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Home My WebLink About201-007 • • l (-70 Nye- 1HH1pS TRANSMITTAL FROM: Sandra D. Lemke,ATO-704 TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 RE: Rendezvous 2 Permit: 201-007 DATE: 06/29/2017 Transmitted: North Slope, NPRA, Alaska Rendezvous 2 Digital file via email Rendezvous 2-Expro well test; Jurassic interval perfs 8350-8390'; Feb 19 to March 3, 2008 Replacement for AOGCC eset number T16175 as requested by Meredith Guhl; 6/28/2017 `The information provided hereunder by ConocoPhillips Alaska,Inc.,as Operator of the Greater Moose's Tooth Unit("ConocoPhillips"),is confidential and proprietary to ConocoPhillips and is not subject to disclosure because it contains information or data that is exempted from disclosure under 20 AAC 25.537(b). Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemkec COP.com CC: Rendezvous 2-e-transmittal well folder (2_cy Receipt: Date: GGRE I ConocoPhil" s Alaska Ph: 907.265.6947 SCANNED l-U t 0 7 201/ STATE OF ALASKA A. ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT j 00 20 AAC 25.230 Name of Operator: Field and Pool: Month and Year: ConocoPhillips Alaska, Inc. Greater Moose's Tooth Unit- Exploratory Feb -08 1. Well No. 2. API No. 3. Type 4. Field & 5. Method 6. Days 7. Avg FTP DAILY AVG PRODUCTION TOTAL MONTHLY PRO DUCTION 50- XXX- XXXXX -XX -XX (see Pool Code (see in Oper. psig (see 8. OIL 9. WATER 10. GAS 11. OIL 12. WATER 13. GAS instruct.) instruct.) Instruct.) (BBL) (BBL) (MCF) (BBL) (BBL) (MCF) RENDEZVOUS 50- 103 - 20363 -00 1 1 7 670 360 111 570 2,523 774 3,990 1 1 This report is confidential and proprietary to ConocoPhillips Alaska, Inc. and not subject to disclosure because it contains information or data that is (1) trade secret information as defined in AS 45.50.940(3) and State v. Arctic Slope Regional Corp., 834 P.2d 123 (Alaska 1991); (2) data required to be held confidential under AS 38.05.035(a)(8), AS 31.05.035(c), AS 43.05.230, and AS 40.25.100(a); and /or (3) data required to be held confidential pursuant to Article 3.9.7 of the Colville River Unit Agreement. 1 1 1 1 1 1 I hereby certify that the foregoing is true and correct to the best of my knowledge. 14 Printed Name: Julie Sale Title: Supervisor, Revenue & Regulatory Signature: c Date: June 18, 2009 TOTAL 2,523 774 3,990 Form 10-405 Rev. 04/2006 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA r ALASKA OIL AND GAS CONSERVATION COMMISSION TT tt MONTHLY PRODUCTION REPORT _ F 20 AAC 25.230 Name of Operator. Field and Pool: Month and Year: ConocoPhillips Alaska, Inc. Greater Moose's Tooth Unit- Exploratory Mar -08 1. Well No. 2. API No. 3. Type 4. Field & 5. Method 6. Days 7. Avg FTP DAILY A VG PRODUCTION TOTAL MONTHLY PRODUCTION 50- XXX- XXXXX -XX -XX (see Pool Code (see in Oper. psig (see 8. OIL 9. WATER 10. GAS 11. OIL 12. WATER 13. GAS instruct.) instruct.) Instruct.) (BBL) (BBL) (MCF) (BBL) (BBL) (MCF) RENDEZVOUS 50- 103 - 20363 -00 1 j 2 1300 899 0 560 1,798 0 1,120 This report is confidential and proprietary to ConocoPhillips Alaska, Inc. and not subject to disclosure because it contains information or data 1 that is (1) trade secret information as defined in AS 45.50.940(3) and State v. Arctic Slope Regional Corp., 834 P.2d 123 (Alaska 1991); (2) data required to be held confidential under AS 38.05.035(a)(8), AS 31.05.035(c), AS 43.05.230, and AS 40.25.100(a); and/or (3) data required to be held confidential pursuant to Article 3.9.7 of the Colville River Unit Agreement. 1 1 1 1 1 I hereby certify that the foregoing is true and correct to the best of my knowledge. 14 Printed Name: Julie Sale Title: Supervisor, Revenue & Regulatory Signature: A 0 Date: June 18, 2009 TOTAL 1,798 0 1,120 � !/i N' i FEE c, t lZ Form 10-405 Rev. 04/2006 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ConocoPhillips, Anadarko make two discoveries in NPR-A, Oil & Gas Journal -May 04, ... Fage 1 of 1 Print thin article Close ConocoPhillips, Anadarko make two discoveries in NPR-A sy OGJ editors HOUSTON, May 4 -- ConocoPhillips and Anadarko Petroleum Corp. reported the discovery and test production from two welts it n thet a~t~r~l Pe~trCo.~l'e~um Reserve-Alaska (NPRt_ A). ~ ~ Q ~ , O~~ Pioneer 1, which was testedin March, and Rene4~zrr4us 2, which was testedtn winter 2008, both lie in the Greater Mooses Tooth Unit about 20 miles southwest of the Colville River Unit development on the North Slope of Alaska. Test production rates for these wells ranged from 500 b/d to 1,300 bld of high-gravity oil. Gas production races averaged 1.5 MMcfd for each well, the companies said. "Na further delineation drilling is planned for Pioneer or Rendezvous at this time," the companies said. These two accumulations will be pursued as possible satellite developments with processing at the Alpine facilities in the Colville River Unit. Operator ConocoPhillips holds 7$% interest in the Greater Mooses Tooth Unit, while Anadarko holds 22%. To acxess this article, go to: http://www.ogj.com/articleslarticte_display.cfm?ARTICLE ID=3610988p=7 Copyright ~ 2009: PennWell Corporation, Tulsa, OK; All Rights Reserved. r ~,~_~t ~~ j 1 ~ .~ r ° ~ L.. bl k http://www.ogj.com/articles/print screen.cfm?ARTICLE ID-361098 5/7/2009 NE - NPRA '07-'08 Exploratiot.7l,F,~n~F~ FEe ~ s zoos Program Scope ~,a ,~r,~ „~_ .~ Tr A',~~1lQ~1./O1 'tea ,, CASSIN f } / 4 ~ ., ! Froze ~' i ~ ~ ; _"T~~. L _._ ~ j ~' ~ a ~ FY '~~., 12 miles ~ t ~~ - ~ ~ =i ~; ...,,fie r'.,,~ SCOU7 BFafRikl`i, t~r~a' ~, ~\ _.~VI/O9 / A~ LOOKOIIf7~ ~Y ' ' ~ NANUK2- '.`r LOOKOUj~ G `` T "j ® y~~ .. 1 1L(+J~ .. NOOSES _ ' , ~ :. ,~S 100 .y~-.`- ' ~~eel. ~) - ~ O~ f ~NIlRE I ' I:., ~ARKI ~ 4 miles~~ OL veR A ' I ..PARK /A RENDif'YOUS A~ 6RARK DD-9 2U mIIeS .,'~ .~ I ~ 4 miles ~ x I '~ cNDEZVOU52 I...:~~ f ~ ~ . ..1, y~, National Petroleum Reserve - tllaska ~ ~ Pay "` ~~''~~'"" ~, _. ~STOf41'HILL ~'~ '~ ~pT1 w ~ .+~ %'y' ~ ~`` f f r~ ~ 141(!7 llM1H I u,aM1rJns `;x Paifn,IOng f ~ ~ ' ~' : `\ ® 1899 2W7 DrilleJ ~~ ® Suspendetl Well fir, 1 ~ ~~..-~~ Prd~~uus'ry Pdrmdlutl lud FUSiis ~ _ i /t,4 ~ :.