45 19.67 19.34 18.66 18.32 17.42 17.18 16.06 15,19 13.64 13.03 12,18 10.82 10.23 9.08 7.47 6.48 5.2 4.74 4.61 4.52 4.09 3.99 2.93 2.57 2.57 2.42 2.42 2.24 2.04 2.22 2.04 2 1.81 1.92 277.05 276.92 276.08 276.71 275.12 275.18 277.08 278.47 275.82 277.9 278.29 278.4 279.47 279.68 284.09 283.25 288.66 286.15 290.11 289.19 289.8 287.35 294.27 290.33 293.71 292.15 293.13 291.41 292.94 294.57 306.04 311.23 307.34 307.45 311.26 4522.801 4603.339 4691.275 4779.255 4867.54 4955.7 5048.217 5135.76 5226.248 5315,688 5406.083 5496.968 5587.775 5674.678 5771 .O92 5863.685 5960.612 6050.541 6145.313 6230.828 6319.745 6413.859 65O8.463 66O3.978 6695.113 6786.511 6878.324 6972.849 7O64.3O3 7157.099 7248.446 7342.491 7434.714 7523.714 7617.635 4522.801 4603.339 4691.275 4779.255 4867.54 4955.7 5048.217 5135.76 5226.248 5315,688 5406.083 5496.968 5587.775 5674.678 5771 .O92 5863.685 5960.612 6050.541 6145.313 6230.828 6319.745 6413.859 65O8.463 66O3.978 6695.113 6786,511 6878.324 6972.849 7O64,303 7157,099 7248,446 7342.491 7434.714 7523.714 7617.635 274.432 278.107 281.635 285.0O6 288,052 290,603 293,676 297.201 300.364 303.087 306.103 3O9.052 311.911 314.596 317.935 321.127 324.345 327.117 329.667 332.019 334.388 336.652 339.016 341.235 342.867 344.465 346.004 347.518 348.921 350.315 352.034 354.21 356,269 358.067 36O.O07 -2109.445 -2139.428 -2170,375 -2200.481 -2229.843 -2258.152 -2286.8 -2312.69 -2337.792 -2360.615 -2381.829 -2401.937 -242O. 189 -2436.11 -2452.156 -2465.239 -2476.638 -2485.407 -2493.238 -2499.824 -2506.516 -2513.228 -2519.464 -2524.792 -2528.852 -2532.63 -2536.322 -2540.019 -2543.465 -2546.64 -2549.551 -2552.285 -2554.8 -2557.152 -2559.513 446683.5 446653.6 446622.6 446592.6 446563.2 446534.9 446506.3 446480.4 446455.3 446432.5 446411.3 446391.3 446373 446357.1 446341.1 446328 446316.7 446307.9 446300.1 446293.5 446286.9 446280.2 446273.9 446268.6 446264.6 446260.8 446257.1 446253.4 446250 446246.8 446243.9 446241.2 446238.7 446236.4 446234 5821943 5821947 5821951 5821954 5821957 5821960 5821963 5821967 5821971 5821973 5821977 5821980 5821983 5821985 5821989 5821992 5821995 5821998 5822001 5822003 5822006 5822008 5822010 5822013 5822O14 5822016 5822017 5822019 5822020 5822022 5822024 5822026 5822028 5822030 5822032 1.887 2.O7 O.464 0.763 0,653 O.972 0.633 1.301 1.197 1.769 0.664 0.913 1.485 0.669 1.397 1.725 1.216 1.444 0.603 0.175 0.115 0.495 0.524 1.135 0.433 0.076 0.17 0.077 0,208 0.225 0,505 0.28 0.155 0.213 0.176 2127.15 2157.36 2188.51 2218.8 2248.31 2276.72 23O5.52 2331.65 2356.95 2379.94 2401.36 2421.68 2440.14 2456.28 2472.61 2485.99 2497.7 25O6.75 2514.84 2521.66 2528.6 2535.54 2542.02 2547.59 2551.82 2555.77 2559.62 2563.48 2567.07 2570.4 2573.5 2576.48 2579.23 2581.79 2584.38 8801.29 8846.09 8935 1.86 314.38 7709.744 7709.744 362.072 -2561.743 446231.8 5822034 1.77 315.5 7754.522 7754.522 363.074-2562.748 446230.8 5822035 1.77 315.5 7843.39 7843.39 365.032 -2564.672 446228.9 5822037 0.129 2586.85 0.216 2587.97 0 2590.12 SURVEY CALCULATION AND FIELD WORKSHEET Job No, 0451-03345 Sidetrack No, Page 1 of 5 I Company ARCO ALASKA INC. Rig Contractor & No. DOYON DRILLING COl - #141 Field .... . Well Name & No, EXPLORATION/MELTWATER SOUTH #1 Survey Section Name SURFACE BHI Rep, A,.J, HARSTAD ~~ WELL DATA -- . Target TVD (Fr) Target Coord, N/S Slot Coord, N/S -670,21 Grid Correction 0,000 Depths Measured FrOm: RKB Target Description Target Coord, E/W Slot Coord. E/W 1749,58 Magn, Declination 26,520 Calculation Method MINIMUM CURVATURE Target Direction (OD) Buil~Walk\DL per: lOOff~ 30m[~ 10m ~ Vert, Sec, Azim, 277.16 Uagn. to Map Corr, 26.520 Map North to: OTHER SURVEY DATA ., Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (Fr) (OD) (OD) (F-r) (FT) (FT) (FT) (Per 100 F~ Drop (-)' Left (-) MWD 0,00 0.00 0,00 0,00 0,00 0,00 0,00 TIE IN POINT ~ MWD 108,00 0,00 0,00 108.00 ' 108,00 0,00 0,00 0,00 0,00 0,00 . 25-JAN-99 MWD 185.00 1,09 !.07.87 77.00 185,00 . -0,72 -0,22 0,70 1,42 1,42 - , 25-JAN-99 MwD , 278,00 1,13 94,54 93,00 277,98. -2,50 -0,57 2,45 0,28 0.04 , 25-JAN-99 MWD 369,00 1,10 98;17 91.00 368.96 -4,27 -0,76 4.21 0,08 -0,03 25-JAN-99 MWD 462,00 0,49 167,49 93,00 461,95 -5,30 -1,28. 5,18 1,11 -0,66 25-JAN-99 MWD 554,04 3,62 262,50 92,04 553,93 -2.62 -2.04 2139 4,01 · 3,40 25-JAN-99 MWD 646,65 5,73 271,64 92,61 646,23 4,81 -2,29 -5,14 2,41 2,28 9,87 25-JAN-99 MWD 741,04 · 9,03 273,36 94,39 ' 739,82 16,89 -1,72 -17.24 3,50 3,50 1,82 25-JAN-99 MWD .828,45 11,69 275,94 87,41 825,80 32,59 -0,40 -32.90 3,09 3,04 2,95 25-JAN-99 MWD 920,94 13,74 278,<J6 92,49 916.02 52.94 2.28 ' -53,07 2,33 2,22 3,27 25-JAN-99 MWD 1009,93 14,43 '281,33 88,99 1002,33 74,57 6,10 -74,39 1,01 0,78 2,66 25-JAN-99 MWD 1104,13 16,27 281,32 94,20 1093.17 99,44 11,00 -98,84 1,95 1,95 -0,01 MWI~ 1193,86 i8,53 280,95 89,73 1178,79 126,20 16,17 -125,16 2,52 2,52 -0,41 26-JAN-99 MWD 1286,49 19,80 280,40 92,63 1266,28 156,55 21.80 -155.05 1,38 1,37 -0,59 26-JAN-99 MWD 1379,39 .21,54 279,14 92,90 1353,20 189,31 27,35 -187,36 1,93 1,87 -1,36 26-JAN-99' MWD '1472,27 23,26 275,25 92,88 1439,07 224,68 31,74 -222,46 2,44 1 ,~85 -4,19 26-JAN-99 . MWD 1565,14 25,21 271,87 92,87 1523,76 '262,71 34,06 -260,50 2,58 2.10 -3,64 26-JAN-99 MWD 1657,65 26,21 271,31 92.51 1607,11 302,65 35,17 -300.61 1,11 '1.08 -0,61 26-JAN-99 MWD 1750,84 26,18 275.56 .93.19 1690.74 343,68 37,63 -341,65 2,01 -0,03 4,56 26-JAN-99 MWD 1843,44 27,23 276,33 92,60' 1773,46 385,28 41,95 -383,04 ! ' 1,19 1.13 0,83 26-JAN-99 MWD 1937,39 27,51 277,14 ' 93.95 1856,89 428.47 47,02 -425,93 0.50 0,30 0,86 26-JAN-99 MWD 2029,91 27,10 277,69 92,52 1939,10 470,91 52,49 -468,02 0,52 -0.44 0,59 . 26-JAN-99 MWD 2122,79 28,12 278,22 92.88 2021,40 513.95 58,45 -510,65 1,13 1,10 0,57 · '~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-03345 Sidetrack No. Page 2 of 5 ~ Company ARCO ALASKA INC. Rig Contractor & No. DOYON DRILLING CO. - #141 Field ~ Well Name & No. EXPLORATION/MELTWATER SOUTH #1 Survey Section Name SURFACE BHI Rep. A.J. HARSTAD Jr~irr~ WELL DATA 'arget TVD (FT) Target Coord. N/S Slot Coord. N/S -670.21 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SSr- 'arget Description Target Coord. E/W Slot Coord. E/W 1749.58 Magn. Declination 26.520 Calculation Method MINIMUM CURVATURE 'arget Direction (DD) Buil~Walk\DL per: lO0ft~ 3Omni lomE] Vert. Sec. Azim. 277.16 Magn. to Map Corr. 26.520 Map North to: OTHER SURVEY DATA . Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F-r) (DD) (DD) (FT) (FT) (F~ (FT) (Per lO0 F'r)Drop (-) Left (-) -26.~99 MWD 2215.46 28.17 278.26 92.67 2103.12 557.66 64.72! -553.91 0.06 0.05 0.04 MWD 2309.00 27.89 278.51 93.54 2185.68 601.60 71 .i 3 -597.40 0.32 -0.30 0.27 26-JAN-99 MWD 2401.51 27.59 278.15 92.51 2267.56 644.65 77.37 -640.00 0.37 -0.32 -0.39 . 26-JAN-99 MWD 2486.35 28.19 277.76 84.84 2342.55 684.34 82.86 -679.31 0.74 0.71 -0.46 29-JAN-99 MWD 2581.40 28.33 276.28 95.05 2426.27 729.34 88.36 -723.97 0.75 0.15 -1.56 9 5/8" CASING TO 2548' 29-JAN-99 MWD 2674.37 27.99 278.02 92.97 2508.24 773.21 93.81 -767.50 0.96 -0.37 1.87 29-JAN-99 MWD 2767.29 27.34 275.45 92.92 2590.54 816.34 98.88 -810.33 . 1.46 -0.70 -2.77 29-JAN-99 MWD 2860.34 28.36 276.75 93.05 2672.81 859.80 103.51 -853.55 1.28 1.10 1.40 29-JAN-99 MWD 2953.11 28.79 280.20 92.77 2754.28 904.14 110.05 -897.42 1.84 0.46 3.72 29-JAN-99 MWD 3046.61 28.68 280.95 93.50 2836.27 949.01 118.30 -941161 0.40 -0.12 0.80 29-JAN-99 MWD 3139.54 28.29 279.51 92.93 2917.95 993.27 126.18 -985.22 0.85 -0.42 -1.55 29-JAN-99 MWD 3232,79 28.17 278.91 93.25 3000. i 1 1037.35 133.24 . -1028.76 0.33 ' ' -0.13 -0.64 · . 29-JAN-99 MWD 3325.18 28.07 279.33 92.39 3081.59 1080.87 140.1'4 -1071.76 0.24 -0..11 0.45 ~9~-9 ~WD 3423.07 '29.66 279;39 97.89 3167.32 1128.09 147.83 -1118.38 1.62 1.62 0.06 29-JAN-99 MWD 3514.82 29.78 279.37 91.75 3247.00 1173.54 155.24 -1163.26. 0.13 0.13 -0.02 · . . 29-JAN-99 MWD 3608.35 29.04 277.85 ~ 93.53 3328.48 1219.45 162.12. .1208.67 1.12 -0.79 -1.63 ~ 29-JAN-99 MWD 3699.82 28.55 279.13 91.47 3408.64 1263.49 .168.62 -1252.24 0.86 -0.54 1.40 . 29-JAN-99 ! MWD 3793.20 28.01 278.05 93.38 3490.87 1307.72 175.23 -1295.98 0.80 ~0.58 -1.16 29-JAN-99 MWD 3888.01 28.56 278.03 94.81 3574.36 1352.64 181.52 -1340.47 0.58 0.58 -0.02 29-JAN-99 MWD 3979.24 28.01 277.97 91.23 3654.70 1395.86 187.53 -1383.28 0.60. -0.60 -0.07 29-JAN-99 MWD 4067.53 28;17 278.95 88.29 3732.59 1437.42 193.65 -1424.40 0.55 0.18 1.11 . 30-JAN-99 MWD 4159.96 29.29 277.43 92.43. 3813.64 1481.84 199.97 -1468.37 1.45 1.21 -1.64 30-JAN-99 MWD . 4257.15 28.25 277.06 97.19 3898.83 1528.62 205.87 -1514.77 1.09 -1.07 ;0.38 30-JAN-99 MWD 4350.58 28.33 273.52 93.43 3981.11 1572.86 209.95, -1558.85 1.80 0.09 -3.79 "------~'SURVEY CALCULATIONAND FIELDWORKSHEETJob NO. 0451-03345 Sidetrack No. Page 3 of 5 Company ARCO ALASKA INC. Rig Contractor & No. DOyoN DRILLING CO. - #141· Field Well Name & No. EXPLORATION/MELTWATER sOuTH #1 Survey Section Name SURFACE BHI Rep. A,J. HARSTAD ~Jllllrj~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -670.21 Grid Correction 0.0(X) Depths Measured Fr°m: RKB ~ MSL ~ SS[-] Target Description Target Coord. E/W Slot Coord. E/W 1749.58 Magn. Declination 26.520 Calculation Method MINIMUM CURVATURE Target Direction ' (DD) Build~Walk\DL per: 100ff~ 30mr~ 10mQ Vert. Sec. Azim. 277.16 Magn. to Map Corr. 26.520 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical TOtal Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FI') (FT) (FT) (F'r) (Per 400 F'r)Drop (-) Left (-) MWD 4444.80 27.50 273.32 94.22 4064.36 1616.87 212.58 -1502.88 0.89 -0.88 -0.21 ~-- . MWD 4535.67 27.89 274.64 90187 4144.82 1659.04 215.52 -1645.00 0.80 0.43 1.45 30-JAN-99 MWD 4628.79 28.09 274.i 7 93.12 4227.05 1702.69 218.87 -1688.58 0.32 0.21 -0.50 '~O-JAN-99 MWD 4721.91 29.57 277.41 93.12 4308.63 1747;57 223.43 -1733.23 2.31 1.59 3.48 30-JAN-99 MWD 4813.91 29.07 278.54 92.00 4388.85 1792.61 229.68 -1777.85 0.81 -0.54 1.23 ._ 30-JAN-99 MWD 4908.93 29.84 277.56 95.02 4471.59· 1839.33 236.21 -1824.11 0.96 0.81 -1.03 ,._ 30-JAN-99 MWD .5001.77 29.26 276.88 92.84 4552.35 1885.11 241.97 -1869.53 0.72' -0.62 -0.73 - ' 30-JAN-99 MWD 5093.42 28~39 277.62 91.65 4632.64 1929.30 247.54 -1913.37 1.03 -0.95 0.81 30-JAN-99 . MWD 5183.14' 27.12 277.91 89.72 4712.04 1971.08 253.19 -1954.77 1.42 -1.42 0.32 30-JAN-99 MWD 5280.03 25.65 277.61 96.89 4798.83 2014.13 259.00 -1997.43 1.52 -1.52 -0.31 30-JAN-99' MWD 5372;99 24.61 277.37 92.96 . 4882.99 2053.61 264.15 -2036.57 1.12 -1.12 -0.26 . · 30-JAN-99 MWD 5462.50 23.24 ' 278.27 89.51 4964.81 208.9.91 269.08 -2072.53 1.58 -1.53 01.01 31-JAN-99 MWD 5560.48 21.45 277.05 97.98 5055.43 2127.1·5 274.06 -2109.44 1~89 -1.83 -1.25 -~-O.---~ MWD 5646.50 119.67 276.92 86.02 5135,97 2157.36 277.74 . -2139.43 2.07 -2.07 -0.15 31-JAN-99 MWD 5739.78 19.34 276.08 93.28 5223.89 2188.50 281.26 -2170,37 0.46 -0.35 -0.90 31 -JAN-99 MWD 5832.84 18.66 276.71 93.06 531 '1.88 2218.80 284.64 -2200.48 0.76 -0.73 0.68 31 -JAN-99 MWD 5925.93 18.32 275.12 93.09 5400.17 2248.31 287.68 -2229.84 0.65 -0.37 ~1.71 31 -JAN-99 MWD 6018.56 17.42 275.18 92.63 5488.33 2276.72 290.23 -2258.15 0.97 -0.97 ' 0.06 31 -JAN-99 MWD 6115.46 17.18 277.08 96.90 5580.85 2305.52 293.31 -2286.80 0.63 -0.25 1.96 · · · 31 -JAN-99 MWD 6206.82 16.06 278.47 91.36 5668.39 2331.65 296.83 -2312.69 1.30 -1.23 1.52 31 -JAN-99 MWD 6300.78 15.1.9 275.82 93.96 5758.88 2356.95 299.99 -2337.79 1.20 '-0.93 -2.82 31 -JAN-99 MWD 6393.13 13.64 277.90 ' 92.35 ·5848.32 2379.94 302.72 -2360.61 1.77 -1.68 2.25 31-JAN-99. MWD 6486.03 13.03 278.29 92.90 5938.71 2401.36 305.73 -2381.83 0.66 -0.66 0.42 · 31 -JAN-99 MWD 6579.16 12.18 278.40 93.13 · 6029.60 2421.68 308.68 -2401193 0.91 -0.91 O. 12 i SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-03345 Sidetrack No, Page 4 of 5 Company ARCO ALASKA INC, Rig Contractor & No, DOYON DRILLING CO, - #141 Field Well Name & No. EXPLORATION/MELTWATER SOUTH #1 Survey Section Name SURFACE BHI Rep, A,J, HARSTAD ~'r~~ WELL DATA Target TVD (Fr) Target Coord. N/S Slot Coord. N/S -670.21 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W 1749.58 Magn. Declination 26.520 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build~Walk\DL per: 100ft~ 30m0 10m0 Vert. Sec. Azim. 277.16 Uagn. to Map Corr. 26.520 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F~ (DD) (DD) (FT) (F'r) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 33~-99 MWD 6671.83 10.82 279.47 92.67 61 20.40 2440.14 311.54 -2420.19 1.49 -1,47 1.15 ~ MWD 6760.22 10.23 279..68 88.39 6207.31 '2456.28 314.22 -2436.11 0.67 -0.67 0.24 31 -JAN-99 MWD 6858.02 9.08 284.09 97.80 6303.72 2472.61 317.56 -2452.15 1.40 -1.1 8 4.51 31-JAN-99 MWD 6951.59 7.47 283.25 .; 93.57 6396.31 2485.99 320.76' -2465.24 1.73 -1.72 -0.'90 01-FEB-99 MWD 7049.24 6.48 288.66 97.65 6493.24 2497.70 · 323;97 -2476.64 1.22 -1.01 5.54 ROTARY ASSEMBLY IN @ 7020' 01-FEB-99 MWD 7139.64 5.20 '286.15 90.40 6583.17 . 