~~? UU7-iKdW Putenoel Wincar Trails A SCALE I~ J PAII F ; ,i~ 40 Miles of "Exploration Ice Road" (west of Alpine C U t-Off 3 Ice Pads ~ 2 New Wells with Full Core ~ 1 Re-entry ~ 1 Sidetrack to Horizontal ~ 2 Hydraulic Fracture Stln'tulatlOnS ~ 4 Tests ~ 3 Complete P&A's a~~-~~ IasNa ~Kploration SI"tOf"~' f ~ E / r 1<ilNC ' 4FL~/ ~~Ip L~ -`' ~ i ,~ ~~ .. -~ ALACER 7~ `' ' ~ ~ ~ ~ ~ I S'Cl ~. k ~ , ~ .. ~ „ OB[ROJ[Y . ~;..;, 4 ~ Y ~~/ ~ ~ : _ 4 '' `k t 3 ~~ r l1 ,f ~, t ~ AfW Y~~AR.., ~~ 1. ~. ,. - ; ! ~ it ' - ~y` ~1. .., Cor~ocoPhillips 2007-2008 Proposed Exploration Wells X11 x,17 U7U625U1ODU tikes ~ ~ ~ c.~~cJ 1 ~~~~~~~C ,~~+''~ CanacpPhillips 1't?l'aE~tt~^ ca+~r~,cr~~u-;~=, Alaska, Inc. • • • TRANSMITTAL C4NF/DE/VT/AL DATA FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhiliips Alaska, Inc. State of Alaska P.O. Box 100360 AOGCC Anchorage AK 99510-0360 555 W. 7"' Ave., Suite 100 Anchorage, Alaska 99501 RE: Rendezvous 2 AOGCC Permit: 201-007 DATE: 01 /20/2009 North Slope, Alaska Rendezvous 2 501032036300 1 hardcopy report 2008 Geochemical Analytical Results; Rendezvous 2 well, North Slope, NPRA-Alaska; Albert HoIba/Tina Phillips; Subsurface Technology data report, December 2008. Whole Oit/GC; saturate GC/MS; saturate GClMS/MS; Aromatic GC/MS Please promptly sign, scan as pdf file and return. via a-amail to email address below; retain a copy for your corporate files CC: Greg ilso , AI Geologist ~ '. ~ 3~; Receipt: Date: r . ~ . ,,~ >., I ~-'}~ ~3.~-3"e~'hr°tical ~aa"a s$~lara,~ernert ~ ~o~Qc~~~il'/sljr. -'w pr~ge, ~las/sa ~ Ph: ~L~~~'~'S.~'.~~7 Sandra D.LemkeCa)Conocophi/lips corn ~~ -,,.~ ~~~;'~~~9~~ J~~ ~' ~ }7~tr.~. 'f" `` ~UGl if • ConocoPhillips Subsurface Technology 20~eochemical Data Report 2008 Geochemical Analytical Results: Rendezvous-2 Well, North Slope, Alaska By Albert G. Holba ~~~1~ Tina Phillips ~~ ~`O (`~~ ConocoPhillips Subsurface Technology, V Data Report December 2008 Geochemical analytical data is reported here for drill stem test oil and gas samples from the 2008 test of well, Rendezvous-2, drilled in 2001. Table 1 provides sample identification and description as well as an inventory of analyses performed on the samples. Analyses of oil samples were performed by Baseline Resolution Inc., a subsidiary of Weatherford Labs (current address: 143 Vision Park Bivd., Shenandoah, TX, 77384). Rendezvous-2 samples are referenced to Baseline project code 08-628-A. Data is provided in the Vendor Data Appendices. Test gas analyses were performed at Isotech Laboratories, (1308 Parkland Court, . Champaign, Illinois, 61821) under Isotech Job 9821. Gas compositions and isotopic ratios (carbon and deuterium) test gases are provided in the Vendor Data Appendices. Separator oil samples from DSTs 1.12, 1.13, 2.16, and 2.17 arrived in April, 1 2008 at Baseline Resolution Inc. lab (Weatherford) from Alaska and were analyzed immediately. Two additional PVT quality DST oils are sent .from Qil Phase (Schlumberger, Houston).in June to Baseline. Two gas samples (DST 1.08 and 2.15) are sent to Isotech labs from Oil Phase (Schlumberger). Sample analyses were invoiced to the well test. Time-writing and late 2008 analyses were charged under the ConocoPhillips Upstream Technology technical work agreement for the Rendezvous-2 well, WNT.161935.IB. a 1 • • ConocoPhillips Subsurface Technology 2008 Geochemical Data Report Table of Report Contents • Vendor Data Appendices Miscellaneous Vendor Data DST 1.08 & 2,15 Gas Analysis (2 pages). Medium Pressure Liquid Chromatograghy Fractionation of oils (1 page). Carbon Isotopes Oil. Fractions (1 page). Gas Chromatograms and numerical data for Whole Oil (WGC): Sample ID Raw Data Depth Formation Number File Number of Pages Rendezvous - 2 US140550 G3080630.D 8,350-390 Alpine (3 pages); US140551 G3080631.D 8,350-390 Alpine (3 pages); US140552 G3080632.D 8,350-390 Alpine (3 pages); US140553 G3080633.D 8,350-390 Alpine (3 pages}; US141080 G1081128.D 8,350-390 Alpine (3 pages); US141081 G1081129.D 8,350-390 Alpine (3 pages); Gas Chromato~raphy/Mass Spectrometry G{ C/MS} saturate hydrocarbon chromatograms and numerical data; Rendezvous - 2 US140522 M2081229.D 8,350-390 Alpine (5 pages); Gas Chromatocraphy/Tandem Mass Spectrometry (GCIMS/MS} saturate hydrocarbon mass chromatograms and numerical data; Rendezvous - 2 US140522 MS080260.D 8,350-390 Alpine (6 pages); Gas Chromatography/Mass Spectrometry (GC/MS) aromatic hydrocarbon chromatograms and numerical data. Rendezvous - 2 US140522 M1081236.D 8,350-390 Alpine (7 pages); C 2 • ConocoPhillips Subsurface TeZTinology DISTRIBUTION LIST: Albert Holba (CoP/ Sub-Surface Technology) Greg Wilson ConocoPhillips Alaska Inc Post drill Summary reports, for partners, etc. To Bev Burns ConocoPhillips Records, Houston 2~eochemical Data Report (1 copy) (1 copy) (4 archive copies) (1 archive copy). • Table 1. Sample Identification analyses Inventory: Rendezvous-2 Sample Identification endor ID Vendor Project! Job Code ell DT # !Type Meas. Depth Top (ft.) Meas. Depth Base (ft.) ormation U a ~ O o c9 r ~ tnU v +' C? ~ mU V o c7 Q ~U ~ +s V to O a~i o ° +'~ °~ a44, a~i a ° O w Z ~ A ° O E v m `0 ° C7 uo GAS SAMPLES (from Separator Gas Line ) US140930 138499 9821 Rendezvous-2 DST 1.08 8,350 8,390 Alpine G X X US140931 138500 9821 Rendezvous-2 DST 2.15 8,350 8,390 Alpine C X X OIL SAMPLES US140550 CP289068 OS-628-A Rendezvous-2 DST 1.13 sep. Oil 8,350 8,390 Alpine C X X US140551 CP289069 08-628-A Rendezvous-2 DST 2.16 sep. Oil 8,350 8,390 Alpine C X US140552 CP289070 08-628-A Rendezvous-2 DST 1.12 sep. Oil 8,350 8,390 Alpine C X X X X X X X US140553 CP289071 08-628-A Rendezvous-2 DST 2.17 sep. Oil 8,350 8,390 Alpine C X US141080 CP289647 08-628-A Rendezvous-2 DST sep. dead Oil 8,350 8,390 Alpine C X US141081 CP289648 OS-628-A Rendezvous-2 DST sep. dead Oil 8,350 8,390 Alpine C X Miscellaneous Vendor Data MEMORANDUM TO: Jim Regg Z �� P. I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission clej DATE SUBJECT: August 10, 2008 Location Inspection Rendezvous #2 ConocoPhillips PTD 2010070 Sunday, August 10, 2008: 1 performed a Location Clearance inspection of the CPAI exploratory well Rendezvous #2. 1 was accompanied by Chris Brown (CPAI Environmental). This exploration location was clean with no evidence of past drilling activity other than a slight discoloration of the tundra in the area of the pad and access road. The cellar area was mounded nicely to prevent ponding. I recommend this location be approved "final location cleared". - Attachments: Photos (2) - 2008-0810_Location_Clear_Rendezvous-2_cs.docx Page 1 of 2 Location Inspection — Rendezvous #2 (PTD 2010070) Photos by AOGCC Inspector C. Scheve 8/10/2008 2008-0810 Location Clear_ Rendezvous -2 cs.docx Page 2 of 2 • • COTE H ° i ,- isoMCA inc. 4395 Caurt, ~. 11521- T (2!7} ~8-349Q Fa~c (217j Lab #: 138500 Job #: 9821 Sample Name: 1.08 - GSB BA6102 Co. Lab#: US140930 Company: ConocoPhillips, Alaska Date Sampled: 5/22/2008 Cylinder: 4023 Container: 150 ml stainless Field/Site Name: Rendezvous #2 Location: Formation/Depth: Sampling Point: Date Received: 6/03/2008 Date Reported: 6/27/2008 Component Chemical Delta 13C Delta D Delta 15N mol. % per mil per mil per mil Carbon Monoxide -----------• nd Hydrogen Sulfide ------------ nd Helium -------------------------- 0.0028 Hydrogen ---------------------- nd Argon --------------------------~ 0.0264 Oxygen ------------------------ 0.548 Nitrogen ------------------------ 2.22 Carbon Dioxide --------------- 1.50 -9.04 Methane ------------------------ 68.51 -48.70 -210.0 Ethane -------------------------- 13.92 -33.65 Ethylene -----------------------• nd Propane ------------------------ 8.16 -30.17 Iso-butane --------------------- 1.17 -31.32 N-butane ----------------------- 2.25 -29.80 Iso-pentane -------------------~ 0.601 N-pentane --------------------- 0.553 Hexanes + --------------------- 0.539 Total BTU/cu.ft. dry @ 60deg F & 14.7psia, calculated: 1335 Specific gravity, calculated: 0.812 nd =not detected. na =not analyzed. Isotopic composition of carbon is relative to VPDB. Isotopic composition of hydrogen is relative to VSMOW. Calculations for BTU and specific gravity per ASTM D3588. Chemical compositions are normalized to 100%. Mol. % is approximately equal to vol. %. Chemical analysis based on standards accurate to within 2% Lab #: 138499 Job #: 9821 Sample Name: 2.15 - NSK107 Co. Lab#: 05140931 Company: ConocoPhillips, Alaska Date Sampled: 3/01/2008 Cylinder: NSK107 Container: 150 ml stainless FieldlSite Name: Rendezvous #2 Location: Formation/Depth: Sampling Point: Date Received: 6/03/2008 Date Reported: 6/27/2008 Component Chemical Delta 13C Delta D Delta 15N mol. % per mil per mil per mil Carbon Monoxide ------------ nd Hydrogen Sulfide ------------ nd Helium -------------------------- 0.0028 Hydrogen ----------------------~ nd Argon --------------------------- 0.0067 Oxygen ------------------------- Nitrogen ------------------------ 0.117 0.55 Carbon Dioxide --------------• 1.55 -9.01 Methane -----------------------• 68.97 -48.71 -209.8 Ethane ------------------------- 14.60 -33.66 -169.3 Ethylene ------------------------ nd Propane ------------------------ 8.63 -30.17 -140.7 Iso-butane -------------------- 1.25 -31.35 N-butane ----------------------- 2.42 -29.83 Iso-pentane -------------------• 0.683 N-pentane -------------------- 0.642 Hexanes + --------------------- 0.581 Total BTU/cu.ft. dry @ 60deg F & 14.7psia, calculated: 1382 Specific gravity, calculated: 0.819 Remarks: Report revised on 7/25/08 to include hydrogen isotope data for ethane and propane. nd =not detected. na =not analyzed. Isotopic composition of carbon is relative to VPDB. Isotopic composition of hydrogen is relative to VSMOW. Calculations for BTU and specific gravity per ASTM D3588. Chemical compositions are normalized to 100%. Mol. % is approximately equal to vol. %. Chemical analysis based on standards accurate to within 2% US14(3b52 CP289474 -34.4 - 9:4 -29.3 -29.3 i Baseline Resolution, Inc., 143 Vision Park Blvd., Shenandoah, Texas 77384 Phone: 281 681-2200 Fax: 281-681-0326 Email: info~brilabs.com U J a a • e z m N O N '~ tL` • M O • ~. O ®a ~~ v cfl ~~ • ~~~ ~. _ ~ N r ~ O O O a0 V' _ CO t~ ~ O ' O ~ • O O O O r ~ • ~ tC') tC3 O O • O O O O N O * ~ t t> ~ ~ ~ • O O O O cr c? ~ ~ ' • O O O O ~~ ~ '~' ~ ~ • O O O O Od O ~ O O rn O O ~ cV cV d ~ U U ~ ~ 00 vv ~~ ~~ a m .o 0 c E w s m 0 m c m L CO Y m a ci c c o_ 5 0 w d d c .~ 0 m 0 m _O C) u • ~ BASELJNE R~SOLAJTI~fV INC. WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US141080 Country: UNITED STATES Project #: 08-628-A Basin: NORTH SLOPE Lab ID: CP289647 Lease: Sample Type: Separator Oil Block: Sampling Point: 2008 DST Field: RENDEZVOUS Formation: Alpine Fm Well Name: RENDEZVOUS-2 Geologic Age: Jurassic Latitude: 70.15146 Top Depth: 8,350 ft. Lon itude: -151.6855 Bottom De the 8,390 ft. • Pr~tanelPtsytane 1.99 A, BZInC~ 0.22 Pristaneln C„ 0.57 B. TOUn C~ 1.02 Phytanetn G,a 0.33 C. (~, cB+m c,~(cl~a-c+t> 0.63 nC,~lnC,s 1.07 (. lsoheptane Value 1.28 nC~~JnC~ 3.65 F. nC,#MCH 0.48 CPI Marn'` 1.03 U. CHlMCP 1.53 fVormai Paraffins 29.8 R, n G,l2MH 2.93 Isoprenoids 4.1 S. n C~/220M6 35.33 Cycloparaffms 7.5 H. hieptane Value 18.30 Branched (iso-} Paraffins 4.1 MCHln G~ 2.06 BTX aromatics 4.4 mpXYUn C& 1.03 Resolved unknowms 50.1 Thompson, K.F.M.,1483.GCA:V.47, p.303. Mango, F.D.,1494.GCA: V.58, p.895. 3Halpem,H.L,1995,AAPG Butl.: V.79, p.801. ~Marzi,l993,OrgG,20,t301. • Company: CONOCOPHILLIPS Client ID: US141080 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289647 Sampling Point: File Name: G1081128.D • !C4 Iso-akane C4 4A70 15023 12089 1.30 2.40 NC4 Noma{ Alkane C4 4.184 49376 39040 4.27 7:75 IC5 Iso-akane C5 4.610 52900 38642 4.57 7.67 NG5 Normal AHcane G5 4.845 69034 48428 5.97 9.61 22DMB 2,2-Dimethylbutane 5.287 2264 1445 024 0.29 CP Cydopentane 5.744 9859 6084 0.85 1.21 23DMB 2,3-Dimethylbutane 5.775 7327 4582 0.63 0.91 2MP 2-Methyipentane 5.856 42665 25923 3.69. 