2506.75 326.75 -2485.40 1.44 -1142 -2,78 01-FEB-99 MWD 7234.77 4.74 290.11 95.13 6877.94 2514,84 329.30 -2493,24 0.60 -0.48 05-FEB-99 MWD 7320,57 4,61 289,19 85,80 6763,46 2521.66 .331,65 -2499.82 0,17 -0,15 05-FEB-99 MWD 7409.77 4,52 289,80 89,20 ': :6852i37 :~ 2528,60 334,02 -2506,51 0,11 -0,10 STEERABLE ASSEMBLY IN @ 7407' 05-FEB-99 MWD 7504,1'5 4,09 287,35 94,38 6946,49 2535,54 336.28 -2513.23 0,50 -0,46 05-FEB-99 MWD 7598,99 3,99 294,27 94,84 7041,09 · 2542,02 338,65 -2519,46 0,52 -0,11 05-FEB-99 'MWD 7694,68 2,93 290,33 95,69 7136,61 2547,59 340,86 -2524,79 ~ 1,13 -1.11 05-FEB-99 MWD 7785,92 2,57 293,71 91,24 7227,74 2551,82 342,50 -2528,85 0,43 ~ -0,39 ~ MWD 7877,41 2,57 292,15 91,49 7319,14 2555,77 344,09 -2532,63 0,08 O.0o (- 05-FEB-99 MWD 7969.31 2.42 293.13 91.90 7410.95 2559.62 345,63 -2536.32 0.17 -0.16 . · 05-FEB-99 MWD 8063.92 2.42 291.41 94.61 7505.48 2563.48 347.15 -2540.02 0.08 0.00 05-FEB-99 MWD 8155145 2.24 292.94 91.53 7596.93 2567.07 348.55' -2543.46 0.21 -0.20 '05-FEB-99 MWD 8248,31 2.04. 294.57 92.86 7689.73 2570.40 349.94 -2546.64 0.23 · -0.22 . 05-FEB-99 , MWD ' 8339.72 2.22 306.04 91.41 7781.07 2573.50 351.66 -2549.55 0.51 0.20 05-FEB-99 MWD 8433.83 2.04 311.23 94.11 7875.12 2576.48 353,84 · -2552.28 0128 -0.19 05-FEB-99 MWD 8526.11 2.00 307.34 92.28 7967.34 2579.23 355.90 -2554.80 0.15 -0104 05-FEB-99 MWD 8615.16 1.81 307.45 89.05 8056.34 2581.79 357.70 -2557,15 0.21 -0.21 05-FE'B-99 MWD 8709.13 1.92 311.26 93;97 8150.26 2584.38 359.64 -2559.51 0.18 0.12 05-FEB-99 MWD 8801.29' 1.86 314.38 92.16 8242.37 2586.85 361.70 -2561.74 0.13 -0.07 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-03345 Company ARcO:ALASKA INC, Rig Contractor & No. DOYON DRILLING CO.- #141 Well Name & No~ EXPLORATION/MELTWATER SOUTH #1 Survey Section Name SURFACE WELL DATA Sidetrack No. Page Field BHI Rep. A.J. HARSTAD 5 of 5 Target TVD Target Description Target Direction im Date 05-FEB-99 Survey Depth 8935.00 Target Coord. N/S Slot Coord. N/S Target Coord. E/W Slot Coord. E/W Suil~Walk\DL per: 100ft[~ 30m~ lomE~ Vert. Sec. Azim. SURVEY DATA Hole Course Vertical Direction Length TVD Section (DD) (FI') (FT) 315.50 44.80 8287.15 2587.97 315.50 88.91 8376.02 2590.12 -670.21 Grid Correction 1749.58 Mag n. Declination 277.16 Magn. to Map Corr. Total Coordinate Build Rate Build (+) N(+) /S(-) E(+) /W(-) Drop (-) (F-r) 362.70 -2562.75 -0.20 364.66 -2564.67 0.00 0.000 26.520 26.520 Depths Measured From: RKB~] MSL~ SS[- Calculation Method MINIMUM CURVATURE Map North to: OTHER Walk Rate Right (+) Left (-) Comment PROJECTED DATA '~,~.~,. MWS SIDEWALL CORES MEASURED DEPTH LITHOLOGY GRAIN SIZE SORTING SPHERICITY 3458 Tuff 3475 Mdst 3485 Slst 3505 Mdst 3920 Mdst 3925 Mdst 3930 Mdst 7100 Mdst 7120 Mdst 7135 Mdst 7164 Mdst 7195 Mdst 7230 SS VF-UM Poor SA-SR 7255 SS VF-F Mod SA-SR 7265 Slst 7322 SS L-U VF Mod SA-SR 7425 Mdst 7515 Mdst 7535 Mdst 7545 Mdst 7564 Tuff/Slst 8014 Mdst 8090 Mdst 8123 Mdst 8208 Cong Gran-pebble Poor SA 8220 Slst 8273 Mdst 8308 Sltst 8325 Sltst 8340 Sltst 8375 Mdst 8416 SS L-U VF mod SA-SR 8440 SS L-U VF mod SA-SR 8445 SS L VF mod SA-SR 8465 SS L-U VF mod SA-SR 8488 SS L VF mod SA-SR 8535 SS L VF mod SA-SR 8589 $1st 8642 Sltst 8646 SS VF-L F mod SA-SR 8655 SS Lower VF mod SA-SR 8660 Mdst 8722 SS L VF-SLT mod SA-SR 8771 Sltst 8773 SS VF-LM mod SA-SR 8785 Mdst 8810 SS VF-F mod SA-SR 8812 SS VF-F mod SA-SR ~ MWS SIDEWALL CORES 8815 SS 8824 SS 8828 SS,Slt, Mdst 8838 Sltst and Mdst 8839 SS Lower VF Lower VF Lower VF Lower VF mod SA-SR mod SA-SR mod SA-SR mod SA-SR ARCO Alaska, Inc. A Core Description Report Operator and Well Name Page I of ARCO Meltwater South # 1 1I 3 Location Date North Slope, Alaska 2 / 3 / 99 Core Number I Interval Cut Recovered Core # 1I 7278' - 7370.5' Depth Thickness Description 7371.5 chip Sandstone, very fine, firm, qtzJchert, dark lithics? and accessories,, white clay-like matrix (zeoloite?) Non to slightly calcareous, NSOCF, poor porosity 7370.8 chip Sandstone, very fine, firm, qtz/chert, dark lithics? & accessories., white clay-like matrix (zeoloite?), Non to slightly calcareous, NSOCF, poor porosity 7369 chip Siltstone, medium grey, hard, slightly calcareous, scattered organic fragments throughout sample. 7366 chip Siltstone with thin discontinuous organic laminations, organics fragments on bedding surfaces. Dark grey, hard, moderate calcareous. 7363 chip Shale, dark grey, with numerous "coaly" organic fragments, some partially pyritized, hard, moderately calcareous, 7360 chip Slightly sandy siltstone, medium grey, hard, moderately calcareous. NSOCF 7357 chip Sandstone, very fine, medium grey, salt and pepper, moderate calcareous, Scattered pinpoint yellow mineral flourescence, white clay-like matrix (zeoloite?) 60% qtz/chert, 30% dark lithics ? and accessories, NSOCF. Low porosity 7354 chip Slightly sandy siltstone, with thin discontinuous organic laminations. Fragments of Organics on bedding surfaces. Dark grey, hard, moderate calcareous. 7351 chip Sandstone, very fine, salt & pepper, moderate sorting, very calcareous, scattered Bright yellow mineral flourescence, qtx_/chert, dk lithics? & accessories, some biotite. Patchy white clay-like matrix (zeolite?), pale yellow fluorscence, no cut fluor or vis. cut. 7348 chip Siltstone with a sharp contact with very fine sandstone Siltstone, dark grey, hard, mod calc Sandstone, very fine, hard, qtz/chert, dk lithics? and accessories, mod calcareous, NSOCF, Iow porosity 7345 chip Sandstone, very fine -fine, salt & pepper, hard, moderate calcareous, 50% Qtz/chert, 45% Dk lithics? & accessories, 5% biotite, patchy white clay-like matrix (zeolite?) Slow pale yellow flour, when crushed. Bannan/ Wood rCore Number Chips from end of 3' aluminum sleeve barrel Core # 1 AR3B-2389-B ARCO Alaska, Inc. A ~.,' ~,,.~ Core Description Report Operator and Well Name Page ] of ARCO Meltwater South # 1 2I 3 Location Date North Slope, Alaska 2 / 3 / 99 Core Number1 IInterval7278' - 7370.5 ICut Recovered Depth Thickness Description 7341.7 chip Siltstone medium grey, hard, mod. to highly calcareous, scattered organic fragments throughout sample. 7337 chip Very silty sandstone, very fine, medium grey, hard mod calcareous, 5% biotite. NSOCF 7334 chip Sandstone, light grey, salt and pepper, fine to medium grain, angular to sub angular , . White flour, instant straw cut fluor, resid. Yellow rim. 40% qtz, 40% chert, 20 % biotite, accessories and metaminerals 7331 chip Sandstone, light grey, salt and pepper, very fine to fine grain, subangular Calcite cemented, trace to poor vis porosity, no stain, possible layers of light brownish Dead oil? Pinpoint fluor, v slow straw cut fluor., residual yellow rim 30% qtz, 30 % chert 40 % large biotite and others. 7328 chip Sandstone, light grey, silty, very fine to fine, subangular, calcite cemented, No vis porosity, no stain, fractures across grains, minor patchy faint fluor, v. slow yellow cut flour 50% qtz, minor chert and others. 7325 chip Sandstone, light grey, very fine to silty, occ. Med or fine subangular, calcite cemented No vis porosity, no stain, no fluor, v. slow yellow cut flour, 50% qtz, 10% chert, 10% others 7322 chip Sandstone/siltstone, very fine, to silt subangular, minor calcite cemented -others? No visible porosity, no stain, no fluor 7319 chip Siltstone, minor very fine ss, minor calcite cemented -others, no visible porosity, no stain, no fluor, no cut flour, earthy appearance 7316 chip Sandstone, medium grey, very fine to fine occ. medium, salt & pepper, Moderate calc, qtz/chert, dark lithics ? and accessories, scattered biotite. 60% scattered yellow flour, instant pale yellow cut flour, no vis cut. 7313 chip Silty sandstone, very fine, hard, very calc., organic fragments scattered throughout. NSOCF 7309.9 chip Sandstone, fine, occ. medium, salt & pepper, hard, very calcareous, qtz/chert, dark lithics ? and accessories, 5% biotite. NSOCF Chips from end of 3' aluminum sleeve barrel ICore Number 1 AR3B-2389-B ARCO Alaska, Inc. A ~-~ '~.~' Core Description Report Operator and Well Name Page I of ARCO Meltwater South # 1 3I 3 Location Date North Slope, Alaska 2 / 3 / 99 Core Number I Interval ICut Recovered Core #1 7278'-7370.5 Depth Th ickness Descri pti on 7305 chip Sandstone, light grey, salt & pepper, fine to medium grain, firm, mod. Calc. qtz/chert, dark lithics ? and accessories, 15% biotite and organic fragments. Soft white clay-like matrix (zeolite?) NSOCF 7302 chip Sandstone, fine, medium grey, salt & pepper, hard, very calc. qtz/chert, dark lithics ? and accessories, abundant biotite. NSOCF 7299 chip Sandstone, very fine -fine, medium grey, hard, mod. Calc, qtz/chert, dark lithics ? and accessories, abundant biotite, scattered organics NSOCF. 7296 chip Siltstone, medium grey, firm moderate calc. Scattered biotite and organic fragments. NSOCF 7293 chip Shale, dark grey with rare organic fragments, moderate calc. 7290 chip Sandstone, very fine -fine occ. medium, salt & pepper, very calc. qtz/chert, dark lithics ? and accessories. NSOCF 7287 chip Sandstone, very fine, medium grey, very calc. qtz/chert, dark lithics ? and accessories. NSOCF 7284 chip Shale, dark grey with thin siltstone interbedds, hard, slightly calc. 7281 chip Sandstone, fine, light grey, firm, si calc, qtz/chert, dark lithics ? and accessories, scattered biotite. Poor to fair porosity 80% pale yellow - yellow green fluor, pale yellow cut fluor when crushed No visible cut, weak odor, no stain. 7278 chip Sandstone, fine with some medium, firm, si. Calc qtz/chert, dark lithics ? and accessories, minor biotite. 10% scattered very pale yellow fluor, instant pale yellow cut flour, weak odor, No stain, no visible cut. ICore Number Chips from end of 3' aluminum sleeve barrel Core #1 AR3B-2389-B ARCO Alaska, Inc. ,,. ~ ~,,-,,~' Core Description Report Operator and Well Name :~age of ARCO Meltwater South # 1 I 1 Location Date North Slope, Alaska 2 / 4 / 99 Core Number Interval I Cut Recovered Core # 2 7370.5 - 7408 Depth Thickness Description 7370.5 Chips Sandstone and siltstone Sandstone, very fine, light to medium grey, salt & pepper, no visible porosity Calc. Cement, 20% qtz, 30% chert 50% lithics and others, NSO, trace residual rim 7373 Chips Sandstone, very fine to silty, light to medium grey, no visible porosity, Calc. Cement, 20% qtz, 30% chert, lithics and silty, very slow crush cut (Milky yellow)fluor 7376 Chips Siltstone, silt occ very fine sand, medium grey, tr organics particles Trace calc. Cement, NSOCF 7378.6 Chips Sandstone, very fine to silty, light to medium grey, no visible porosity, tr Calc. Cement, Tr pin-point fluor - possible mineral flour, tr pale straw crush cut fluor, no stain or cut. 7381 Chips Shale and siltstone Dark grey shale, hard slightly calc. Medium grey sandstone, w/scattered organic frags, no shows 7384 Chips Sandstone, very fine, light grey, hard, slightly calcareous, tight, 50% qtz/chert, 45% lithics and others, 5% biotite. NSOCF 7387 Chips Silty sandstone, very fine, light grey, hard, mod calc., organic frags concentrated in one area. No fluor. 