5:15 3MP 3-Methylpentane 6.147 27906 16213 2.41 322 NG6 Normal Alkane C6 6.551 79837 45499 6.90 8.95 22DMP 2,2-Dimethylpentane 7.211 2078 1190 0.18 0.24 MGP Methy{cyclo~ntane 7.268 54488 27920 4.71 5:54 24DMP 2,4-Dimethylpentane 7.400 4635 2264 0.40 0.45 223TMB 2,2,3-Trimethylbutane 7.554 764 325 4.07 4.06 BZ Benzene 8.018 17274 7879 1.49 1.56 33DMP 3,3-Dimethylpentane 8.224 1398 619 4.12 4.12 CH Cyclohexane 8.340 83509 39011 7.22 7.74 2MH 2-Methylhexane 8.719 30223 14242 2.61 2.83 23DMP 2,3-Dimethylpentane 8.768 7889 3925 0.68 0.78 11 DMCP 1,1-Dimethy{cyclopentane 8.856 9444 41$1 0.82 0.83 3MH 3-Methylhexane 9.057 32466 14881 2.81 2.95 1G3DMCP 1-cis-3-Dimethylcyclopentane 9.287 13997 6298 1,21 1.25 1T3DMCP 1-trans-3-DimethylcyGopentane 9.440 13079 5857 1.13 1.16 3EP 3-Ethy{perttane 9.459 1463 1257 4.13 4.25 1T2DMCP 1-trans-2-0imethylcyclapentane 9.514 22023 9289 1.90 1.84 NG7 Normal Alkane G7 10.108 88570 39147 7.65 7.76 ISTD Intemai Standard 10.324 40615 17685 3.51 3.51 MGH Mefhylcydohexane 10.959 182786 73$63 15.80 14.66 113TMCP 1,1,3,-Trimethylcyclopentane 11.117 10164 3907 0.88 0.78 ECP Ethylcyt~o~ntane 11.522 6436 2645 0.56 .0.53 124TMCP 1,2,4-Trimethyicyclopentane 11.968 8475 3445 0.73 0.68 123TMCP 1 „2,3-Trimethylcyc~opentar~e 12.336 7225 2876 4.62 0.57 TOL Toluene 12.657 90167 35157 7.79 6.9$ NC8 Norval Alkane C8 15.346 141573 34621 8.78 6.87 IP9 Esoprenoid C9 17.164 11447 4165 4.99 0.83 MXYt_ m-Xytene 18.384 80824 28482 6.99 5:65 PXYI p-Xylene 18.438 23990 9784 2.07 1.94 OXYL a-Xylene 19.628 33714 11456 2.91 2.27 NG9 Normal Alkane C9 21.045 93486 32567 8.08 6.46 {P10 {soprenoid C10 23.015 15414 4827 1.30 4.96 NC10 Normal Alkane C10 26.641 91985 31067 7.95 6.17 IP11 {soprenaid C11 27.930 16983 5679 1.47 1.13 NC11 Normal Alkane C11 31.905 96473 34696 8.34 6.09 NC12 Norval Alkane C12 36.832 85925. 27732 7.43 5.50. IP13 Isoprenoid C13 37.565 22129 6280 1.91 1.25 IP14 Isoprenoid C14 40.328 15349 5047 1.33 4.99. NC13 IP15 Normal Alkane C13 Isoprenoid C15 41.448 44.894 86633 23642 26992 7183 7.49 2.04 5.36 1.43. NC14 Normal Alkane C14 45.787 82250 24913 7.11 4.95 {P16 Isoprenou! C16 48.447 34333 8058 2.97 1.64 NC15 Normal Alkane C15 49.880 82478 22733 7.13 4.51 • • F Company: CONOCOPHILLIPS Client ID: US141080 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289647 Sam lin Point: File Name: G1081128.D NC16 Normal Alkane C16 53.747 70196 20986 6.07 4.17 1P1$ fsoprenoid C18 55.679. 31430 6830 2.72 1:36 NC17 Normal Alkane C17 57.414 67359 19363 5.82 3.84 1P19 lsoprenoid C19 {Pristane} 57.773 38700 7366 3.34 1:46 PHEN Phenanthrene 58.816 5046 1163 0.44 0.23 NC18 hkorma# Alkar~ C38 60.899 58495 171:12 5.06 3.40 fP20 fsoprenoid C20 (Phytane} 61.354 19437 3421 1.68 0.68 NG19 Normal Alkar~ C19 64.217 54914 15877 - 4.75 3.15 - NC20 Normal Alkane C20 67.383 53119 14599 4.59 2.90 NC21 Normal Alkane C21 70.407 463(31 13409 4.00 2.66 C25H61 Highly Branch Isoprenoid C25 70.651 3059 695 0.26 0.14 NC22 Normal Alkane C22 73.303 43182 12158 3.73 2:41.... NC23 Normal Alkane C23 76.080 40111 11129 3.47 2.21 NC24 Norrrral Atkarre C24 78.745 355911 10069 3.08 2.00 NC25 Normal Alkane C25 81.306 32720 8859 2.83 1.76 NC26 Normal Alkane C26 83.772 28668 7779 2.48 i.54 NC27 Normal Alkane C27 86.151 23925 6687 2.07 1.33 NC28 Normal ANcaree C28 88.444 18890 5099. 1.63 1.01 NG29 Normal Alkane C29 90.658 18474 4533 1.60 0.90 NC30 Nomtal ANcar~ C30 92.805 13993 3549. 1.21 0:70 NC31 Normal Alkane C31 94.879 11610 2886 1.00 0.57 NC32 Normal.A~tarae C32 96.7 8353 2202 0.72 0.44 NC33 Normal Alkane C33 98.840 11430 2101 0.99 0.42 NC34 Nomaai Alkane C34 100.732 6585 1511 0.57 0:30 NC35 Normal Alkane C35 102.605 5765 1253 0.50 0.25 NC36 Natural Alkane C36 104.635 3969 753 0.34 0: i 5 NC37 Normal Alkane C37 106.914 3160 559 0.27 O. i 1 NC38 Nomral Alkane C38 109:507 2387 379 0.21 0.08 NC39 Normal Alkane C39 112.508 2134 294 0.18 0.06 NC40 Normal Alkane G40 115.997 1935 210 0.17 0.04 I NC41 Normal Alkane C41 120.053 1675 152 0.15 0.03 • ~ IPI9JIP20 PristanelnC17 IPI9/NC17 PhytanelnC18 IP20MC18 nC18/nC19 NC181NC19 nC17inG29 NCI7JNC29 CPI Mare"' {(NC23+NC25+NC27}+(NC25+NC27+NC29})!(2*{NC24+NC26+NC28}} 100`(NC4+NC5+NG6+NC7+NC8+NC9+NCI O+NCII+NCI2+NG 13+NG14+NC15+NC16+NG17+NC18+NC19+ Norrnat Paraffins NC20+NC21+NC22+NC23+NC24+NC25+NC26+NC27+NC28+NC29+NC30+NC31+NC32+NC33+NC34+ NC35+NC36+NC37+NC38+NC39+NC40+NG41)lTOTAI RESOLVED Isoprenoids 100*(IP9+1P10+IP11+IP13+IP14+IP15+IP16+IP18+IP19+IP20+C25HB1)tCOTAI_RESOLVED Cydoparaffins 100'(CP+MCP+CH+11 DMCP+1 T3DMCP+1 T2 DMCP+MCH+113TMCP+ECP+124TMCP+123TMCP+1 C3DMCP+ 1 C2DMCP)ITOTAL_RESOLVED Branched (iso-) Paraffins 100'(IC4+IC5+22DMB+23DMB+2MP+3MP+22DMP+24DMP+223TMB+33DMP+2MH+23DMP+3MH+3EP)/ TOTAL_RESOLVED BTX aromatics 100*{BZ+TOI+MXYL+PXYL+OXYL)lTOTAL_RESOLVED {-OXYL added 05!2112007) BZlnC6 BZJNC6 TOUnC7 TOL/NC7 (nC6+nC7)!(CH+MCH} (NC6+NC7}J{CH+MCH} lsoheptane Value (2MH+3MH)J{1C3DMCP+1T3DMCP+IT2DMGP) nC7/MCH NC7/MCH CHlMCP CHJMCP nG7/2MH NC712MH nC6122DM6 NC6/22DM6 Heptane Value 100*NC7!(CH+2MH+23DMP+1IDMCP+3MH+1C3DMCP+IT3DMCP+IT2DMGP+MCH+NC7} MCH/nC7 MCH/NC7 mpXYUnC8 (MXYL+PXYL}!NC8 Mango2 P1 100*NC7/(22DMP+24DMP+223TM6+33DMP+2MH+23DMP+11 DMCP+3MH+1 C3DMCP+IT3DMCP+3EP+ IT2DMGP+NC7+MCH+ECP+TOL} P2 100*(2MH+3MH)/(22DMP+24DMP+223TMB+33DMP+2MH+23DMP+11 DMCP+3MH+1 C3DMCP+1 T3DMCP+ 3EP+1T2DMCP+NC7+MCH+ECP+TOL) P3 100*(3EP+33DMP+23DMP+24DMP+22DMP+223TMB)/(22DMP+24DMP+223TMB+33DMP+2MH+23DMP+ 11 DMCP+3MH+i C3DMCP+1 T3DMCP+3EP+1 T2DMCP+NC7+MCH+ECP+TOL} ' 5N1 100*(ECP+1T2DMCP)/(22DMP+24DMP+223TMB+33DMP+2MH+23DMP+11DMCP+3MH+1G3DMCP+ 1T3DMCP+3EP+1T2DMCP+NC7+MCH+ECP+TOL) N2 100*(11DMCP+1 C3DMCP+1 T3DMCP}/{22DMP+24DMP+223TM8+33DMP+2MH+23DMP+11 DMCP+3MH+ 1C3DMCP+IT3DMCP+3EP+IT2DMGP+NC7+MCH+ECP+TOL} 6N 1 100*(MCH+TOL)/(22DMP+24DMP+223TMB+33DMP+2MH+230MP+11 DMCP+3MH+1 C3DMCP+1 T3DMCP+ 3EP+1T2DMCP+NC7+MCH+ECP+TOL) K1 {2MH+23DMP)!(3MH+24DMP} K2 {2MH+3MH}t(2MH+3MH+11 DMCP+1 C3DMCP+1 T3DMCP} 5N 1l6N1 (ECP+1 T2DMCP)!(MGH+TOL} P3M2 {3EP+33DMP+23DMP+24DMP+22DMP+223TM6)/(11 DMCP+1 G3DMCP+1 T3DMCP) In(24DMPl23DMP) In{24DMPl23DMP) Halpem3 Tr1 TOU11 DMCP Tr2 NC7l11 DMCP Tr3 3MHf1 I DMCP Tr4 2MHJ11 DMCP Try (2MH+3MH}!11 DMCP Tr7 1T3DMCPl11 DMCP Tr8 {2MH+3MH}!{22DMP+23DMP+24DMP+33DMP+3EP) C1 22DMP!{22DMP+23DMP+24DMP+33DMP+3EP) C2 23DMP/(22DMP+23DMP+24DMP+33DMP+3EP} C3 24DMP!{22DMP+23DMP+24DMP+33DMP+3EP) C4 33DMP/(22DMP+23DMP+24DMP+33DMP+3EP} C5 3EP/(22DMP+23DMP+24DMP+33DMP+3EP} WGC Parameters PristanelPhytane s • • ~A~~l..iN~ 1..1J'T! IIVC, WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US141081 Country: UNITED STATES Project #: 08-628-A Basin: NORTH SLOPE Lab ID: CP289648 Lease: Sample Type: Separator Oil Block: Sampling Point: 2008 DST Field: RENDEZVOUS Formation: Alpine Fm Well Name: RENDEZVOUS-2 Geologic Age: Jurassic Latitude: 70.15146 Top Depth: 8,350 ft. Lon itude: -151.6855 Bottom De the 8,390 ft PristanetPtrytane Pristaneln C,7 PhYtanefn ~`na n C,~Jn C,9 n C,7/n C~ CPI Marrs"' PtotTrtaf Paraftms Isaprenoids i ~ Brandied (so-) Paraffins BTX aromatics Resolved unknowns 1.~ A. BZIn C~ 0.2'4 0.57 B. TOUn C~ 1.01 0.34 C. (n GB+n C7~{GFI+MCt-t) 0.61 1.06 I. Isoheptane Value 1.27 3.76 f=. n C7tMCH 0.48 1.03 U. CHlMCP 1.56 2&.6 R. n Crl2tulH 2.92 4.2 S. nCQ/22DMB 33.81 7.3 H. Heptane Value 18.13 3.8 MCHIn C7 2.10 4.2 mpXYUnC$ 1.02 50.8 ~Thompsoa K.F.M.,t983.GCA:V.47, p.303. ZMango, ED.,1994.GCA: V.58, p.895. ;Halpern,H.L,1945,AAPG Bu1L: V.79, p.801. °Marzi,1993,OrgG;2Q,130t. Company: CONOCOPHILLIPS Client ID: US141081 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289648 Sampling Point: File Name: G1081129.D IC4 {so-alkane C4 4.071 12601 10091 1.08 1.98 NC4 Normal Aikane C4 4.185 38527. 3052p 3.30 5.97 {C5 iso-a{kane C5 4.611 46781 34057 4.00 6.67 NC5 Normal Aikane C5 4.846 58770 41332 5A3 8.09 22DMB 2,2-Dimethyibutane 5.288 2146 1356 0.18 0.27 CP Cydopentar~ 5.745 8872 5504 0.76 1..08 23DM8 2,3-Dimethyibutane 5.777 6794 4245 0.58 0.83 2MP 2-Methylpentane 5.857 39164 23$70 3.35 4.67 3MP 3-Methylpentane 6.149 25881 15092 2.21 2.95 NG6 Namzal Aikane C6 6.552 72552 41359 6.21 8.10 22DMP 2,2-Dimethylpentane 7.212 2004 1152 0.17 0.23 MGP Methykydopentane 7.269 50846 26229 4.35 5,13 24DMP 2,4-Dimethylpentane 7.402 4435 2168 0.38 0.42 223TM8 2,2,3-Trimethylbutane 7.555 756 316 0.07 0.€~ BZ Benzene 8.019 15469 7070 1.32 1.38 33DMP 3;3-Dimethyipentane 8.226 1353 602 0.12 0.12 CN Cyclohexane 8.341 79289 37124 6.78 7.27 2MH 2-MethylhEexane 8.720 28732 13604 2.46 2.66 23DMP 2,3-Dimethylpentane 8.770 7643 3786 0.65 0.74 11DMGP 1,1-DimethylCydopentane 8.858 9191 4059 4.79 0.80 3MN 1C3DMCP 3-Methylhexane 1-as-3-Dnrethylcycfopentane 9A59 9.289 31080 13385 14303 6058 2.66 1.15 2.80 1,19 1T3DMGP 1-trans-3-DimethylcyGapentane 9.402 12521 5629 1.07 1.10 3EP 3-Ethyipentane 9.461 1522 1259 0.13 0.25 1T2DMCP 1-trans-2-Dimethyicyciopentane 9.515 21180 8989 1.81 1.76 NG7 Normal Aikane C7 10.110 84028 37183 7.19 7.28 1STD Internal Standard 10.326 4056$ 17729 3.47 3.47 MGFi Methylcydahexane 10.960 176516 71099 15.10 13.92 113TMCP 1,1,3,-Trimethyicyclopentane 11.119 9939 3816 0.85 0.75 EGP Ethylcyclopentane 11.524 61.67 2538 0.53 0.50 124TMCP 1,2,4-Trimethylcyclapentane 11.970 $248 3365 0.71 0.66 123TMCP 1,2,3-Trimethylcydopentane 12:338 7047 2806 0.60 0.55 TOL Toluene 12.658 85094 33002 7.28 6.46 NC8 Nomiai Aikane C8 15.307 98842 33607 8.45 6.58 IP9 Isoprenoid C9 17.165 11078 4002 0.95 0.78 MXYL m-Xylene 18.382 779 27485 6.67 5.38 PXYL p-Xylene 18.439 23083 9381 1.97 1.84 OXYL o-Xylene 19.629 32724 11134 2.80 2.18 NC9 Normal Aikane C9 21.046 91647 31794 7.84 6.22 iP10 Isoprenoid C10 23.016 14788 4696 1.27 0.92 NG10 Nomlai Aikane C10 26.642 91425 30778 7.82 6A2 IP11 Isoprenoid C11 27.931 16777 5582 1.44 1.09 NC11 Normal Aikane C11 31.906 95986 30780 821 6.02 NG12 Normal Aikane G12 36.832 86591 27958 7.41 5.47 {P13 isoprenaid C13 37.565 22659 6324 1.94 1.24 {P14 Isoprenoid G14 40.329 15258 5046 1.31 0,99 NG13 Normal Aikane C13 41.448 87033 26941 7.44 5.27 If'15 Esoprenoid C15 44.891 23827 7291 2.04 1.43 NC14 Normal Aikane C14 45.789 83021 25514 7.10 4.99 lP16 Isoprenoid C16 48.446 35104 $101 3.t~ 1.89 NC15 Normal Aikane C15 49.880 83798 23299 7.17 4.56 • • • • Company: CONOCOPHILLIPS Client ID: US141081 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289848 Sam lin Point: File Name: G1081129.D NC16 Normal Alkane C16 tP48 IsoprenoidC48 NC17 Normal Alkane C17 IP19 Isoprenoid C19 {Pristane} PHEN Phenanthrene NC18 Normal ABtane C18 IP20 Isoprenoid C20 {Phytanej NC18 Normal Alkane C19 NC20 Normal Alkane C20 NC21 Normal Alkane C24 C25HBI Highly Branch Isoprenoid C25 NC22 Ncxma# Alkane C22 NC23 Normal Alkane C23 NC24 Normal Alkane C24 NC25 Normal Alkane C25 NC26 Normal.A~cane C26 NC27 Normal Alkane C27 NC28 Nom3al ANcane C28 NC29 Normal Alkane C29 NG30 Normal-Alkane C30 NC31 Normal Alkane C31 NC32 Norrnat ANcane C32 NC33 Normal Alkane C33 NC34 Normal ANcane G34 NC35 Normal Alkane C35 NC36 Norma! A~Cane G36 NC37 Normal Alkane C37 NC38 Normal Alkane C38 NC39 Normal Alkane C39 NC40 Nomral ~&arre C40 NC41 Normal Alkane C41 53.747 71730 21329 6.14 4.18 55.681 31887 6929 2.74 1.36 57.415 68848 19661 5.89 3.85 57.774 39431 _ 755(} ` 3.37, 1.48 58.817 5066 1172 0.43 0.23 60.899 59602.. .. 17853 5.10 3.49 61.351 20085 3601 1.72 0.71 64.220. 56235 16073 4.84 3:15 67.384 54190 15027 4.64 2.94 70.409 46830 13609 4:01 2.66 70.656 3107 704 0.27 0.14 73.305 43818 1241$ 3:75 243 76.081 40696 11406 3.48 2.23 78.746 36227 10172 3.40 1:99 81.307 33278 9194 2.85 1.80 83:775 29327 8076 2.51 1.58 86.152 24333 6612 2.08 1.29 .88.445. 191113 5138 1.63 1:Ot 90.659 18306 4577 1.57 0.90 92.807. 13972 3588 1.20 - 0.70 94.877 11186 2852 0.96 0.56 96.890 8356 2068 0.72 Q.41 1 98.841 11073 1989 0.95 0.39 100.737 6257 1402 0.54 0:2T 102.604 5989 1119 0.51 0.22 .104,636 3414: 576 0.29 0.4 i 106.925 2211 369 4.19 0.07 1~J.509 1907 `265 0.16 0.05 112.513 1498 186 0,13 0.04 115.999 921 1'08- Q08 0.02 120.066 569 79 0.05 0.02 • • • • BAS~UIVE ~~50LEJTiC~''V IWC. WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US140550 Country: UNITED STATES Project #: 08-628-A Basin: NORTH SLOPE Lab ID: CP289068 Lease: Sample Type: DST OIL 1.12 Block: Sampling Point: 2008 DST Field: RENDEZVOUS Formation: Alpine Well Name: RENDEZVOUS-2 Geologic Age: Late Jurassic Latitude: 70.15146 Top Depth: 8,350 ft. Lon itude: -151.6855 Bottom De the 8,390 ft. Pristane/n C„ Phytaneln Cta n C,~In C,4 1 rrC,~InC~ CPI Marra"4 1 t4armaf Paraffns Isoprenaids Branched {iso-) Paraffins BTX arwnatus Resolved unknowns _~ A: BZIa Ca 0.22 .59 B. TpLln C, 1.02 ,33 C. (n Ca*n C,KtGH+MCH} 0.&5 .03 1. tsoheptane Value 1.29 .97 F. n G~tMCH 0.49 .03 U. CH(MCP i.51 9.4 R. n C7f2MF1 2.91 4.0 S. n C~122DM8 34.05 7.6 H. Heptarte Val 18.43 4.3 MCWnC7 2.03 4,5 0 0 3 2 mpXYUnC$ 1.05 ~ [hompson, K.F.M.,1983.GCA:V.47, p.303.''Mango, F.D.,1994.GCA: V.58, p.895. 3Halpem,H.1.,1995,AAPG BuIL~ V_79, p.801. °Maai,1993,OrgG X0,1301. Company: CONOCOPHILLIPS Client ID: US140550 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab lD: GP289068 Sampling Point: File Name: G3080630.D C~ IC4 Iso-alkane C4 3.979 14946 13189 1.36 2.67 NC4 Normal Alkane C4 4.095 51111. 44205 4.65 8:95 IC5 iso-alkane C5 4.525 52315 42028 4.76 8.51 NC5 Normal Alkane C5 4.762 68875. 