7390 Chips Shale, dark grey, organic fragments scattered throughout, mod calc. 7393 Chip Siltstone, medium grey, hard, moderate calc.~ scattered organic fragments. 7396 Chips Sandstone, very fine, light grey, hard, moderate calc, salt & pepper, mod calc, NSOCF 7399 Chips Siltstone, dark grey, hard, silty, mod. Calc, NSOCF 7402 Chips Sandstone, very fine, light grey, hard, moderate calc, salt & pepper, NSOCF 7405 Chips Shale, dark grey, scattered organic fragments, mod calc. 7408 Chips Sandstone, very fine, silty, light grey, hard, moderate-very calc, salt & pepper, some biotite and organic fragments NSOCF Wood /Bannan Chips from 3' end pieces of core in aluminum sleaves AR3B-2389-B ICore Number Core # 2 COMPANY: ARCO ALASKA, INC, Well: Meltwater South # 1 Core # 1 7278.00 - 7370.50 ft Profile Permeabilit_~ Date 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 31 32 33 35 37 39 40 41 42 43 7278.18 0.05 0.02 7278.40 0.05 0,02 7278.60 0.05 0,02 7278.80 0.04 0.02 7278.99 0.06 0,03 7279.21 0.07 0.03 7279,40 0,09 0.04 7279,61 0,06 0.03 7279,80 0.05 0,02 7280.01 0.05 0,02 7280.20 0.09 0.04 7280.41 0.10 0,05 7280,60 0.11 0.06 7280.80 0,07 0.03 7281.15 0.07 0.03 7281,41 0.08 0.04 7281.60 0.09 0.04 7281,80 0,10 0,05 '" 7282,01 0.10 0.05 '7282.22 0.04 0.01 7282.41 0.09 0.04 7282.65 0.08 0.03 7282.81 0.06 0.03 7283.00 0.03 0,01 7283.19 0.03 0,01 7283,48 0.02 0,01 7283,60 0.02 0.01 7283.91 0.06 0,02 7284.19 0.06 0,02 7284,47 0,05 0.02 7284.60 0.08 0.04 7284.81 0.04 0,02 7285.02 0.04 0.01 7285.21 0,06 0,02 7285.41 0.04 0.02 7285.59 0.05 0,02 7285.80 0.03 · 0.01 7286.01 0.07 0,03 7286.20 0.06 0.02 7286,39 0.08 0,04 7286.60 0,06 0,02 7286,79 0.08 0,04 7286.94 0.05 0.02 44 7287,19 0,14 0.07 45 7287.41 0,12 0,06 46 7287.61 0.12 0.06 47 7287,81 0,12 0,06 48 7288,00 0.09 0.04 49 7288,20 0.07 0,03 50 7288.40 0,09 0,04 51 7288.62 0,06 0.03 52 7288,79 0,06 0.03 53 7289,00 0.05 0.02 54 7289.20 0.05 0.02 55 7289.40 0,06 0.03 56 7289.60 0,07 0,03 57 7289.80 0,06 0.03 58 7290.20 0.10 0,05 59 7290.43 0,12 0.06 60 7290,60 0.10 0.05 61 7290,82 0,11 0.05 62 7291.01 0,08 0.04 63 7291.20 0.06 0.03 64 7291.40 0.07 0,03 65 7291.70 0.04 0,02 66 7291.89 0.07 0.03 67 7292,00 0,11 0,05 68 7292.21 0.10 0.05 69 7292,40 0,11 0.05 70 7292,61 0,08 0.04 71 7292,81 0.09 0.04 72 7292.93 0,04 0,02 73 7293,23 0,04 0,02 74 7293,40 0,04 0.01 75 7293,60 0,04 0.02 76 7293.81 0,07 0.03 77 7294,00 0.06 0.02 78 7294,21 0,06 0.03 79 7294,40 0,03 0.01 80 7294.60 0,08 0.04 81 7294.78 0,01 0,00 82 7295.00 0,05 0.02 83 7295,24 0.02 0,01 84 7295.40 0,05 0,02 85 7295,58 0,07 0,03 86 7295,86 0,06 0,03 Page I Profile Permeability Data COMPANY: ARCO ALASKA, INC. Well: Meltwater South # 1 Core # 1 7278.00 - 7370.50 ft III 87 7296.22 0.06 0.03 88 7296.40 0.07 0.03 89 7296.60 0.09 0.04 90 7296.80 0.06 0.03 91 7297.07 0.05 0.02 92 7297.18 0.07 0.03 93 7297.38 0.09 0.04 94 7297.60 0.08 0.03 95 7297.80 0.06 0.02 96 7297.99 0.06 0.03 97 7298.20 0.03 0.01 98 7298.40 0.07 0.03 99 7298.60 0.08 0.03 100 7298.80 0.07 0.03 101 7298.95 0.09 0.04 102 7299.21 0.15 0.08 103 7299.40 O. 19 O. 10 104 7299.60 0.15 0.08 105 7299.80 0.11 0.05 106 7300.00 0.10 0.05 107 7300.20 0.11 0.05 108 7300.41 0.14 0.07 109 7300.60 0.10 0.05 110 7300.80 0.14 0.07 111 7300.99 0.09 0.05 112 7301.20 0.08 0.03 113 7301.44 0.02 0.01 114 7301.60 0.05 0.02 115 7301.80 0.04 0.02 116 7301.96 0.06 0.03 117 7302.21 0.09 0.04 118 7302.40 0.10 0.05 119 7302.60 O. 10 0.05 120 7302.80 0.11 0.05 121 7303.00 0.08 0.03 122 7303.20 0.04 0.02 123 7303.40 0.05 0.02 124 7303.59 0.09 0.04 125 7303.79 0.18 0.10 126 7304.00 0.41 0.26 127 7304.22 0.31 0.19 128 7304.41 0.43 0.28 129 7304.60 0.33 0.20 130 7304.81 0.07 0.03 131 7304.99 O. 11 0.05 132 7305.13 0.12 0.06 133 7305.40 0.07 0.03 134 7305.59 0.09 0.04 135 7305.80 0.09 0.04 136 7306.03 0.21 0.12 137 7306.22 0.15 0.08 138 7306.39 0.15 0.08 139 7306.60 0.18 0.10 140 7306.80 0.15 0.08 141 7306.98 0.05 0.02 142 7307.22 0.05 0.02 143 7307.39 0.09 0.04 144 7307.59 0.12 0.06 145 7307.76 0.12 0.06 146 7307.93 0.13 0.06 147 7308.18 0.17 0.09 148 7308.44 0.17 0.09 149 7308.84 0.09 0.04 150 7309.00 0.10 0.05 151 7309.17 0.14 0.07 152 7309.40 0.07 0.03 153 7309.60 0.06 0.03 154 7309.80 O. 14 0.07 155 7310.03 0.06 0.03 156 7310.20 0.05 0.02 157 7310.40 0.03 0.01 158 7310.60 0.07 0.03 159 7310.79 0.05 0.02 160 7310.94 0.08 0.04 161 7311.20 0.05 0.02 162 7311.41 0.06 0.03 163 7311.60 0.04 0.02 164 7311.79 0.08 0.04 165 7312.00 0.16 0.08 166 7312.20 0.18 0.10 167 7312.40 0.12 0.06 168 7312.60 0.14 0.07 169 7312.81 0.17 0.09 170 7313.03 0.13 0.07 171 7313.20 0.11 0.05 172 7313.53 0.17 0.09 I i i Page 2 COMPANY: ARCO ALASKA, INC. Well: Meltwater South # 1 Core # 1 7278.00 - 7370.50 ft Profile Permeability Data 173 7313.66 0.09 0.04 174 7313.81 0.09 0.04 175 7314.20 0.08 0.04 176 7314.40 0.13 0.06 177 7314.60 0.13 0.07 178 7314.80 0.15 0.08 179 7314.99 0.15 0.08 180 7315.20 0.12 0.06 181 7315.44 0.13 0.07 182 7315.60 0.19 0.10 183 7315.80 0.22 0.13 184 7315.94 0.17 0.09 185 7316.11 0.07 0.03 186 7316.20 0.08 0.03 187 7316.37 0.08 0.04 188 7316.59 0.14 0.07 189 7316.79 0.11 0.06 190 7316.93 0.15 0.08 191 7317.20 0.17 0.09 192 7317.39 0.21 0.12 193 7317.60 0.16 0.09 194 7317.81 0.16 0.09 195 7318.00 0.27 0.16 196 7318.17 0.28 0.17 197 7318.39 0.18 0.10 198 7318.60 0.16 0.08 199 7318.77 0.06 0.03 200 7318.99 0.10 0.05 201 7319.20 0.14 0.07 202 7319.40 0.22 0.12 203 7319.60 0.22 0.12 204 7319.79 0.11 0.06 205 7319.96 0.03 0.01 206 7320.20 0.23 0.13 207 7320.40 0.10 0.05 208 7320.60 0.14 0.07 209 7320.80 0.20 0.11 210 7321.00 0.12 0.06 211 7321.24 0.12 0.06 212 7321.41 0.03 0.01 213 7321.63 0.01 0.00 214 7321.81 0.07 0.03 215 7322.02 0.03 0.01 216 7322.20 0.08 0.04 217 7322.35 0.10 0.05 218 7322.73 0.11 0.06 219 7323.20 0.07 0.03 220 7323.~ 0o 11 0.05 221 7323.83 0.05 0.02 222 7324.00 0.08 0.04 223 7324.20 0.09 0.04 224 7324.62 0.23 0.13 225 7324.78 0.06 0.02 226 7325.04 0.06 0.02 227 7325.23 0.19 0.10 228 7325.40 0.11 0.06 229 7325.60 0.20 0.11 230 7325.80 0.16 0.09 231 7325.96 0.10 0.05 232 7326.20 0.17 0.09 233 7326.40 0.30 0.18 234 7326.60 0.24 0.14 235 7326.81 0.32 0.19 236 7327.00 0.20 0.11 237 7327.20 0.28 0.17 238 7327.42 0.24 0.14 239 7327.60 0.27 0.16 240 7327.80 0.17 0.09. 241 7328.07 0.27 0.16 242 7328.23 0.29 0.17 243 7328.40 0.27 0.16 244 7328.64 0.07 0.03 245 7328.86 0.17 0.09 246 7329.19 0.02 0.01 247 7329.47 0.17 0.09 248 7329.63 0.02 0.01 249 7329.64 0.08 0.04 250 7330.02 0.11 0.06 251 7330.20 0.04 0.01 252 7330.43 0.03 0.01 253 7330.60 0.22 0.13 254 7330.86 0.08 0.04 255 7331.03 0.17 0.09 256 7331.20 0.12 0.06 257 7331.40 0.07 0.03 258 7331.61 0.27 0.16 Page~~-- ~ COMPANY: ARCO ALASKA, INC. Well: Meltwater South tt 1 Core il I 7278.00 - 7370.50 ft Profile Permeability Data 259 7331.80 0.26 0.15 260 7332.20 0.21 0.12 261 7332.38 0.31 0.18 262 7332.60 0.23 O. 13 263 7332.80 0.20 0.11 264 7333.00 0.03 0.01 265 7333.20 0.09 0.04 266 7333.40 0.19 0.10 267 7333.60 0.23 0.13 268 7333.80 0.21 0.12 269 7334.00 0.29 0.17 270 7334.19 0.18 0.10 271 7334.35 0.22 0.12 272 7334.61 0.26 0.16 273 7334.80 O. 14 0.08 274 7334.94 0.13 0.07 275 7335.20 0.25 0.15 276 7335.40 0.19 0.10 277 7335.60 0.22 0.12 278 7335.80 O. 11 O. 05 279 7336.00 0.09 0.04 280 7336.18 0.23 0.13 281 7336.37 0.10 0.05 282 7336.66 0.07 0.03 283 7336.81 0.18 0.10 264 7337.07 0.06 0.03 285 7337.20 0.05 0.02 286 7337.40 0.06 0.02 287 7337.56 0.14 0.07 288 7337.85 O. 15 O. 08 289 7337.96 0.11 0.06 290 7338.10 0.09 0.04 291 7338.21 0.05 0.02 292 7338.42 0.03 0.01 293 7338.56 0.05 0.02 294 7338.83 0.09 0.04 295 7339.01 0.06 0.03 296 7339.19 0.06 0.03 297 7339.39 0.07 0.03 298 7339.63 0.04 0.02 299 7339.91 0.07 0.03 300 7340.04 0.07 0.03 301 7340.20 0.17 0.09 302 7340.42 0.06 0.02 303 7340.61 0.01 0.00 304 7340.77 0.10 0.05 305 7340.92 O. 11 0.06 Page 4 MEMORANDUM State of Alaska Alaska.Oil and Gas Conservation Commission TO: Robed Christenson~ DATE: February 13, 1999 Chairman THRU: BlairWondzell, ~ FILE NO: P. I. Supervisor ~.(eS'f'~?~ FROM' Lou Grimaldi,/)~ SUBJECT: Petroleum Inspector Y99JBMNGF. DOC Surf. Plug & Cap Inspection Meltwater South #1 Arco Alaska Tarn exploratory PTD# 99-006 Saturday, February 13, 1999; I inspected the surface plug and cap on Arco's exploratory well, Meltwater South #1. I arrived location to find a 16" casing stub with a 9 5/8" stub inside cut-off approximately four feet below tundra level. The 9 5/8" casing had firm cement approximately 2 feet from the surface. The 9 5/8" by 16" annulus had what appeared to be dehydrated mud at surface. I obtained a short length of 1/2" rod and attempted to find cement below the mud with no success. A length of 3/4" pipe was brought out and drove to approximately 6 feet where it fetched up solid. Upon withdrawing the pipe a section of cement was stuck inside the pipe. The mud inside the annulus was dug out as deep as possible and both casing strings were filled with dry cement. The marker plate was welded on in such a manner as to prevent fluid transition. The hole was filled in with the original dirt and tundra from when the Conductor was drilled. I advised Mike Whitely (Arco drilling foreman) that a Location Clearance inspection would be required this summer before a clearance would be granted. SUMMARY: I made a inspection of the surface plug and marker plate on Arco's exploratory well, Meltwater South #1 in the Tarn exploratory area. Attachments: Y99JBMGF.xls Meltwater Southla.jpg Meltwater South 1 b.jpg Meltwater South 1 c.jpg CONFIDENTIAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment / Location Clearance Report ( Title 20 AAC 25, Article 2 ) Operator: Arco Alaksa Address: Surface Location: 671 F N L, 1748 F W L Section # ,T 7N ,R 7E ,M U Well Name: Meltwater South #1 PTD No.: 991006 APl No. 50- 287-200'14 Unit or Lease Name: ADL 38+9047 ALK 4994 Field and Pool: Tarn ExpL Downhole P&A Date: ~ Operator: Arco Alaska Well Name: Meltwater South #1 Surface Location: 671 F N L, 1748 Section # ,T 7N Inspection D [i~ ~iil Approval Date: Steel Post OD: (4" min) NO POSt "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 ? All openings closed ? With Marker Plate Diameter: 16 "Thickness: 0.5 "Distance Below Final Grade Level: 4 ft. Marker Plate Attached To: Wellhead Cutoff Csg X Other Information Beadwelded Directly to Marker Post or Blind Marker Plate: ( Note when different from file information) Unit / Lease Name: None Remarks: APl # beaded on plate Inspection Date: PITS: F W L ,R7E ,M U Approval Date: Filled In: Liners Removed or Buried: Debris Removed: SURFACE CONDITION OF PAD AND / OR LOCATION: ( Rough, Smooth, Contoured, Flat, Compacted ) Clean: Type & Quan. of Debris if any remaining on pad and / or location: TYPE AND CONDITION OF SURROUNDING AREA: (Wooded,Tundra,Grass,Brush,Dirt,GraveI,Sand) Clean: Type & Quan. of Debris if any remaining on surrounding area: TYPE AND CONDITION OF ACCESS ROAD AND SURROUNDING AREA: ( Dirt, Gravel, Ice, Other) Clean: Type & Quan. of Debris if any remaining on access road or surrounding area: CLEANUP WORK REMAINING TO BE DONE: RECOMMENDED FOR APPROVAL OF ABANDONMENT: Distribution: Reason: orig - Well file c - Operator c - Database c - Inspector FI-000 (Rev. 3/93) Yes No X Surface inspection needed in summer. ( If "No" See Reason ) FINAL INSPECTION: Yes INSPECTED BY: Lou Grimaldi Y99JBMGF.xls No DATE: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson,Q~,~ DATE: February 12, 1999 Chairman ¥, THRU' Blair Wondzell, ,d~~ FILE NO: P. I. Supervisor ,2.1~'~'f~/ FROM: Lou Grimaldi,l~'~o.