53029 6.27 10.74 22DMB 2,2-Dimethylbutane 5.209 2268 1530 0.21 0.31 CF Cydopentarte 5.672 9925 6437 0.90 1.30 23DMB 2,3-Dimethylbutane 5.705 7100 4652 0.65 0.94 2MP 2-Methylpentane 5.785 41519 26762 3.78 5.42 3MP 3-Methylpentane 6.081 27059 16641 2.46 3.37 NG6 Normal Alkane C6 6.489 77221 45999 7.03 9:32 22DMP 2,2-Dimethylpentane 7.157 2066 1206 0.19 024 MCP Methylcyctopentane 7.215 521 ~ 27800 4.74 5.63 24DMP 2,4-Dimethylpentane 7.349 4369 2281 0.40 0.46 223TMB 2,2,3-TrlmethyEbutarfe 7.504 660 319 0.~ 0.07 BZ Benzene 7.969 17130 8334 1.56 1.69 33DMP 3,3-Dimethylpentane 8.182 1268 607 0.12 0.12 GH Cyciohexane 8.299 78926 38234 Z18 7J4 2Ml-I 2-Methythexane 8.680 28861 14000 2.63 2.84 23DMP 2,3-Dimethylpentane 8.731 7561 3799 0.69 0.77 11DMCP 1,1-DimeQhylcyclopentane 8.820 $922 4124 0.81 0.84 3MH 3-Methyihexane 9.022 30838 14626 2.81 2.96 1C3DMCP 1~as-3-Dimetttylcyciopentane 9.255 13381 6189 1.22 1.25 1T3DMCP 1-trans-3-Dimethylcyclopentane 9.369 12506 5762 1.14 1.17 3EP 3-Ethylpentane 9.429 1688 .1340 0.15 0.27 1T2DMCP 1-trans-2-Dimethylcyclopentane 9.483 20334 9064 1.85 1.84 NC7 Normal Alkane C7 10.0$1 83957 37800 7.64 7.66 ISTD Internal Standard 10.297 38253 17181 3.48 3.48 MCH Methylcydohexane 10.939 170258 70429 15.49 14.27 113TMGP 1,1,3,-Trimethylcyciopentane 11.100 9540 3765 0.87 0.76 EGP Ethytcyclopentane 11.507 81••65 2585 0.56 0.52 124TMCP 1,2,4-Trimethylcyclopentane 11.956 8072 3326 0.73 0.67 123TMCP 1,2,3-Trime#hyicydopentane 12.327 6859 2773 0.62 0.56 TOL Toluene 12.643 86040 34590 7.83 7.01 NG8 Normal Alkane C8 15.3 94990 33242 8.64. 6.73 IP9 Isoprenoid C9 17.177 10719 3900 0.98 0.79 MXYL m-Xylene 18.388 76594 27296 6.97 5.53 PXYI_ p-Xylene 18.447 22934 9388 2.09 1.90 QXYL o-Xylene 19.641 32196 10842 2.93 2:20 NC9 Normal Afkane G9 21.060 86284 30408 7.85 6.16 1P10 Isoprenoid G10 23.038 13863 4424 1.26 0.90 NC10 Normal Alkane C10 26.665 84247 28660 7.66 5.$1 IP11 lsopre~id C11 27.960 15566 5225. 1.42 1.06 NC11 Normal Alkane C11 31.934 86779 28253 7.90 5.72 NG12 Normal Afkane C12 36.864 77913 25070 7.09 5.08 IP13 Isoprenoid C13 37.601 19817 5548 1.80 1.12 IP14 Isoprenoid C14 40.367 13993 44$5 1.27 0.91 NC13 fP15 Narmai Alkane C13 Isoprenoid C15 41.482 44.928 78286 21604 24496 6757 7.12 1.97 4.96 1.37 NC14 Nonnai Alkane C14 45.824 74387 22793 6.77 4.62 IP16 Isoprenoid C16 48.485 31347 7078 2.85 1.43 NC15 Normal Alkane C15 49.916 74405 20668 6.77 4.19 • • ~J Company: CONOCOPHILLIPS Client ID: US140550 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289068 Sam lin Point: File Name: G3080630.D NC16 Normal Alkane C16 53.783 63270 19094 5.76 3.87 IP18 Isopcenoid C18 55.722 28334 6140 2.58 fi;24 NC17 Normal Alkane C17 57.451 60170 17195 5.47 3.48 tP19 Isopcecroid G19 (Pristarte} 57:805 '35264 6784. 3.21 ' 1:37 PHEN Phenanthrene 58.842 4670 1178 0.43 0.24 NC18 Normal Arcane C1$ 60.934 52916 15658 4.81 3.17 tP20 Isoprenoid C20 (Ptrytane} 61.387 17651 3160 1.61 0.64 NCfi 9 Normal Atkane G19 64250. 51285... fi4286 4.67 2.89 NC20 Normal Alkane C20 67.413 49204 13582 4.48 2.75 NC21 Normal A#cane G21 70.435 44137 12376 4.02 2,51 C25HBi Highfy Branch Isoprenaid C25 70.684 2642 642 0.24 0.13 NC22 Normal Atkane C22 73.327... . 4L1660 11465 3.70 2.32 NC23 Normal Alkane C23 76.100 37059 10365 3.37 2.10 f~1G24 NormaYAAcane G24 78.762 32fi52 8786 2.93 L78 NC25 Normal Alkane C25 81.319 28936 7770 2.63 1.57 NC26 NomraE Alkane C26 83.779. 2316- 6890 228... fi.40 NC27 Normal Alkane C27 $6.152 20476 5537 1.86 i.12 NG28 Normal A~ane G28 88.439 15951 4'118 1 45 13.83 NC29 Normal Alkane C29 90.649 15162 3904 1.38 0.79 NC30 Normal Atkar~ G30 92.788. 11404. 2.807 1.04 0.57 NC31 Normal Alkane C31 94.857 9248 2306 0.84 0.47 NC32 Nama! Alkane G32 96.864 6916. 17t}7 0.63 0:35 NC33 Normal Alkane C33 98.809 9023 1773 0.82 0.36 NC34 Normal Atkane C34 100.700 5613 1214 0.51 025 NC35 Normal Alkane C35 102.554 4514 951 0.41 0.19 NC36 Plamial Atkane G36 fi 04.568 3279 583 0.30 0.1:2 NC37 Normal Alkane C37 106.840 2373 387 0.22 0.08 NC38 Normal AAcane C38 109.429 1481: 238 0.14 0.05 NC39 Normal Alkane C39 112.416 1397 171 0.13 0.04 NC40 tJormal Alkane G40 115:873 1368 130 0.12 0.03 NC41 Normal Alkane C41 119.917 625 65 0.06 0.01 • BASELJNB R~OLUTION INC. WHOLE OIL GC Company: CONOCOPHILLIPS Client ID: US140551 Country: UNITED STATES Project #: 08-628-A Basin: NORTH SLOPE Lab ID: CP289069 Lease: Sample Type: DST OIL 1.13 Block: Sampling Point: 2008 DST Field: RENDEZVOUS Formation: Alpine C Well Name: RENDEZVOUS-2 Geologic Age: Jurassic Latitude: 70.15146 Top Depth: 8,350 ft. Lon itude: -151.6855 Bottom De the 8,390 ft. ~~ ~.J Pristane/Phytane 1.99 A. BZtn Ca 0.23 Pristane/n C„ 0.59 B. TOUn C, 1.07 PhytaneJnC,~ 0.33 C. (nCe+nCr}!(CH+MCH) 0.61 n C,~ln C,9 1.04 I. Isaheptane Value 1.28 n Gin me 3.48 F, n C,1MCFf 0.49 CPI Mani'` 1.03 U. CHlMCP 1.58 Norma! Paraffins 29.5 R. n C.r12Mti 3.42 Isaprenaids 4.2 S. nC~l22DMB 38.20 Cyctaparaffins 7.0 H. tieptarse Vatpae 18.68 Branched (iso-) Paraffins 3.3 MCHIn C.~ 2.06 BTX aromatics 4.5 mpXYUn Cg 1.07 Reso#ved unknowns 51.4 Thompson, K.F.M.,1983.GCA:V.47, p.303. Mango, PD.,1944.GCA; V.58, p.895. 3HaLpem,H.L,1995,AAPG Bull._ VJ9, p.801. ~Marti,1993,OrgG;20,1301 Company: CONOGOPHILLIPS Client ID: US140551 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289069 Sampling Point; File Name: G3080631.D • IC4 Iso-akane C4 3.980 7112 6134 0.64 1.25 NC4 Norma! Alkane C4 4.096 26526 22520 2.39 4.57 IC5 Iso-alkane C5 4.526 32185 25287 2.90 5.14 NC5 Norrnal Alkane C5 4.764 44829 33819 4.04 6:87 22DM6 2,2-Dimethylbutane 5.211 1594 1043 0.14 0.21 CP Cydopentane 5.675 7285 4632 0.66 0.94 23DMB 2,3-Dimethylbutane 5.707 5297 3407 0.48 0.69 2MP 2-Nletfiyipentar:e 5.788 30894 19764 2.78 4.01. 3MP 3-Methylpentane 6.084 20809 12569 1.87 2.55 NC6 Normal Alkane C6 6.492 60897 36156 5.48 7.34 22DMP 2,2-Dimethylpentane 7.160 1688 976 0.15 0.20 MCP Methylcydopentane 7.219 42469 22660 3.82 4.60 24DMP 2,4-Dimethylpentane 7.352 3706 1867 0.33 0.38 223TM6 2,2,3-Trimethylbutane 7.508 570 265 0.05 0.05 BZ Benzene 7.973 14266 7008 128 1.42 33DMP 3,3-Dimethylpentane 8.185 1089 515 0.10 0.11 CH Cyclohexane 8.302 67136 32401 6.04 6.58 2MH 2-Methylhexane 8.684 25224 12117 2.27 2.46 23DMP 2,3-Dimethylpentane 8.735 6674 3322 0.60 0.68 11DMGP 1,1-Dimethylcyelopentane 8.824 7858 3561 0.71 0.72 3MH 3'Methylhexane 9.026 27307 12785 2.46 2.60 1C3DMCP 1-cis-3-Dimethylcycfopentane 9.259 11841 5436 1.07. 1.10 1T3DMCP 1-trans-3-Dimethylcyclopentane 9.373 11128 5087 1.00 1A3 3EP 3-Ethylpentane 9.433 1487 1162 .0.13 0.24 1T2DMCP 1-trans-2-DimethylcyGopentane 9.487 18063 7968 1.63 1.62 NC7 Normal Alkane C7 10.085 76243 34496 6.86 7.01 ISTD Internal Standard 10.302 38320 16987 3.45 3.45 MCH Methylcyclohexane 10.942 156718 64764 14.11 13.15 113TMCP 1,1,3,-TrimethylcyGopentane 11.104 9041 3457 0.81 0.70 ECP Ethylcyclopentane 11.511. 5714 2377 0.51 0.48 124TMGP 1,2,4-Trimethylcyclopentane 11.961 7547 3099 0.68 0.63 123TMCP 1,2,3-Trimethyicyctaperttane 12.331 6449 2592 0.58 0.53 TOI_ Toluene 12.647 81289 32579 7.32 6.62 NC8 Normal Alkane C8 15.310 92262 32340 8.31 6.57 IP9 Isaprenoid C9 17.181 10349 3755 0.93 OJ6 MXYL m-Xylene 18.391 75580 26749 6.$1 5.43 PXYL p-Xyiene 18.450 22694 9284 2.04 1.89 OXYt_ o-Xylene 19.644 31770 10702 2.86 217 NC9 Normal Alkane C9 21.063 85511 30179 7.70 6.13 1P10 Isoprenoid C10 23.041 13691. 4349 123 0.88 NC10 Nam~al Alkane C10 26.667 84076 28946 7.57 5.88 IP11 lsoprenoid C11 27.961 15499 5228 1.40 1.~ NC11 Normal Alkane C11 31.936 87048 28276 7.84 5.74 NC12 Normal Alkane C12 36.865 78499 25282 7.07 5.14 1P13 Isoprenaid G13 37.602 20205 5536 1.82 1.12 fP14 lsoprenoki C14 40.368 14059 4490 1.27 0.91 NC13 Noma[ Alkane C13 41.483 78714 24620 7.09 5.4t} lP15 Isoprenaid C15 44.934 21723 6746 1.96 1.37 NC14 Normal Alkane C14 45.824 74913 23100 6.75 4.69 IP16 Isoprenoid C16 48.486 31970 7209 2.88 1.46 NC15 Normal Alkane C15 49.917 75259 20624 6.78 4.19 • • • Company: CONOCOPHILLIPS Client ID: US140551 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289069 Sam lin Point: File Name: G3080631.D NC16 Normal Alkane C16 lP1$ fsoprenoid G18 NC17 Normal Alkane C17 lPf9 lsaprenoid C19 (Przstane} PHEN Phenanthrene NC18 Normal Alkane C18 IP20 Isoprenofd C20 (Phytane) tVC19 Normai Alkane G19 NC20 Normal Alkane C20 NC21 No~aF Alkane C21 C25HBI Highly Branch lsoprenoid C25 NG22 Normal Alkat~ C22 NC23 Normal Alkane C23 NC24 Normal Alkar~ G24 NG25 Normal Alkane C25 NG26 Plor~ma# Alkar~ C26 NG27 Normal Alkane C27 NC28 Normal AHcane C28 NC29 Normal Alkane C29 NC30 Normal Alkar~ G34 NC31 Normal Alkane C31 NC32 Normal Alkane C32 NC33 Normal Alkane C33 NC34 Norma! Alkane C34 NC35 Normal Alkane C35 NC36 Nomtal Alkane C36 NC37 Normal Alkane C37 NG38 Norzrtal Alkar~ C38 NG39 Normal Alkane C39 NG40 Normal Alkar~ G40 NC41 Normal Alkane G41 53.783 63950 18952 5.76 3.85 55:722` 28636 6145 2.58 1:25 57.451 60706 17907 5.47 3.64 57.80;1. 35573 6881 3.20 1.40 58.845 4691 1210 0.42 0.25 64.934 53456 15727 481, 3,19 61.388 17835 3120 1.61 0.63 64.252. 51382 14402 4.63 2.93 62416 49098 13769 4.42 2.80 70.438 43075' 12466 3.88 2.53 70.686 2892 647 0.26 0.13 73.330. 401.42 1:1325 3.61 2.30 76.102 37392 10606 3.37 2.15 78.761 331 9240 3:02 1.88 81.320 30924 8552 2.78 1.74 83.782' 27230 7307 2.45 1.48 86.152 22851 5979 2.06 1.21 88:449 18088 4794 1.63 0;97 90.653 17445 4454 1.57 0.90 92.793 13213 3324 1.19 0.68 94.864 11018 2768 0.99 0.56 96:865..... $146 2035. 0:73 0.41. 98.815 10109 1978 0.91 0.40 100698 6573 1509 0.59 0:31 102.552 5410 1144 0.49 0.23 .104.575 3$30.. 797 0.35 0.15 106.840 3031 514 0.27 0.10 1(}9.430 ;2395 366 022 - 0.07 112.408 2115 287 0.19 0.06 115.867 2294 221 0.21 0.05 119.915 1483 143 0.13 0.03 • • C J • ~~~ BASELINE RPSOLUTION INC. WHOLE OIL GC Company: CONOCOPHILLlPS Client ID: US140552 Country: UNITED STATES Project #: 08-628-A Basin: NORTH SLOPE Lab ID: CP289070 Lease: Sample Type: DST OIL 2.16 Block: Sampling Point: 2008 DST Field: RENDEZVOUS Formation: Alpine Well Name: RENDEZVOUS-2 Geologic Age: Jurassic Latitude: 70.15146 Top Depth: 8,350 ft. Lon itude: -151.6855 Bottom De the 8,390 ft. C Pris#anelPhytane 2.00 A. BZJn C,~ 0.22 Prisianeln C,~ 0.59 B. TOUn C~ 1.03 Phytaneln C,8 0.33 C. {n Ca+n C,y{CN+taCH) 0.65 n C,~ln C,e 1.03 I. Isoheptane Value 1.30 nC,~JnC~ 3.55 F. nC,JMCH 0.45 CPI Maru~` 1.03 U. CHlMCP 1.51 Normal Paraffins 25.6 R. n C712MH 2.90 isoprenoids 4.0 S. n CBl22DM6 34.61 Cydaparaffins 7.5 ti. Nep#ar~ Value 1&.50 Branched (iso-) Paraffins 4.2 MCHin C, 2.03 BTX anxna#ecs 4.5 mpXYUn Cs i .05 Resolved unknowns 50.1 Thompson, K.F.M.,1983.GCA:V.47, p.303.~Mango, F.D.,1994.GCA: V.58, p.$95, 'Halparn,H.L,1995,AAPG Bull.: V.74, p.801. aMaai~1993,OrgG;2Q1301 • Company: CONOCOPHILLIPS Client ID: US140552 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289070 Sampling Point: File Name: G3080632.D • 1C4 Iso-alkane C4 3.979 15009 13411 1.34 2.62 NC4 Norma! Alkane C4 4.095 51801 45432 4.63 8..89 IC5 Iso-alkane C5 4.525 52072 42700 4.65 8.35 NC5 Normal Alkane C5 4.762 68858 53856 6.15 10.54 22DMB 2,2-Dimethylbutane 5.209 2219 1540 0.20 0.30 CP Cydopentane 5.672 10022 6532. 0.90 1.28 23DMB 2,3-Dimethylbutane 5.704 6945 4664 0.62 0.91 2MP 2-Methytpentane 5.785 41122 27039 3.67 5.29 3MP 3-Methyipentane 6.080 26837 16880 2.40 3.30 NC6 Normal Alkane C6 6.488 76809 47124. 6.86 9.22 22DMP 2,2-Dimethylpentane 7.156 2094 1220 0.19 0.24 MCP Methytcydopentane 7.214 51969 28374 4.64 5.55. 24DMP 2,4-Dimethylpentane 7.348 4267 2296 0.38 0.45 223TMB 2,2,3-Trintethylbutane 7.503 640 322 0.{l6 0..06... BZ Benzene 7.968 17253 8593 1.54 1.68 33DMP 3,3-Dimethylpentane 8.181 1269 617 0.11 0.12 CH Cyclohexane 8.298 78486 39084 7.01 7.65 2MH 2-Methylhexane 8.679 29101 14320 2,60 2.80 23DMP 2,3-Dimethylpentane 8.730 7415 3798 0.66 0.74 11 DMCP 1,1-Dimethylcydopentane $.819 8837 4192 0.79 0.82 3MH 3-Methylhexane 9.021 30858 14835 2.76 2.90 1C3DMCP 1-cis-3-t~imethytcydopentane 9.253 13433 6309 1.20 1.23 1T3DMCP 1-trans-3-Dimethylcyciopentane 9.367 12562 5876 1.12 1.15 3EP 3-Ethytpentane 9.429 1844 14(18 0.17 0.28 1T2DMCP 1-trans-2-Dimethylcydopentane 9,482 24117 9231 1.80 1.81 NC7 Normal Alkane G7 10.080 84500 38634 7.55 7.56 tSTD tntemal Standard 10.296 39196 17892 3.50 3.50 MCH Methytcydohexane 10.938 171511 71120 15.32 13.91 113TMCP 1,1,3,-Trimethylcyclopentane 11.099 9401 3823 0.84 0.75 ECP Ethylc}rdopentara? 