~ SUBJECT: Petroleum InslSector C99JBKNGF.DOC Casing Shoe Plug Inspection Meltwater South #1 Arco Alaska Tarn exploratory Thursday, February 11, 1999; I witnessed the placement of the retainer and cement plug at the casing shoe for abandonment on Arco's exploratory well, Meltwater South #1. I arrived location to find the rig still coming out of the hole after placing the open- hole plugs. A HES squeeze packer was picked up and ran to 2498' RKB (shoe @ 2548' RKB) the packer set properly and 30K was set down on the packer. 18.5 barrels of 15.8 ppg "G" cement was pumped through the packer. The running tool was unstung and 8 bbls of cement was laid on top. During this time the mud level in the stack acted properly with no increase observed during the pumping under the packer and returns were taken during the top portion. SUMMARY: I witnessed the placement of a cement plug (through retainer) at the casing/open hole shoe on Arco's exploratory well, Meltwater South #1 in the Tarn exploratory area. Attachments: None CONFIDENTIAL ARCO Alaska, Inc. Location: FAX #: I:l · Il I ~1s41 41 II II II I II !! · ti " :" lB !1 ii II i! lWm~ .. Kuparuk Development 'P. O. BOX '~ 00360 ANCHORAGE, AK 99510-0360 FAX # 907 265-622.4 ATO-1279 . Subject: Comments: ...L l,ll i, -- .__ Revised 2-9-99 B.K. MWS 1 Expl Dean ~ WELLBORE CONFIDENTIAL .SCHEMATIC. and emen! I-' ancl A Plan 16" ~ ~ 300' Cmt Plug @ 135 sacks Arctic Set 1 Slurry Volume Conductor Surface-300' MD Slurry Weight Slurry Yield Thickening Time Port Collar ~1000' MD 132,6 cu-ft 15.7 ppg 0,93 cu-ft/sk 2.2 - 2.8 hours 12-1/4" Hole 9-5/8" $ u rfa.?~._~ 2548' MD Cemented with 600 sx AS3 Lite. 340 sx G 200' Cmt Pluq ~ 2448'-2658' MD (50'above and 150' below Ret, 2498') · 200' CmtPluq(~ 3370'-3570° MD 100 sacks Class G cement + 0,2% D46 AntiFoam 0,3% I;)65 Dispersant + 1,0% S1 CaCI2 Accel. 35 Sacks above retainer 65 sacks below retainer Slurry Volume (1 '1.5" O1-1 on Caliper log) Slurry Weight Slurry Yield Thickening Time 75 degF 113.2 cu-ft 15,8 ppg 1.17 cu-ft/sk 3.0 - 3.5 hours 105 sacks Class G cement + 0,2% D46 AnfiFoam + 0,2% D65 Dispersant Slurry Volume 10.5" OH on Caliper log 120.3 cu-ff Slurry Weight 15.8 ppg Slur. ry Yield 1.17 cu-fflsk Thic~;ening Time 95 degF 3.0 - 3.5 hours 8-1/2" Hole OH Caliper log_ used to Calculate Cement Volum~..s 9.8 ppg Mud between plugs TD at 8935' MD 300' Cmt Pluq~ 3700'-4000'MD 1815' Cmt Piuq ~ 7120L8935' MD Set in 3 Plu~s 155 sacks Class G cement + 0,2% D4§ AntiFoam + 0,2% D65 Dispersant Slurry Volume 10,5" OH on Caliper log Slurry Weight Slurry Yield Thickening Time 95 degF ~ sacks Class G cement 4- 0.2% D46 AntiFoam + 0.2% D65 Dispersant + 0.49 % DS00 Retarder Slurry Volume (gauge 8,5" Hole on Caliper log up to 7400', 9.5" OH above 7400') Slurry Weight Slurry Yield Thickening Time, 165 degF BHCT 180,4 cu-ff 15,8 ppg 1,17' cu-ft/sk 3,0 - 3.5 hours 742.7 cu-ft 15.8 ppg 1.17 cu-ft/sk 4,0 - 4.5 hours . Meltwater South #1 Final P&A CONFIDENTIAL Notify AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pm-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. Mobilize and rig up DIS for well P&A operation. Spot a balanced cement plug #1from TD @ 8935'MD to 7120'MD (.100' above top of the Bermuda interval). This plug can be laid in three sections as needed. Total interval is 18'15' in length. (Top stain at 7222' MD-very tight) Will net need to tag the plug, as we are setting the plug from TD of the well, ~v.. ~ Spot a balanced cement plug #2 across the interval from 4000'MD to 3700'MD (300') leaving 9.8 ppg mud in the lower section of hole, (Stains from 3920' to 3940' MD-very tight) Not required to tag the plug. ~::)k..,EJ).a,C.. Spot a balanced cement plug #3 across the interval from 3570'MD to 3370'MD (200') leaving 9,8 ppg mud in the lower section of the hole. {Stains from 3480' to 3510' MD- very tight) Not required to tag the plug, or- ~~ By the down squeeze method through a retainer set 50' minimum above the shoe (or approx. 2498') pump cement plug #.4 as per AOGCC regulations. Pump sufficient cement through the retainer to extend 150' below and lay a 50' cement cap on top of the retainer. Weight test retainer before pumping cement. Not required to tag ~e plug. Leave 9.8 ppg mud above and below the plug. o~ ~ Spot a balanced Arctic ,Set I cement plug #5 from 300' to surface. Clear lines and shut down pumps, Rig down cementing unit and clean up. ~)wl~o~J' Cut off wellhead and all casing strings at 3 feet belo und level. Send casing head with stub to Materials for repair / re-dressing. 10. Weld cover plate over all casing strings with the following information bead welded into the top: ARCO ALASKA, INC '~ Meltwater South #1,,~ ~ APl# 60-287-20014 O~ (~ 11. Remove cellar, Back till cellar with gravel as needed. Back till remaining hole to ground level with gravel. Clear ice pad location and demob all materials and equipment. TJB 219/99 File:MWS#'I Procedures based on conversations between Paul Maz. zolini and Blair Wondzell 2/9199. Exploration/Tarn Team Leader MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christensor~/~/~ DATE: February 4, 1999 Chairman 'tv THRU: Blair Wondzell, .~J~ P. !. Supervisor FROM: Lawrence M Wade ~ SUBJECT: Petroleum Inspector FILE NO: a9ngbdgf. DOC BOP Test Doyon 141 Meltwater South #1 PTD 99-006 FebruarY 471999: I drove to Meltwater South #1 to witness a BOP test. The lower pipe rams would not pass the pressure test. They were replaced and passed. We also froze up the kelly testing the kelly valves. The location was orderly and clean. Due to other Doyon rigs being shut down, the crews are getting used to working with each other. SUMMARY: I witnessed a BOP test on Doyon 141, 0 failures,5 hours. Attachments: a9ngbdgf, xls NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Doyon Operator: ARCO Well Name: Meltwater South #1 Casing Size: g 5/8" Set (i~ Test: Initial Weekly Rig No. 141 PTD# Rep.: Rig Rep.: 248 Location: Sec. X Other DATE: 2/4/99 99-006 Rig Ph.# 263-3140 Mike Whitely Mark E~holm 33 T. 7N R. 7E Meridian Test Pressures 250/5000 Umiat Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gan) PTD On Location X Standing Order Posted. X Well Sign X Drl. Rig X Hazard Sec. X . FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. 1 Pressure P/F 250/5000 P 250/5000 P 250/5000 250/50O0 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F f P 1 250/'5000 P I 250/5000 250/3500 250/5000 250/5000 250/5000 25O/5O0O F Test CHOKE MANIFOLD: Pressure P/F No. Valves f4 i 250/5000 P No. Flanges 28i 250/5000 I5' Manual Chokes 1 FuncUoned P Hydraulic Chokes f Functfoned P ACCUMULATOR SYSTEM: 250/5000 System Pressure 3,150 I .,, Pressure After Closure 1,850 I MUD SYSTEM: Visual Alarm 200 psi Attained After Closure .___.-- minutes 36 . sec. Trip Tank X X System Pressure Attained 3 minutes 15 sec. Pit Level Indicators X X Blind Switch Covers: Master: X Remote: X Flow Indicator X X Nitgn. Btl's: 1950-2000-2000-1950 Math Gas Detector X X " Psig. H2S Gas Detector X X Number of Failures: f ,Test Time: 4.5 Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within days. Notify the inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Lower Pipe rams failed. Replaced and passed. Distribution: orig-Weli File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO I Waived By: Witnessed By: Larry Wade F1-021L (Rev. 12/94) a9ngbdgf, xls MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenso~[~ DATE: January 28, 1999 Chairman ' I~/~'- THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor FROM: Chuck $cheve, d ~g SUBJECT: Petroleum Inspector a9wka2ge.doc BOPE Test Doyon 141 Meltwater South #1 PTD # 99-006 Thursday, January 28, 1999: I traveled to Arco's Meltwater South #1 exploratory well being drilled by Doyon Rig 141 and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE test report shows, the test lasted 8 hours with 2 failures. The upper pipe rams (3 x 6 VBRs) failed to pressure test; these were replaced with a regular set of 5"ram blocks which tested OK. The manual valve on the choke side of the BOP failed to pressure test, this valve was replaced and the new valve passed it's test. The testing went well with the exception of the above mentioned failures. Good test procedures employed by the Doyon crews allowed completion of the test in a minimum number of steps. The rig was clean and all related equipment appeared to be in good working order. The location was well organized allowing good access to the rig. Summary: I witnessed the initial BOPE test on Doyon Rig 141 drilling Arco's Meltwater South #1 Well. Doyon 141, 1128199, Test time 8 hours, 2 failures Attachment: a9wka2ge.xis Unclassified Confidential (Unclassified if doc. removed ) X Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: DATE: 1/28/99 Drlg Contractor: Do¥on Rig No. 141 PTD # 99-006 Rig Ph.# 263-3140 Operator: ARCO Rep.: Ray Springer Well Name: Meltwater South#1 Rig Rep.' Pat Karupa Casing Size: 9 5/8 Set ~ 2548 Location: Sec. 33 T. 7N R. 7E Meridian Test: Initial X Weekly Other UM Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F Location Gen.: OK Well Sign OK Upper Kelly / IBOP I I 250/5000 P Housekeeping: OK (Sen) Drl. Rig OK Lower Kelly / IBOP I ! 250/5000 P PTD On Location YES Hazard Sec. OK Ball Type I 250/5000 p, Standing Order Posted YES Inside BOP 1, 250~5000 P BOP STACK: Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves 1 HCR Valves Kill Line Valves Check Valve Quan. Test Press. 250/3500 250/5000 250/5000 250/5000 250/5000 2 25015000 I 250/5000 N/A P/F P F/P P P F/P P P MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK CHOKE MANIFOLD: No. Valves 14 No. Flanges 28 Manual Chokes 1 Hydraulic Chokes I Test Pressure P/F 250/5000 IP 250/5000] IP Functioned I P Functioned I P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3100 1800 minutes 30 sec. ,, 3 minutes 12 sec. OK Remote: OK 5 ~f~ 2000 Psi Psig. Number of Failures: 2 ,Test Time: 8.0 Hours. Number of valves tested 23 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: The upper pipe rams (3x6 VBRs) failed to pressure test and were replaced with 5" rams The manual valve on the choke side of the BOP stack failed to pressure test and was replaced. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector F1-021L (Rev.12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Chuck Scheve ARCO Alaska, Inc. Post Office Box%~,~60 Anchorage, Alaska 99510-0360 January 26, 1999 Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Meltwater South # 1 Confidentiality Dear Blair: Based on your telephone conversation 1/26/99 with Tom Brassfield, ARCO requests the highest level of confidentiality allowed under the AOGCC regulation 20.AAC 25.537 for our Meltwater South # 1 Exploration well. This includes any information associated with the original filing of the permit to drill for this well plus any information associated with future submissions including the weekly updates. ARCO will consider the option of requesting "Indefinite Confidentiality" via the DNR beyond the 24 months following the 30-day filing period after abandonment as allowed by 20.AAC 25.537. Thanks once again for your support and guidance in this matter. Sincerely, Paul Mazzolini Drilling Team Leader Exploration/Tam Team Leader RECEIVED JA ! 27 1999 Naska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION January 21, 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Paul Mazzolini Tarn Drilling Team Leader ARCO Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Meltwater South # 1 ARCO Alaska, Inc. Permit No: 99-006 Sur. Loc. 671'FNL, 1748'FWL, SEC 33, T07N, R07E. UM Btmhole Loc. 238'FNL, 405'FEL, SEC 32, T07N, R07E, UM Dear Mr. Mazzolini: Enclosed is file approved application for permit to drill file above referenced well. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure tlmt the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to fl~e Commission on form 10-403 prior to fl~e start of disposal operations. Your request for annular disposal down anofl~er Kuparuk well open ,annulus will only be considered after receipt of the written application which complies with 20 AAC 25.080(d) The permit to drill does not exempt you from obtaining additional permits required by law from other govermnental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the xvell is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Cmmnission'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 Conunission may witness the test. Notice may be given by contacting the Commission,laetroleum field inspector on the North Slope pager at 659-3607. · Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & G,'une. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ._. STATE OF ALASKA AL~A OIL AND GAS CONSERVATION COMe'SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory X Stratigraphic Test [] Development Oil Re-Entry [--] Deepen E~ Service [--~ Development Gas [--1 Single Zone Multiple Zone X "2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 504' feet '3. Address 6. Property Designation Tarn Expl. P. O. Box 100360, Anchorage, AK 99510-0360 ADL 389047 ALK 4994-~' '4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 671' FNL, 1748' FWL, Sec. 33, T7N, R7E, UM N/A Statewide At top of productive interval (@ TARGET ) 8. Well number Number 238' FNL, 405' FEL, Sec. 32, T7N, R7E, UM Meltwater South #1 #U-630610 At total depth 9. Approximate spud date Amount 238' FNL, 405' FEL, Sec. 32, T7N, R7E, UM 1/24/99 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line Wolfbutton 32-7-8 MD 8809' 238' @ TD feet 5.1 Miles feet 2,560 TVD 8377' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 24° Maximum surface 1659 psig At total depth (TVD) 4792 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" Welded 80' 28' 28' 118' 118' +/- 200cf 12W' 9-5/8" 40 ppf L-80 BTC 3076' 28' 28' 3104' 2932' 590 sx AS3 plus 340 sx OI G 81/2" 7" 26 ppf L-80 BTC-M 8781' 28' 28' 8809' 8377' 235 sx CIG 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet0P, I INAL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Sot°r~CdtuU°r~°lr R E C E IV E D Surface Intermediate Production Liner,JAN 14 1999 Perforation depth: measured true vertical .J~J;~ 0ii & Gas Cons, Commission Aprhnrnq(~ 20. Attachments Filing fee X Property plat [] BOP Sketch X .......... ~ Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot X Refraction analysis E~ Seabed report [-~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~"~~( --~)/~"~z~~ Title Tarn Drilling Team Leader Date I/I'~r /Cjc~j Commission Use Only Permit Number I AP, number IAppr°valdate l--o~J--9~ J See cover letter for ~ C~--. (~ ~ ~:~ 50- ~, '?' ~ 0 ~:~ I ~ other requirements Conditions of approval samples required [~' Yes r-'] No Mud log required J~ Yes r-~ No Hydrogen sulfide measures r-~ Yes ~[~No Q Directional survey required ~' Yes [-'] No Required working pressure for DOPE 2M r-~ 3M E~] r"] 10M [] 15M Other: ORIGINAL SIGNED' BY by order of Approved by Robert N. Chdstenson Commissioner the commission Date / '"'c~ !"~? Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. ~V Post Office Box '100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 13,1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill ARCO Meltwater South #1 Surface Location: 671' FNL, 1748' FWL, Sec. 33, T7N, R7E, UM Target & BHL: 238' FNL, 405' FEL, Sec. 32, T7N, R7E, UM Dear Commissioner Christenson: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratOry well, the Meltwater South #1, located approximately 18 miles south of the Kuparuk River Unit's 2N Pad. This well will be accessed via ice read originating near 2N Pad, drilled using Doyon Rig #141, tested and permanently abandoned prior to spring breakup. Attached is the information required by 20 ACC 25.005 (c) for your review. Other pertinent information attached to this application is confidential data including the following: '1) Pressure information as required by 20 ACC 25.035 (d) (2). 2) Prediction of overpressured strata as required by 20 ACC 25.033 (e). There are no shallow hazards expected at Meltwater South #1 (see attached graph). The nearest offset wells indicate no overpressured intervals or lost circulation zones. There will be no reserve pit for this well. Waste drilling mud will be hauled to a KRU Class II disposal well. If a production casing string is set in this well ARCO requests that Meltwater South #1 be permitted for annular disposal of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As in the past ARCO would submit a 10-403 Form to the Commission with the appropriate technical information. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. Please note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment operating, as is the usual case while drilling wells in and near the Kuparuk River Field. If you have any questions or require any further information, please contact me at 263-4603 or James Trantham at 265-6434. Sincerely, Paul Mazzolini Drilling Team Leader Exploration/Tarn Team Leader Attachments cc: Meltwater South #1 Well File RECEIVED ,JAN 14 1999 Alaska 0ii & Gas Cons, Commission ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company GENERAL DRILLING PROCEDURE ARCO Meltwater South #1 . . . . o 10. 11. 12. 13. Move in and rig up Doyon #141 over pre-installed 16" conductor casing. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (3104' MD) according to directional plan. Run and cement 9-5/8" 40# L-80 BTC Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 9-5/8" casing at approx. 1000' 'I'VD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage~ or..~) p ;:cement job. ~ ~/~,¢~ Install and test BOPE to ~psi'¢-Test~;casing to 2,500 psi. Drill out cement and 10' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW) Drill 8-1/2" hole to 8809' MD TD, coring as necessary, according to directional plan (if applicable). Run open hole evaluation logs. If the well is to be tested, run 7", 26#, L-80, BTC-M production casing. Go to step 10. Pressure test casing to 3500 psi. If the well will not be tested, P&A it per AOGCC regulations. Go to step 14 Complete the well with 3-1/2", 9.3#, L-80, EUE 8rd tubing. ND BOPE. NU upper tree and test to 5,000 psi. Shut in and secure well. RDMO Doyon #141. Hook up well for flow testing to surface tanks. Produced fluids to be trucked to Kuparuk production facilities. Test zones as appropriate, abandoning each using a CTU. When complete, plug and abandon the well as per AOGCC regulations and RDMO CTU. 14. Thoroughly clean location and block off access ice road. ARCO Meltwater South #1 PRESSURE INFORMATION AND CASING DESIGN (Per 20 AAC 25.005 (c) (3,4) and as required in 20 AAC 25.035 (d)(2)) DISCUSSION The following presents the data used for calculation of the anticipated surface pressures (ASP) used for the design and drilling of Meltwater South #1. .................................................. It ....................... C~i'§ii;i{~'"S'~tfii:i;~""D~"15'[[5 ........................................................................................................ PS'i;'~ ............................................................................................................................................................. Casing I Fracture Pressure Pore ASP Drilling Siz~ i , , Gradient Gradient Pressure .................. · 1'6 ................. ! ........................... ~"1"8' "TVD'7'"I'"I"8 '"'r~D ....................................... ~"1'":'0"'i5'15~ ............................ 8':'5'"i5'15'~ .................................. 52'"'15§i ................................................. N/;~ ............................. ............ 9""5:/'8"' ........... I ..................... 2g'3'2""T~DT"3"~I"0;~'"'MO .................... i ............. ~!"3":'0""i5'15i~ ............................ 9':"0'"'15'15'~ ............................. ~I'3'7'2'"'15'§i ................................ ~l'6'Sg'"'jS§i .................. Expected Maximum Mud Weights: 12-1/4" Surface Hole to 2932' TVD / 3104' MD: 10.0 ppg 8-1/2" Production Hole to 8377' TVD / 8809' MD: 11.2 ppg Procedure for calculating Anticipated 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 = FG = 0.052 = 0.11 = D= Anticipated Surface Pressure in psi Fracture Gradient at the casing seat in lb/gal Conversion factor from lb/gal to psi/ft Gas gradient in psi/ft True vertical depth of casing seat in ft. RKB OR 2) ASP = FPP -(0.11 x D) Where: FPP = Formation Pore Pressure at the next casing point -1- Meltwater South #1 PRESSURE INFORMATIOrq-AND CASING DESIGN ASP Calculations: 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.11] D = [(11 x0.052)-0.11] x 118 - 54 psi OR ASP =FPP-(0.11xD) = 1370 - (0.11 x 2932) - 1047 psi 2. Drilling below surface casing (9-5/8") ASP = [(FG x 0.052) - 0.11]D = [(13.0 x 0.052) - 0.11] x 2,932 = 1,659 psi OR ASP = FPP- (0.11 x D) = 4789 - (0.11 x 8,377) = 3870 psi Casing Performance Properties Internal Size i Weight i Grade Connection Yield Collapse i ......... ;J'iS'i'~'~ i B'~5-~I~) i ......... .......... ........ ................... '~I'6''' .................. .............. 9:5'/8"' ............ ....................... 7'" ...................... i .................. 26'"'i5'i5'f ............. i ........... E:8'0 .................................. BTC':M .................... i ......... 7;2~'0'"i5-§[ ......... i .......... 5'~:;4"~1-0'"'i5§i ........ !'"-6~'¥'l~l-"i-'60'zl:'"'M--i Casing Setting Depth Rationale 16"-118' RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. 9-5~8"-2932' TVD RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling to next casing setting point. 7"-8377' TVD RKB 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. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into the Meltwater South #1 approved annulus or hauled to the nearest permitted Class disposal well. The cement rinseate will not be injected down the dedicated..,,. disposal well but will be recycled or held for the Meltwater Sout lo~ '~,,-,-~.~ annulus or injected down another Kuparuk well open annulus.' The op~ annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The I~eltwater South #! surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. -2- ~ Meltwater South #1 PRESSURE INFORMATIOI~T~AND CASING DESIGN We request that Meltwater South #1 be permitted for annular pumping of fluids (if production casing is set) occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 100' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of.this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,932') + 1,500 psi Max Pressure = 3329 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the casing performance properties above. Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). -3- ARCO Meltwater South #1 PRESSURE ANALYSIS AND PREDICTION (Per 20 ACC 25.005 (c) (7) and 20 ACC 25.033 (e)) DISCUSSION: An analysis and prediction of overpressured strata was performed for the ARCO Meltwater South #1 well as required by AOGCC regulations. ARCO does not expect to encounter abnormal pressure from any zones. The prediction is based on an evaluation of offset wells Ruby State #1, Cirque #2, and Wolfbutton 32-7- 8. Attached are the following: Mud weight versus depth graph for these wells. Seismic analysis for Meltwater South #1. Pore pressure, frac pressure and anticipated mud weight graph. DRILLING FLUIDS PROGRAI~k~ ARCO Meltwater South #1 Drilling Fluid System: 3- Derrick FIo-Line Cleaners Pioneer Model S2-12 Desander Tri-FIo 'Low Profile' Desilter Alpha-Laval Model DMNX 418 Centrifuge Pit Level Indicator (wi visual and audible alarms) Trip Tank Fluid Flow Sensor 8 - Brandt pit stirrers. Drilling Area Risks: Examination of the three nearest offset wells, Ruby State #1, Cirque #2, and Wolfbutton 32- 7-8 reveal no subsurface hazards such as abnormal pressure or lost circulation zones. For the well, MWS #1, seismic analysis is plotted and pore pressure and fracture gradient curves derived. Again, no indications of abnormal pressure or weak formations were seen particularly at shallow depths. The mud weights planned for MWS #1 are conservatively based on those used during drilling of the offsets. Prudent and precautionary drilling/tripping techniques will be emphasized while drilling this well with specific regards to the potential shallow gas hazards which have been encountered in the Tarn wells and in other exploration activities. The 9-5~8" surface casing shoe will be tested to a maximum 16 ppg EMW formation integrity test or leak-off (whichever is least) after drilling 10 feet of new formation. Pore Pressure and Fra~ure Gradient System ~.,,, MEL~ATER_6 NCZ~: 1SO~S D~N ~m ~ RKB,530 ~ ~o~e MS~ ~r I~ IT~e I~; ~ C~ ~; ~L gDP 11~ FEET 10 1000 ~00 40OO ¢0OO 5000 ooO0 rooo 40 80 8o loo 120 140 180 180 NCTL Interoe~ at GL = 1111 Logm~lbmio Slope = -4Jo-If ~pe~ F~n Ted x ~ill ~m Te~ ~du~oe ~eeeure ~ L~-~ Te~ Circu~n Zones - F~on Top Pipe Loo~on % ~d~uk Loe~on 8 0 10 11 12 13 14 15 16 o - ~ ~PLE PPG 17 18 10 20 Pore Pressure and Fracture Gradient System CDP MSL 0.0 111 1111 1111111 111111111111 MELTWATER TRAVERSE LINE ~: PLI~'~;TOCENE 9 9 9 0 0 ? 8 111111111 0 001 1000. 2000J D £ P T H $000~ 7000.0-- 10.50 -- 11.80 -- 11.50 12.00 -- 12.50 9000,0 Meltwater South Depth vs Time -1000 -2000 -3000 -4000 -5000 -6000 -7000 -8000 -9000 MIRU .................~i ..... ?'--:~ '~'---~-~-e~--~:-~,'~,-,__,.: ~ -"'. ---" ..... ~ ..... -" ...... ' ...... " ...... " ...... '---:--~- ..... ~ ..... ' ...... ~' ..... -" ...... " ...... ' ...... " ...... ' ...... ' ...... ' ...... ' ...... '- ..... ~' ................................ :: :: ': :: :: ' ' 'rill 8'-1/2;' ho'lei . - - _- .-_- [] _ © o © o © o o © o © © © o © Days MWS Time-Cost Graph.xls, Time Chart jt 1/12/99 ARCO Alaska, Inc. ~.~ Diverter Schematic Doyon 141 21%" 2,000 psi wP DRILLING SPOOL wi 16" Outlet Flowline ~ 21%" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER I I 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT MANUAL GATE [--J KILL LINE, WP Shaffer GATE VALVE 3" 5,000 psi w/hydraulic actuator 1 DSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi wP Shaffer GATE VALVE [ ~ wi hydraulic actuator ~_L~~cHOKE LINE ~_J~' 5 'M0 -~,0N~jS~, LW(~ AOTCETvA L V E 13-5/8" 5,000 psi WP DRILLING SPOOL I__I ~ w/two 3" 5M psi WP outlets I~SiNGLE 13-5/8" 5,000 psi WP, -J HYDRIL MPL BOP w/pipe rams 400 8O0 1200 1600 2O0O 2400 28OO 3200 3600 4000 4400 4800 52O0 5600 60OO 6400 68O0 7200 7600 8OOO 8400 RKB ELEVATION: 5-32' ARCO Alaska, Structure : Meltwater South //1 Well : MWS//1 Field : Exploration Location : North Slope, Alaska KOP 2,50 5.00 7.50 DLS: 2..50 deg per 100 fl. ,lO.OO <- West (feet) ~12.fi0 = oo ooo , oo , oo ooo o 20.00 dc~ ~ 22.50 Bose Permafrost ,~'~69 ~ Top West Sok Sands ~O % z ~ ~e¢ 200 ~ Bose West Sok Sands c~G ~ ~u~ ~ G~' %oQ ~o~ ~ Loco(ion: " q %09 I 671' FNL, 1748' FWL, [ ~v B/TopS~tS~-9~/8 cscPt Sec. 3~, TTN, R7~ Tie on O.OO 0.00 281,34 O,O0 0.00 0.00 0.00 0.00 C40 KOP 500,00 0.00 281.34 500,00 O.O0 0.00 0.00 0.00 lend of Buhd t467.33 24.18 281.34 1438.87 3g.56 197.20 201.13 2.50 End of Hold 5521.49 24.18 28t.54 5157.22 366.24-1825.571861.95 O.O0 Beg~n Angle Drop4.00 % End of Drop 7133.71 0.00 281.34 6702.00 4~2.~8-2154,242197.17 1.50 22.50 N DLS: 1.5~r 100 f( 21.00 ~ Torge( Meltwo[er South 7385.71 0.00 281.34 6952.00 432.18-2154.242197.17 0.00 11~u~0~Q~' T.D. ~ End of Hold 8808.71 0.00 281.~4 8~77.00 4~2.18-2154.242197.17 0.00 10.50 9,00 7.50 6.0C 4.50 3.0C 1.50 Top Bermuda Target Midpoint B/ Bermuda - T/ C35 Shale Bose C35 Bose Albion End Angle Drop Meltwater South#1 Rvsd 28-Dec-98 7 Casing ,J L TD ~ i , i i i i i I i i i i i i 0 400 800 1200 1600 2000 2400 2800 Vertical Section (feet) -> Azimuth 281..34 with reference 0.00 N, 0.00 E from slot STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE APPLICATION OF ARCO Alaska, Inc. ) for an order granting an exception to the spacing ) requirements of 20 AAC 25.055(a)(1) to ) provide for the drilling of the Meltwater ) South # 1 exploratory oil. ) ) Conservation Order No. 439 Meltwater South #1 January 12, 1999 IT APPEARING THAT: ARCO Alaska, Inc. (AAI) by letter dated December 2, 1998, requested an exception to the well spacing provisions of 20 AAC 25.055(a)(1). The exception would allow drilling the Meltwater South #1 exploratory oil well to a bottomhole location that is closer than 500 feet to a quarter section line. 2. The Commission published notice of opportunity for public hearing in the Anchorage Daily News on December 5, 1998 pursuant to 20 AAC 25.540. 3. No protests to the application were received. 4. AAI in a letter dated January 11, 1999 made a minor revision to the surface and bottomhole locations of the well. FINDINGS: The Meltwater South #1 exploratory oil well will be drilled as a deviated hole from a surface location of 1112' from the north line, 2605' from the west line of Section 33, T7N, RTE, Umiat Meridian ~ to a bottomhole location 113' from the south line, 884' from the east line, Section 32, TTN, RTE, UM. 2. Offset landowner the State of Alaska, Department of Natural Resources has been duly notified. AAI is the owner of all offsetting governmental quarter sections. 3. An exception to the well spacing provisions of 20 AAC 25.055(a)(1) is necessary to allow the drilling of this well. CONCLUSION: Granting a spacing exception to allow drilling of the Meltwater South #I exploratory oil well will not result in waste nor jeopardize correlative rights. Conservation Order January 12, 1999 Page 2 · 439 NOW, THEREFORE, IT IS ORDERED: AAI's application for exception to the well spacing provisions of 20 AAC 25.055(a)(1) for the purpose o£ drilling the Meltwater South #1 exploratory oil well is approved. DONE at Anchorage, Alaska and dated January 12, 1999· Robert N. Christenson, P. E., Chairman Alaska Oil and Gas Conservation Commission Camill~ Oechsli, Commissioner Alaska Oil and Gas Conservation Commission Alaska Oil an~tion Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23~a day following the date of the order, or next working day ifa holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within i0 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the £mal order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 104 day after the application tbr rehearing was filed). ARCO Alaska. Inc. {~, ~..~, ,~,~., 205087499 AAI PAYABLES P.O. Box 102776 Anchorage, AK 99510-2776 PAY TO THE ORDER OF: The First NatiOnal Bank of Chicago-0710 ChicagO; Illinois Payable Through Republic Bank Shelbyville, Kentucky DECEMBER 29, 1998 0997579 ALASKA DEPT OF REVENUE ALASKA OIL :& :GAS CONSERVATION COMMI ~ : $001 PORCUPINE ~DRIVE: · : .... ~ : :.:: :: ~!: .~ .*** VOID AFTER 90 DAYS *** :: :: : · : EXACTLY *********** 100 DOLLARS AND O0 CENTS $*********** 100.00 : . TRACE NUMBER: 205087499 506 ? h q q,' ~:Og 3 qO [, i~ g 2~-' oqq757q,,' /~'C7-'6d/~7"¢/C ,3' ~'/ Mud Weight (lb/gal) ; WI~LL PERMIT CHECKLIST COMPANY ~r1~t,..~.~ WELL NAME l~4~.i~'fe,, ~',~,,tk~-! PROGRAM: exp /~ev ~ redrll serv ~ wellbore seg ann. disposal para req / FIELD & POOL INIT CLASS b,~; t. [ ~ GEOL AREA '~ ~. C~ UNIT# 1. Permit fee attached ....................... ~L N 2. Lease number appropdate ................... (-~ N -i~ c! 'i-~ wtl[ Is ~. 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ADMINISTRATION ENGINEERING DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ,~"~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. ON/OFF SHORE 43 (~N Y(J~. ~)N (~)N (.~N Y N (~N (~N J/DATE ~ ~'"~J ~,~ ~ 34. ANNULAR DISPOSAL 35. APPR DATE Contactnamelphone forweekly progress reports [exploratory only]{~_ With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or ~use drilling waste. to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. ENGINEERING: UIC/Annular COMMISSION.'.~ JDH --"t_,~ ' co Comments/Instructions: GEOLOGY: RPC_~ 0 0 c:\msoffice\wordian\diana\checklist 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. Sperry-Sun Drillin9 Services LIS Scan Utility Sun Mar 07 08:43:11 1999 Reel Header Service name ............. LISTPE Date ..................... 99/03/07 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Tape Header Service name ............. LISTPE Date ..................... 99/03/07 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific RECEIVED Physical EOF Comment Record TAPE HEADER EXPLORATION m~u:)/~su:) LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM- 90071 R. KRELL R. SPRINGER MAR 15 1999 CONFIDENTIAL MELTWATER SOUTH ~1 502872001400 ARCO ALASKA, INC. SPERRY-SUNDRILLING SERVICES 05-MAR-99 MWD RUN 2 MWD RUN 3 AK-MM- 90071 AK-MM- 90071 R. KRELL R. KRELL R. SPRINGER R. SPRINGER JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MM-90071 R. KRELL R. SPRINGER MWD RUN 5 MWD RUN 6 AK-MM-90071 A/f-MM-90071 ' R. KRELL R. KRELL R. SPRINGER M. WHITELY JOB NUMBER: LOGGING ENGINEER: MWD RUN 6 AK-MM-90071 R. KRELL OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD M. WHITELY 33 07N 07E 671 1748 532.60 531.10 505.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 16.000 108.0 3RD STRING 12.250 9.625 2548.0 PRODUCTION STRING 8.500 8935.0 REMARKS: ~ 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RI/NS 1-5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MI/ELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. MWD RUN 6 IS DIRECTIONAL WITH DGR, EWR4, COMPENSATED NEUTRON POROSITY (CNP) AND STABILIZED LITHO-DENSITY (SLD). 4. MWD DATA IN THE CORED INTERVAL 7280'MD, 6723'TVD TO 7409'MD, 6851'TVD WAS OBTAINED ON A MEASUREMENT AFTER DRILLING (MAD) PASS WHILE RUNNING IN THE HOLE ON MWD RUN 6. THIS INTERVAL WAS LOGGED AT LESS THAN 90 FT/HR WHILE ROTATING THE TOOL STRING, AND IS PRESENTED WITH THE MERGED MWD DATA. 5. SLDSLIDE REFERS TO SLD SENSOR DEPTH DURING SLIDE INTERVALS. 6. DIGITAL MWD DATA IS SHIFTED TO THE SCHLUMBERGER PLATFORM EXPRESS GAMMA RAY DATA OF 02/06/99. 7. MWD RUNS 1 - 6 REPRESENT WELL MELTWATER SOUTH #1 WITH API#: 50-287-20014. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8935'MD (8376'Tlr D). SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). '~ SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (RESISTIVITY). SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SS MATRIX FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT P~ATE. SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (BEST BIN). SC02 = SMOOTHED STANDOFF CORRECTION (BEST BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. PARAMETERS USED IN POROSITY LOG PROCESSING:' HOLE SIZE: 8.50" MUD WEIGHT: 9.85 PPG MUD SALINITY: 400 PPM CHLORIDES FORMATION WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type .............. '..LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 70.5 8888.0 FET 80.5 8860.5 RPD 80.5. 8860.5 RPM 80.5 8860.5 RPS 80.5 8860.5 RPX 80.5 8860.5 ROP 96.5 8930.0 FCNT 6974.5 8867.5 NCNT 6974.5 8867.5 NPHI 6974.5 8867.5 PEF 6985.5 8877.5 DRHO 6985.5 8877.5 RHOB 6985.5 8877.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 70.5 2525.0 2536.5 2542.5 2547.0 2554.0 2579.0 2582.5 2587.5 2596.5 2601.0 2617.5 2643.5 2659.5 2667.0 2669.5 2700.5 2720.0 2743.5 2748.0 2753.0 2758.0 2767.0 2770.5 2786.5 2797.5 2800.0 2801.0 2987.5 2991.0 3004.0 3014.0 3038.5 3058.0 3076.5 3084.0 3086.5 3091.5 3109.0 3118.0 3146.5 3150.0 3152.5 3156.5 3163.0 3172.5 3174.0 3176.5 3180.5 3184.0 3185.5 3194.5 3197.0 3'~Ol.O 3206.5 3213.0 GR 80.0 2534.5 2545.0 2554.0 2557.0 2566.0 2590.0 2594.0 2598.0 2606.0 2612.0 2628.5 2655.5 2669.5 2678.5 2680.0 2711.5 2731.0 2753.5 2760.5 2764.0 2771.0 2777.0 2782.5 2799.5 2807.5 2810.5 2812.5 2998.5 3001.0 3018.0 3029.0 3051.5 3066.5 3089.0 3095.0 3100.5 3103.5 3121.0 3130.0 3158.5 3163.5 3166.0 3168.0 3174.5 3184.0 3185.5 3189.5 3194.5 3196.5 3198.0 3207.0 3208.5 3213.5 3219.0 3223.5 3220.5 3254.5 3261.0 3264.5 3275.0 3295.5 3298.0 3304.0 3309.5 3317.5 3325.0 3349.5 3352.0 3380.0 3381.0 3382.5 3385.5 3405.0 3407.0 3414.5 3420.5 3424.0 3426.0 3430.0 3432.0 3444.0 3448.5 3453.5 3460.0 3462.0 3469.5 3473.5 3480.0 3484.0 3490.5 3497.5 3501.0 3508.5 3512.0 3513.5 3520.5 3522.0 3526.5 3533.0 3542.5 3549.5 3556.5 3559.5 3570.0 3611.5 3662.5 3690.5 3708.5' 3718.5 3724.0 3727.0 3229.0 3264.0 3272.5 3277.5 3286.5 3308.0 3310.0 3315.5 3323.5 3330.5 3339.0 3363.0 3365.0 3393.0 3395.0 3396.5 3398.5 3418.0 3420.5 3427.5 3433.5 3436.5 3438.5 3442.5 3444.0 3456.5 3461.0 3466.0 3473.0 3475.0 3483.0 3485.0 3493.0 3498.5 3503.5 3511.0 3516.0 3522.0 3524.5 3526.0 3533.5 3536.5 3542.5 3546.5 3555.5 3563.5 3569.5 3572.0 3583.0 3625.5 3676.5 3704.5 3722.5 3732.5 3734.5 3738.0 3739.5 3733.0 3737.0 3740.5 3744.0 3755.0 3775.0 3780.5 3783.5 3785.0 3787.5 3793.0 3798.5 3825.0 3825.5 3830.0 3837.0 3854.0 3863.0 3873 .5 3881.0 3887.5 3891.0 3896.5 3907.0 3918.0 3928.0 3930.0 3932.5 3936.0 3939.5 3945.5 3953.0 3953.5 3959.5 3961.5 3963.5 3990.5 4003.0 4006.0 4012.0 4014.0 4041.0 4045.5 4052.5 4073.5 4085.5 4101.0 4132.5 4136.5 4145.5 4158.0 4164.5 4186.0 4197.5 4204.0 4207.0 4210.0 3746.0 3750.0 3752.0 3759.0 3768.0 3788.0 3793.5 3797.0 3799.0 3801.5 3806.5 3812.5 3837.5 3839.5 3842.5 3850.0 3867.5 3877.0 3887.5 3895.0 3902.0 3905.5 3911.0 3921.5 3932.5 3940.5 3943.0 3944.5 3946.5 3950.0 3956.0 3961.5 3963.0 3971.5 3974.0 3977.0 4004.0 4016.0 4019.0 4026.0 4028.0 4053.0 4059.0 4065.0 4086.5 4098.5 4113.0 4144.5 4149.0 4157.0 4172.0 4177.5 4199.0 4211.0 4217.5 4220.5 4223.5 4214.5 4228.0 4217.5 4230.5 4219.5 4232.5 4221.5 4234.5 4226.5 4239.5 4229.0 4241.5 4236.5 4249.5 4238.5 4251.0 4244.5 4257.0 4256.5 4269.0 4258.5 4272.0 4275.0 4288.5 4278.5 4291.5 4281.5 4295.5 4292.5 4305.5 4295.5 4309.0 4302.0 4315.5 4327.5 4341.5 4334.0 4347.0 4342.0 4353.5 4344.5 4354.5 4356.0 4369.0 4361.0 4374.5 4401.5 4415.5 4409.5 4424.5 4426.5 4441.0 4428.0 4442.5 4433.0 4446.5 4455..0 4469.0 4457.5 4471.5 4458.5 4472.5 4462.5 4475.0 4466.0 4478.5 4474.5 4487.0 4477.5 4490.0 4484.5 4498.5 4487.5 4501.5 4490.5 4504.0 4492.5 4507.0 4501.0 4516.0 4503.5 4520.0 4508.5 4526.0 4509.5 4528.0 4513.5 4532.5 4572.0 4590.0 4575.0 4592.0 4592.0 4609.0 4604.0 4618.5 4675.0 4689.5 4680.5 4696.5 4683.o 4699.o 4694.0 4707.0 4~96.0 4710.0 4697.0 4711.0 4700.5 4714.5 4702.5 4705.0 4706.0 4707.5 4710.0 4712.5 4715.0 4718.0 4720.0 4728.0 4729.5 4733.0 4751.0 4760.0 4764.0 4766.5 4783.5 4803.5 4807.0 4815.5 4823.5 4825.0 4839.0 4843.5 4854.5 4859.0 4862.0 4872.5 4876..5 4879.5 4886.0 4892.5 4902.5 4905.0 4906.0 4908.5 4914.0 4919.5 4924.0 4927.0 4935.0 4940.0 4945.5 4950.5 4953.0 4973.5 4998.0 5009.5 5015.0 5017.0 5019.5 5022.5 5028.0 5030.0 5~35.0 5117.5 5136.0 4716.5 4720.0 4721.0 4722.5 4724.5 4726.0 4729.5 4731.0 4733.0 4741.0 4742.5 4747.5 4766.5 4776.0 4779 0 4780 5 4798 0 4818 0 4821 5 4829 5 4837 5 4839 0 4854 0 4858 0 4867.5 4876.5 4878.0 4887.0 4891.0 4894.0 4900.5 4907.0 4915.5 4919.5 4920.5 4923.0 4928.5 4933.5 4938.0 4942.0 4950.0 4954.5 4959.5 4965.5 4970.0 4989.0 5011.5 5025.5 5028.0 5032.5 5035.0 5038.0 5043.0 5045.0 5050.5 5133.5 5155.0 5143.0 5148.0 5160.0 5171.5 5183.5 5185.0 5197.0 5205.0 5212.5 5213.5 5217.0 5218.0 5232.0 5241.5 5247.0 5260.5 5264.0 5268.5 5273.5 5276.5 5289.5 5292.0 5294.0 5297.0 5308.5 5313.0 5320.5 5326.5 5352.5 5372.5 5390.5 5401.5 5406.0 5410.0 5416.0 5437.0 5438.0 5446.5 5449.0 5452.5 5458.0 5461.0 5463.0 5465.0 5473.5 5475.0 5483.5 5513.0 5528.5 5539.5 555O.0 5553 .5 5562 .0 5574.0 5'~76.o 5576.5 5582.5 5161.5 5166.0 5179.0 5190.5 5197.5 5201.0 5212.5 5221.5 5227.5 5228.5 5231.5 5232.5 5247.0 5255.5 5260.5 5274.0 5279.0 5284.0 5290.5 5292.5 5304.0 5306.0 5308.0 5309.5 5321.0 5326.0 5333.5 5340.5 5365.0 5384.0 5404.5 5415.0 5420.0 5422.5 5428.5 5449.5 5452.0 5462.5 5464.0 5465.5 5470.0 5473.0 5477.0 5479.0 5485.0 5487.0 5496.0 5526.5 5543.5 5554.5 5565.5 5569.0 5577.0 5590.0 5592.0 5593.0 5598.5 5585.5 5587.0 5588.5 5593.0 5598.5 5600.5 5604.0 5606.0 5608.5 5612.5 5612.5 5617.0 5623.5 5626.5 5633.5 5639.5 5650.0 5651.5 5664.0 5667.5 5671.5 5721.5 5723.5 5726.5 5727.5 5742.5 5745.5 5752.0 5754.0 5756.5 5765.0 5766.5 5779.0 5781.0 5783.0 5801.0 5803.5 5807.0 5809.5 5817.0 5827.5 5857.5 5863.0 5866.5 5870.0 5872.5 5875.5 5878.5 5878.7 5884.5 5897.0 5913.0 5914.5 5934.0 5958.0 5965.5 5977.0 5600.5 5602.0 5603.5 5606.0 5612.5 5614.5 5618.5 5620.5 5622.5 5626.0 5627.5 5630.5 5640.0 5642.0 5650.0 5657.0 5665.5 5667.5 5680.5 5684.0 5686.5 5736.0 5738.0 5741.5 5743.0 5759.0 5762.0 5768.5 5770.5 5772.5 5780.5 5783.0 5794.5 5796.5 5799.5 5814.0 5817.5 5822.0 5824.5 5833.0 5843.5 5874.0 5879.0 5882.0 5885.5 -5889 0 5892 0 5897 5 5900 0 5902 5 5916 5 5932.0 5935.0 5952.0 5975.5 5984.0 5994.5 5990.0 6008.5 5993.0 6012.0 5994.0 6013.5 6003.0 6023.5 6065.0 6081.5 6066.0 6083.5 6072.0 6086.0 6076.5 6092.5 6079.5 6096.0 6084.0 6101.5 6086.0 6103.5 6091.0 6108.5 6101.0 6121.0 6109.0 6128.5 6111.5 6131.5 6119.5 6140.5 6121.5 6142.5 6128.0 6149.0 6133.5 6151.0 6153.5 6172.5 6160.0 6181.5 6163.0 6184.5 6169.0 6187.5 6171.5 6190.0 6176.0 6193.5 6177.5 6197.0 6183.5 6200.5 6193.0 6210.5 6194.5 6213.0 6195.5 6214.5 6203.0 6220.0 6208.0 6225.5 6216.5 6234.5 6221.0 6239.0 6223.5 6241.5 6225.0 6243.0 6228.0 6246.0 6229.5 6247.5 6233.5 6251.0 6239.5 6256.5 6246.5 6264.5 6255.0 6273.5 6259.5 6278.0 6262.0 6280.0 6269.5 6287.5 6276.0 6294.0 6284.5 6301.0 6286.0 6302.0 6291.5 6307.5 6293.0 6309.5 6298.5 6'313.5 6304.0 6318.0 6306.0 6320.0 6324.5 6338.0 6325.5 6339.0 6334.0 6347.0 6342.0 6353.0 6347.5 6387.5 6395.0 6402.0 6425.0 6427.5 6429.5 6432.0 6437.5 6440 · 0 6442.5 6444.5 6449.0 6464.0 6489.5 6506.0 6514.0 6517.0 6519.0 6523.5 6529.0 6533.0 6541.0 6548.5 6568.0 6571.5 6573.0 6576.5 6577.5 6582.0 6585.5 6590.5 6593.5 6597.0 6602.0 6614.5 6624.0 6637.0 6690.0 6694.5 6698.5 6706.0 6723.0 6731.0 6738.0 6742.5 6751.0 6758.5 6763.5 6769.5 6786.0 6791.5 6799.5 6807.0 6819.0 6821.5 6361.5 6403.0 6409.5 6419.5 6442.5 6443.5 6447.0 6450.0 6452.0 6454.0 6455.5 6457.0 6460.0 6476.5 6504.0 6521.5 6531.5 6534.0 6536.0 6540.0 6545.5 6550.0 6558.0 6568.5 6587.0 6589.5 6590.5 6592.5 6595.0 6600.0 6603.0 6608.0 6611.0 6614.5 6619.5 6632.5 6640.0 6654.0 6707.0 6712.0 6716.0 6723.0 6739.5 6747.0 6754.5 6758.5 6767.0 6774.5 6780.0 6785.0 6801.5 6808.0 6816.0 6823.5 6826.0 6835.5 6838.0 6829.0 6833.0 6841.5 6850.0 6864.0 6872.0 6874.0 6876.0 6896.0 6898.0 6904.0 6905.5 6909.0 6911.0 6915.0 6917.0 6918.0 6923.0 6927.0 6929.0 6932.0 6936.5 6941.0 6946.0 6947.5 6955.0 6965.0 6970.0 6972.5 6975.0 6979.5 6988.0 6991.0 6994.0 6999.0 7004.0 7007.0 7010.0 7016.0 7018.5 7018.6 7024.5 7028.0 7033.0 7048.0 7054.0 7058.5 7062.0 7086.5 7088.5 7095.5 7106.5 7118.5 7123.5 7128.0 7129.0 7144.5 6843.5 6848.5 6857.5 6866.5 6880.5 6888.5 6890.0 6892.0 6912.0 6914.0 6920.0 6921.5 6924.0 6925.5 6930.5 6932.5 6933.5 6939.0 6942.5 6944.5 6946.5 6952.0 6957.0 6962.0 6963.5 6972.0 6982.0 6987.5 6990.0 6993.5 6997.0 7004.5 7008.0 7011.5 7015.5 7022.0 7024.5 7028.0 7035.5 7038.5 7039.5 7043.0 7046.5 7050.0 7065.0 7071.5 7076.0 7080.5 7105.0 7107.0 7114.0 7124.0 7136.0 7141.5 7145.5 7147.0 7162.5 7149.0 7154.5 7157.0 7176.5 7183.5 7191.5 7193.5 7195.5 7199.5 7202.0 7204.0 7207.0 7208.5 7212.0 7215.0 7222.0 7226.0 7231.0 7234.0 7239.5 7242.5 7245.5 7248.5 7254.5 7255.5 7257.5 7260.5 7264.5 7267.5 7274.5 7278.5 7281.5 7282.5 7287.0 7299.0 7308.5 7323.5 7327.5 7334.0 7336.5 7341.5 7346.5 7349.0 7352.5 7360.0 7363.0 7371.0 7378.0 7380.0 7388.0 7392.5 7393.5 7398.5 7402.0 7405.0 7413.0 7419.0 7167.0 7172.5 7175.0 7194.5 7201.5 7209.5 7211.5 7213.5 7217.5 7219.5 7221.5 7224.5 7226.5 7230.5 7233.5 7240.5 7244.0 7249.0 7251.0 7256.5 7261.0 7264.0 7266.5 7271.0 7273.0 7275.0 7278.0 7283.0 7286.0 7293.0 7295.5 7299.0 7300.5 7304.5 7317.0 7321.0 7336.0 7341.0 7347.0 7349.5 7354.5 7358.5 7361.5 7365.5 7373.0 7376.0 7384.5 7391.5 7393.5 7400.5 7405.0 7406.5 7412.0 7415.0 7417.5 7425.5 7431.5 7420.0 7432.5 7427.5 7441.0 7434.5 7447.5 7448.0 7461.0 7449.5 7462.5 7459.0 7472.0 7460.5 7473.5 7462 . 0 7475 . 0 7464 . 0 7477 . 0 7486.5 7499.0 7501.5 7515.5 7505.5 7518.0 7508.0 7520.5 7523.5 7536.0 7527.5 7540.0 7533.0 7546.5 7536.5 7549.0 7542.5 7555.0 7548.0 7560.0 7557.5 7571.5 7563.0 7576.5 7565.5 7579.0 7570.0 7583.0 7582.0 7595.5 7588.0 7601.5 7593.0 7606.5 7598.0 7609.5 7603.0 7616.0 7622.0 7636.5 7639.5 7652.5 7657.5 7670.5 7661.5 7674.5 7670.0 7683.0 7673.5 7686.5 7683.5 7696.5 7706.5 7719.5 7708.0 7720.5 7711.0 7724.0 7715.5 7730.0 7723.0 7735.5 7725.5 7739.5 7731.5 7744.0 7734.5 7747.0 7741.0 7753.5 7745.0 7758.0 7750.0 7764.5 7756.5 7769.5 7759.0 7771.5 7762.5 7775.0 7766.0 7779.5 7768.0 7782.5 7769.5 7784.0 7782.0 7795.5 7787.0 7801.5 7803.5 7816.5 7816.5 7828.5 7860.5 7871.5 7877.5 7882.5 7885.0 7908.0 7918.5 7930.5 7943.5 7944.5 7951.5 7957.0 7958.5 7968.0 7988.0 7996.0 8001.5 8006.5 8010.5 8012.5 8043.0 8047.0 8075.5 8090.0 8092.5 8096.0 8104.5 8131.0 8146.5 8157.0 8167.5 8172.5 8174.0 8177.0 8190.5 8203.0 8208.0 8210.5 8215.0 8222.0 8239.5 8241.0 8242.0 8260.0 8272.5 8282.0 8299.0 8303.0 8330.5 8333.5 8335.5 8337.0 8349.5 8354.5 8357.5 8390.0 87Ol.5 8406.5 8407.5 7891.0 7894.5 7897.0 7918.5 7930.0 7943.0 7952.5 7953.5 7961.5 7967.0 7968.5 7977.5 7996.0 8005.0 8013.0 8016.5 8020.5 8024.0 8054.5 8059.0 8087.0 8101.5 8104.0 8108.5 8115.5 8140.5 8157.5 8168.0 8178.5 8184.0 8185.5 8188.5 8201.5 8214.5 8218.0 8221.0 8226.0 8232.5 8249.5 8252.0 8253.0 8270.0 8282.5 8292.0 8309.0 8312.5 8338.5 8341.5 8343.5 8345.0 8356.0 8362.5 8365.5 8398.5 8411.0 8416.0 8417.0 8418.0 8427.5 8422.0 8432.5 8430.0 8440.5 8431.5 8442.0 8437.5 8447.0 8442.5 8452.0 8445.5 8455.0 8451.0 8461.0 8461.0 8471.0 8465.0 8475.5 8479.0 8488.5 8486.0 8495.5 8488.5 8498.0 8491.5 8500.5 8494 . 5 8505 . 0 8499.0 8509.0 8506.0 8515.0 8508.5 8517.5 8514.0 8523.0 8516.5 8525.5 8524.5 8535.0 8535.0 8544.0 8548.5 8558.5 8569.0 8578.0 8570.5 8579.5 8582.0 8591.0 8584.5 8594.0 8586.0 8595.5 8591.0 8599.5 8595.0 8603.5 8599.0 8607.5 8606.0 8614.5 8610.5 8619.5 8616.0 8625.0 8618.0 8627.0 8620.5 8629.5 8626.0 8635.0 8627.0 8636.0 8631.0 8640.0 8635.5 8644.5 8644.5 8653.5 8650.0 8659.0 8651.5 8660.5 8664.0 8673.0 8679.5 8688.5 8691.5 8700.5 8694.5 8702.5 8709.0 8717.5 8725.5 8735.0 8736.0 8744.0 8739.5 8748.0 8751.5 8760.0 8760.5 8769.0 8766.0 8774.5 8770.5 8779.0 8774.5 8783.0 8777.0 8785.0 8779.5 8783.5 8794.0 8797.0 8802.0 8811.0 8814.5 8819.0 8823.0 8824.5 8828.0 8830.0 8832.0 8837.0 8840.5 8845.0 8930.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ REMARKS: 8787.5 8792.0 8802.5 8806.5 8811.5 8819.0 8823.0 8827.5 8831.5 8833.0 8836.5 8838.5 8840.5 8845.0 8848.5 8851.0 8936.0 BIT RUN NO MERGE TOP MERGE BASE 1 108.0 1731.0 2 1731.0 2558.0 3 2558.0 4210.0 4 4210.0 7020.0 5 7020.0 7280.0 6 7280.0 8935.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 NCNT ~WD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 32 9 36 10 40 11 44 12 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 48 52 13 14 Name Min Max Mean DEPT 70.5 8930 4500.25 ROP 1 2226.55 165.284 GR 12.01 238.49 106.265 RPX 1.11 1894.03 12.0877 RPS 1.09 1530.79 17.097 RPM 1.08 2000 47.561 RPD 1.27 2000 65.2476 FET 0.14 71.66 1.88372 NPHI 18.96 55.44 33.4782 NCNT 2315.51 3620.56 2951.89 FCNT 478.68 958.24 675.619 RHOB 2.27 2.99 2.57514 DRHO -0.03 0.6 0.0530925 PEF 4.77 7.74 6.09629 Nsam 17720 17668 17636 17561 17561 17561 17561 17561 3787 3787 3787 3785 3785 3785 First Reading 70.5 96.5 70.5 80.5 80.5 80.5 80.5 80.5 6974.5 6974.5 6974.5 6985.5 6985.5 6985.5 Last Reading 8930 8930 8888 8860.5 8860.5 8860.5 8860.5 8860.5 8867.5 8867.5 8867.5 8877.5 8877.5 8877.5 First Reading For Entire File .......... 70.5 Last Reading For Entire File ........... 8930 File Trailer Service name ............. STSLIB.001 Service Sub Level Name...' Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD De~th shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: START DEPTH STOP DEPTH 6974.5 7395.5 6974.5 7395.5 6974.5 7395.5 6974.5 7395.5 6974.5 7395.5 7000.0 7395.5 7048.5 7395.5 MAD RUN NO. MAD PASS NO. 6 MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE TOP 7052.0 MERGE BASE 7409.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 RAT MAD FT/H 4 1 68 GR MAD ;%PI 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHMM 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OF_MM 4 1 68 FET MAD HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 6974.5 7395.5 7185 843 RAT 2.2 200.98 71.8723 695 GR 84.54 174.3 129.008 792 RPX 2.17 15.96 5.95177 843 RPS 2.23 14.12 5.96248 843 RPM 2.11 11.58 5.60539 843 RPD 2.3 11.31 5.73947 843 FET 0.14 71.67 18.0322 843 First Reading For Entire File .......... 6974.5 Last Reading For Entire File ........... 7395.5 First Reading 6974.5 7048.5 7000 6974.5 6974.5 6974.5 6974.5 6974.5 Last Reading 7395.5 7395.5 7395.5 7395.5 7395.5 7395.5 7395.5 7395.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NTJMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 80.0 1677.5 FET 90.0 ' 1687.5 RPD 90.0 1687.5 RPM 90.0 1687.5 RPS 90.0 1687.5 RPX 90.0 1687.5 ROP 106.0 1730.5 $ LOG HEADER DATA DATE LOGGED: 26-JAN-99 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2.12.3 DOWNHOLE SOFTWARE VERSION: HCIM 630.91 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 1731.0 TOP LOG INTERVAL (FT): 108.0 BOTTOM LOG INTERVAL (FT): 1731.0 BIT ROTATING SPEED (RPM): HO~E INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 26.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER P1227CGR8 P1227CGR8 12.250 12.3 SP~ 10.00 80.0 9.8 200 9.6 4.900 4.230 5.000 5.500 27.3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 1 FT/H 4 1 68 4 2 GR MWD 1 API 4 1 68 8 3 RPX MWD 1 OHMM 4 1 68 12 4 RPS MWD 1 OHMM 4 1 68 16 5 RPM MWD 1 OHMM 4 1 68 20 6 RPD MWD 1 OHMM 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 Name Min Max Mean Nsam DEPT 80 1730.5 905.25 3302 ROP 1.87 2226.55 161.604 3250 GR 12.01 125.9 66.7003 3196 RPX 2.71 1894.03 37.7252 3196 RPS 2.88 1508.66 62.4359 3196 RPM 2.73 2000 223.768 3196 RPD 2.3 2000 298.224 3196 FET 0.33 1.24 0.62245 3196 First Reading 80 106 8O 90 90 9O 9O 90 Last Reading 1730.5 1730.5 1677.5 1687.5 1687.5 1687.5 1687.5 1687.5 First Reading For Entire File .......... 80 Last Reading For Entire File ........... 1730.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RD-NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 1678.0 FET 1688.0 RPD 1688.0 RPM 1688.0 RPS 1688.0 RPX 1688.0 ROP 1731.5 $ STOP DEPTH 2505.5 2515.5 2515.5 2515.5 2515.5 2515.5 25'59.0 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined 27-JAN-99 INSITE 3.2.12.3 HCIM 630.91 MEMORY 2558.0 1731.0 2558.0 26.2 28.2 TOOL NUMBER P1227CGR8 P1227CGR8 12.250 12.3 SPUD 10.20 71.0 9.6 600 6.2 4.900 4.230 5.000 5.500 28.9 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 DEPT ROP GR RPX RPS RPM RPD FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD 2 FT/H 4 1 68 MWD 2 API 4 1 68 MWD 2 OHMM 4 1 68 MWD 2 OHMM 4 1 68 MWD 2 OHMM 4 1 68 MWD 2 OHMM 4 1 68 MWD 2 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean DEPT 1678 2559 2118.5 ROP 3.17 1266.92 144.072 GR 27.03 126.99 81.5368 RPX 2.71 50.89 12.4072 RPS 3.02 65.62 14.3649 RPM 3.16 79.82 14.6005 RPD 3.54 80.15 15.2743 FET 0.35 5.4 0.880115 Nsam 1763 1656 1656 1656 1656 1656 1656 1656 First Reading 1678 1731.5 1678 1688 1688 1688 1688 1688 Last Reading 2559 2559 2505.5 2515.5 2515.5 '2515.5 2515.5 2515.5 First Reading For Entire File .......... 1678 Last Reading For Entire File ........... 2559 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and lo9 header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2505.0 4156.0 FET 2516.0 4165.5 RPD 2516.0 4165.5 RPM 2516.0 4165.5 RPS 2516.0 4165.5 RPX 2516.0 4165.5 ROP 2559.5 4210.0 $ 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: 30-JAN-99 INSITE 3.2.12.3 HCIM 630.91 MEMORY 4210.0 2558.0 4210.0 27.3 29.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P1231HGR6 P1231HGR6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT): 8.500 8.5 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 9.60 50.0 9.4 250 7.2 3.200 2.780 5.100 2.500 28.9 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD 3 FT/H 4 1 68 GR MWD 3 API 4 1 68 RPX MWD 3 OHMM 4 1 68 RPS MWD 3 OHMM 4 1 68 RPM MWD 3 OHMM 4 1 68 RPD MWD 3 OHMM 4 1 68 FET MWD 3 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean DEPT 2506 4210 3358 ROP 2.2 944.09 204.987 GR 34.78 238.49 106.842 RPX 1.26 2000 7.15757 RPS 1.32 2000 8.75036 RPM 1.32 2000 14.8145 RPD 1.5 2000 35.7638 FET 0.25 52.53 2.0219 Nsam 3409 3302 3301 3300 3300 3300 3300' 3300 First Reading 2506 2559.5 2506 2516 2516 2516 2516 2516 Last Reading 4210 4210 4156 4165.5 4165.5 4165.5 4165.5 4165.5 First Reading For Entire File .......... 2506 Last Reading For Entire File ........... 4210 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 Fi~e Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4156.5 6965.0 FET 4166.0 6974.5 RPD 4166.0 6974.5 RPM 4166.0 6974.5 RPS 4166.0 6974.5 RPX 4166.0 6974.5 ROP 4211.0 7019.5 $ LOG HEADER DATA DATE LOGGED: 31-JAN-99 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2.12.3 DOWNHOLE SOFTWARE VERSION: HCIM 630.91 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 7020.0 TOP LOG INTERVAL (FT): 4210.0 BOTTOM LOG INTERVAL (FT): 7020.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 7.5 MAXIMUM ANGLE: 29.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: TOOL NUMBER P1231HGR6 P1231HGR6 8.500 8.5 LSND 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD 4 FT/H 4 1 68 GR MWD 4 API 4 1 68 RPX MWD 4 OHMM 4 1 68 RPS MWD 4 OHMM 4 1 68 RPM MWD 4 OHMM 4 1 68 RPD MWD 4 OHMM 4 1 68 FET MWD 4 HOUR 4 1 68 9.60 47.0 8.9 250 5.4 3.500 2.340 5.500 2.800 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 42.2 Name Min Max Mean DEPT 4156.5 7019.5 5588 ROP 1.87 1080.19 191.724 GR 42.68 233.02 132.25 RPX 1.33 21.9 4.57921 RPS 1.38 16.04 4.65216 RPM 1.39 11.5 4.55171 RPD 1.49 11.56 4.89781 FET 0.23 9.46 0.736413 Nsam 5727 5618 5618 5618 5618 5618 5618 5618 First Reading 4156.5 4211 4156.5 4166 4166 4166 4166 4166 Last Reading 7019.5 7019.5 6965 6974.5 6974.5 6974.5 6974.5 6974.5 First Reading For Entire File .......... 4156.5 Last Reading For Entire File ........... 7019.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6960.0 7263.5 ROP 6972.0 7280.0 FET 6975.0 7273.0 RPD 6975.0 7273.0 RPM 6975.0 7273.0 RPS 6975.0 .7273.0 RPX 6975.0 7273.0 $ LOG HEADER DATA DATE LOGGED: 01-FEB-99 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2.12.3 DOWN/~OLE SOFTWARE VERSION: HCIM 630.91 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 7280.0 TOP LOG INTERVAL (FT): 7020.0 BOTTOM LOG INTERVAL (FT) : 7280.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM D/qGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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): MLTD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... .Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 4.7 6.5 TOOL NLTMBER P1231HGR6 P1231HGR6 8.500 8.5 LSND 9.60 49.0 9.2 250 5.1 3.000 1.540 3.200 3.000 55.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 5 FT/H 4 1 68 4 2 GR MWD 5 API 4 1 68 8 3 RPX MWD 5 OHMM 4 1 68 12 4 RPS MWD 5 OHMM 4 1 68 16 5 RPM MWD 5 OHMM 4 1 68 20 6 RPD MWD 5 OHMM 4 1 68 24 7 FET MWD 5 HOUR 4 1 68 28 Name Min Max Mean Nsam DEPT 6965.5 7280 7122.75 630 ROP 1 222.06 44.3225 617 GR 93.83 221.86 137.978 597 RPX 1.11 11.78 5.08384 597 RPS 1.09 11.62 5.15905 597 RPM 1.08 10.41 5.01543 597 RPD 1.27 10.6 5.3737 597 FET 0.14 12.51 2.07906 597 First Reading 6965.5 6972 6965.5 6975 6975 6975 6975 6975 Last Reading 7280 7280 7263.5 7273 7273 7273 7273 7273 First Reading For Entire File .......... 6965.5 Last Reading For Entire File ........... 7280 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT 6993.0 NCNT 6993.0 PEF 7002.5 DRHO 7002.5 STOP DEPTH 8873.5 8873.5 8873.5 8883.5 8883.5 RHOB 7002.5 GR 7264.0 FET 7273.5 RPD 7273.5 RPM 7273.5 RPS 7273.5 RPX 7273.5 ROP 7280.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT): .8883.5 8894.0 8866.5 8866.5 8866.5 8866.5 8866.5 8936.0 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TO~L STANDOFF (IN): EWR FREQUENCY (HZ): 06-FEB-99 INSITE 3.2.12.3 HCIM 630.91 MEMORY 8935.0 7052.0 8935.0 1.8 4.6 TOOL NUMBER P1233HRNLG6 P1233HRNLG6 P1233HRNLG6 P1233HRNLG6 8.500 8.5 LSND 9.90 50.0 9.3 400 4.7 2.400 1.220 3.000 3.000 5.6 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD 6 FT/H 4 1 68 GR MWD 6 API 4 1 68 RPX MWD 6 OHMM 4 1 68 RPS MWD 6 OHMM 4 1 68 RPM MWD 6 OHMM 4 1 68 RPD MWD 6 OHMM 4 1 68 FET MWD 6 HOUR 4 1 68 NPHI MWD 6 PU-S 4 1 68 FCNT MWD 6 CNTS 4 1 68 NCNT MWD 6 CNTS 4 1 68 RHOB MWD 6 ' G/CM 4 1 68 DP. HO MWD 6 G/CM 4 1 68 PEF MWD 6 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEPT 6993 8936 7964.5 3887 ROP 1.45 524.74 116.141 3312 GR 47.6 219.81 106.429 3261 RPX 2.21 17.53 6.45944 3187 RPS 2.33 16.09 6.51312 3187 RPM 2.28 13.92 6.15188 3187 RPD 2.48 14.41 6.48152 3187 FET 0.74 71.67 5.41477 3187 NPHI 18.96 55.44 33.5105 3762 FCNT 478.68 958.24 675.417 3762 NCNT 2315.51 3620.56 2950.84 3762 R/{OB 2.27 2.99 2.57514 3763 DP/qO -0.03 0.6 0.0529777 3763 PEF 4.77 7.74 6.0961 3763 First Reading 6993 7280.5 7264 7273.5 7273.5 7273.5 7273.5 7273.5 6993 6993 6993 7002.5 7002.5 7002.5 Last Reading 8936 8936 8894 8866.5 8866.5 8866.5 8866.5 8866.5 8873.5 8873.5 8873.5 8883.5 8883.5 8883.5 First Reading For Entire File .......... 6993 Last Reading For Entire File ........... 8936 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 6 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR RAT $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE START DEPTH STOP DEPTH 6993.0 7409.0 6993.0 7409.0 6993.0 7409.0 6993.0 7409.0 6993.0 7409.0 7017.0 7409.0 7066.0 7409.0 06-FEB-99 INSITE 3.2.12.3 HCIM 630.91 MEMORY 8935.0 7052.0 8935.0 1.8 4.6 TOOL NUMBER DGR EWR4 CNP SLD $ DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 P1233HRl~LG6 P1233HRNLG6 P1233HRNLG6 P1233HRNLG6 8.500 8.5 LSND 9.90 50.0 9.3 400 4.7 2.400 1.220 3.000 3.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MAD 6 API 4 1 68 4 2 RAT MAD 6 FT/H 4 1 68 8 3 RPX MAD 6 OHMM 4 1 68 12 4 RPS MAD 6 OHMM 4 1 68 16 5 RPM MAD 6 OHMM 4 1 68 20 6 RPD MAD 6 OHMM 4 1 68 24 7 FET ~AD 6 OHMM 4 1 68 28 8 5.6 Name Min Max Mean DEPT 6993 7409 7201 GR 84.54 174.3 128.962 RAT 2.2 200.98 71.9993 RPX 2.17 15.96 5.94181 RPS 2.23 14.12 5.9491 RPM 2.11 11.58 5.59109 RPD 2.3 11.31 5.72401 FET 0.14 71.67 17.6905 Nsam 833 785 687 833 833 833 833 833 First Reading 6993 7017 7066 6993 6993 6993 6993 6993 Last Reading 7409 7409 7409 7409 7409 7409 7409 7409 First Reading For Entire File .......... 6993 Last Reading For Entire File ........... 7409 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/03/07 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............ .LISTPE Date ..................... 99/03/07 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