11.506 6214 2639 0.56 0.52 124TMGP 1,2,4-Trimethylcyclopentane 11.955 8151 3400 0.73 0.67 123TMCP 1,2,3-Trimettrytcydogentane 12.326 6908 2828 0.62 0.55 TEL Toluene 12.643 87120 35275 7.78 6.90 NC8 Normal Alkane C8 15.305 96210 33671 8.59 6.59 IP9 Isoprenoid C9 17.176 10864 4003 0.97 0.78 MXYt_ mrXytene 18.388 77830 27751 .6.95 5.43 PXYt_ p-Xy{ene 18.447 23269 9565 2.08 1.87 OXYt_ o-Xy[ene 19.641 32554 11131 2.91 2.18 NC9 Normal Alkane C9 21.060 87798 31191 7.84 6.10 tP10 tsopn+rroid C10 23.038 14078 4492 1.26 0.88 NC10 Nom~al Alkane C10 26.666 85786 29250 7.66 5.72 tF11 Isoprenoid C11 27.960 15833 5306 1.41 1.04 NC11 Normal Alkane C11 31.936 88642 28975 7.92 5.67 NGi2 Nom~aE Alkane C12 36.866 79396 25681 7.09 5.02 IP13 Isoprenoid C13 37.603 20123 5630 1.80 1.10 IP14 Isoprenoid C14 40.369 14316 .4584 1.28 0.90 NC13 Normal Alkane C13 41.485 80011 25337 7.14 4.96 tP15 Isoprenoid C15 44.932 22023 6757 1.97 1..32 NC14 Normal Alkane C14 45.826 76070 22993 6.79 4.50 IP16 Isoprenoid C16 48.487 31186 7362 2.79 1.44. NC15 Normal Alkane C15 49.919 75959 20873 6.78 4.08 • • Company: CONOCOPHILLIPS Client ID: US140552 Well Name: RENDEZVOUS-2 Project #: 08-628-Q Depth: - Lab ID: CP289070 Sam lin Point: File Name: G3080632.D NC16 Normal Alkane C16 53.785 64732 19058 5.78 3.73 IPt$ Isoprenoid G28 55.725 28823 6252 258 4.22 NC17 Normal Alkane C17 57.452 61385 17847 5.48 3.49 1P29 Isoprenoid G29 (P[is#ane} 57.802 36024:. 6870 3.22 4.34 PHEN Phenanthrene 58.846 4627 1192 0.41 0.23 NC18 Nomtal Alkane C18 60.936 54121 ' 16058 4.83 3.24 IP20 Isaprenoid G20 (Phytane} 61.394 18009 3196 1.61 0.63 NC19 Normal Alkane C29 64253 52445 14629 4.68 " 2,86 NC20 Normal Alkane C20 67.418 50009 13899 4.47 2.72 NC22 Normal Alkane C2t 70.438 45154 13077 4.03 2:56 C25H61 Highly Branch Isoprenoid C25 70.686 2918 659 0.26 0.13 NC22 Nom~al Alkane C22 73.332 41997 2 2627 3.75 227 NC23 Normal Alkane C23 76.103 38954 11201 3.48 2.19 NC24 Normal Arcane C24 78.763 34796 ' 112 3.14 'l.96 NC25 Normal Alkane C25 81.322 31723 8768 2.83 1.72 NC26 Normal Alkane C26 83.782 27704 ?348 2.47 1:44 NC27 Normal Alkane C27 86.154 22974 6281 2.05 1.23 NC28 NormafiAHcane C28 88.442 18040 4950- 1.62 0.97. NC29 Narmaf Alkane C29 90.654 17296 4426 1.54 0.87 NG30 Normat Alkas~ C30 92.797 1292 2 3159 1.'15 0.62 NC31 Normal Alkane G31 94.866 10369 2578 0.93 0.50 NC32 Nonr3al Alkane C32 96.868 7495 2840 0:67 0.36 NC33 Normal Alkane C33 98.816 9390 1784 0.84 0.35 NC34 Nom3al Alkane C34 100.703 5467.. 1204 0.49 ` , 0.24 NC35 Normal Alkane C35 102.558 4044 829 0.36 0.16 NC36 Normal Alkane C36 104.576 2558 473 023 0.09 NC37 Normal Alkane C37 106.845 1591 278 0.14 0.05 NC38 Normal Alkane C38 109.424.. 2026. 158 0.09 0.03 NC39 Norma) Alkane C39 112.405 729 94 0.07 0.02 NC40 Normal AlkaneC4t) 1.25:870: 741 94 0.07 0.02.. NC41 Normal Alkane C41 • • i E"3A~EtJNE R !_t.lTlG'NV INC. WHOLE OIL GG Company: CONOCOPHILLIPS Client ID: US140553 Country: UNITED STATES Project #: 08-628-A Basin: NORTH SLOPE Lab ID: CP289071 Lease: Sample Type: DST OIL 2.17 Block: Sampling Point: 2008 DST Field: RENDEZVOUS Formation: Alpine Well Name: RENDEZVOUS-2 Geologic Age: Late Jurassic Latitude: 70.15146 Top Depth: 8,350 ft. Lon itude: -151.6855 Bottom De the $,390 ft. PrlstanelPhytane 1.99 A. BZln Cg 0.23 Pristaneln C,T 0.58 B. TO(1n C~ 1.03 Phytane/n C,a 0.33 C. (n C~+n C~}l4Ckl+MGH} 0.64 nC,~inC,9 1.04 I. Isoheptane Value 1.29 n G~~In C~ 3.53 f. n CTMlCH 0.49 CPI Marzl` 1.03 U. CHlRACP 1.52 Normal Paraffins 29.6 R. nC7l2MH 2.90 isoprenoids 4.0 S. n Ce/22DM6 34.64 Cyc~oparaffms 7.6 H. Heptane Vakae 18.49 Branched (iso-} Paraffins 4.2 MCFilnC7 2.03 BTXaromatics 4.5 mpXYUnCB 1.05 Resolved unkrtonms 49.9 Thompson, KF.M.,1983.GCA:V.47, p.303. ZMango. F.D.,1994.GCA: V.5$ p.895. ~Halpern,H1.,1995,AAPG Bull.: V.79, p.801. 'Marzi,1993,GrgG;20,1301. Company: CONOCOPHILLIPS Client ID: US140553 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289071 Sampling Point: File Name: G3080633.D • IC4 Iso-alkane C4 3.979 14921 13454 1.33 2.61 NC4 Normal Alkane C4 4.094 51127 45150 4.56 8.77 IC5 iso-alkane C5 4.525 50982 41965 4.54 8.15 NG5 Norma! Alkane C5 4.762 67635 53412 6.03 10.38 22DM6 2,2-Dimethylbutane 5.210 2214 1528 0.20 0.30 CP Cydopentane 5.673 1ER128 6539 .0.89 1.27 23DMB 2,3-Dimethylbutane 5.706 6847 4635 0.61 0.90 2MP 2-NAethylpentane 5.786 40725 27001 3.63 5.25 3MP 3-Methylpentane 6.082 26635 16920 2.37 3.29 NC6 Norma( Alkane C6 6.4~ 76703 47116 6.83 9.16 22DMP 2,2-Dimethylpentane 7.158 2088 1231 0.19 0.24 MCP Methykcydopentane 7.217. 51900 2$662 4.62 5.57 24DMP 2,4-Dimethylpentane 7.350 4233 2307 0.38 0.45 223TMB 2.2,3-Trimethylbutane 7.5(I6 627 323 0.06 0.06 BZ Benzene 7.970 17404 8686 1.55 1.69 33DMP 3,3-Dimethytpeniane 8.183 1261 621 0.11 0.12 CH Cydohexane 8.300 78692 39232 7.01 7.62 2Mti 2-Methylhexane 8.682 29108 14320 2.59 2:78 23DMP 2,3-Dimethylpentane 8.733 7341 3811 0.65 0.74 11DMCP 1,1-Dimethyk;ydopentane 8.822 8790 4202 0.78. 0.82 3MN 3-Methylhexane 9.024 30794 14947 2.74 2.90 1C3DMCP 1-cis-3-DimethylcyGlopentane 9256 13437 6362 1.20 1.24 1T3DMCP 1-trans-3-Dimethylcyclopentane 9.370 12572 5909 1.12 1.15 3EP 3-Ethytpentane 9.430 1508 1245 0.13 0.24 1T2DMGP 1-trans-2-Dimethylcyctopentane 9.485 20470 9241 1.82 1.80 NC7 Norma! Atkane C7 10.083 .84507 38766 7.53 7.53 1STD Internal Standard 10.300 38947 17859 3.47 3.47 MGH Methytcydohexane 10.941 171347 71590 15.27 i3.9i 113TMGP 1,1,3,-Trimethylcyclopentane 11.101 9302 3827 0.83 0.74 EGP Ethylcydopentane 11.509 6214.. .2658 0.55 0.52 124TMCP 1,2,4-Trimethylcydopentane 11.958 8143 3420 0.73 0.66 123TMCP 1,2,3-Trirr:ethyEcydopentane 12.329 6884 2835 0.61 0.55 TOL Toluene 12.646 87411 35644 7.79 6.93 NC8 Norma( Alkane C8 15.308 95351 33623 8.50 6.53 1P9 Isoprenoid C9 17.179 10542 3907 0.94 0.76 MXYL m-Xylene 18.39(} 76980 27508 6.86 5.35 PXYL p-Xylene 18.449 22939 9446 204 1.84 OXYL o-Xytene 19.642. 32060 1{1974 2.86 .2.13 NC9 Normal Alkane C9 21.062 85620 30536 7.63 5.93 tP10 Esaprenoid C14 23.039 13654 .4378 1.22 0.85 NC10 Normal Alkane C10 26.665 $3290 28497 7.42 5.54 1P11 lsaprenoid C11 27.961 15316 51$1 1.37 1.01 NG11 Normal Alkane C11 31.935 85650 28023 7.63 5.45 NC12 Normal Alkane G12 36.864 77812 25315 6.93 4..92 IP13 Isoprenoid C13 32602 19869 5511 1.77 1.07 1P14 Isoprenoid C14 40.368 13942 4502 1.24 0.88 NC13 tP15 Normal Alkane C13 Esoprenoid C15 41.483 44.931 77799 21397 24529 6642 6.93 1.91 4.77 1.29 NC14 Nom~aP Alkane C14 45.824 73939 22158 6.59 4.31 1P16 Isoprenoid C16 48.487 31105 7086 2.77 1.38 NC15 Normal Alkane C15 49.917 74257 20807 6.62 4.04 • • s • Company: CONOCOPHILLIPS Client ID: US140553 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289071 Sam lin Point: File Name: G3080633.D NC16 Normal Alkane C16 IP1$ Isoprenoid Gt8 NC17 Normal Alkane C17 IP19 Isoprenoid G19 (Fristane) PHEN Phenanthrene NG18 Norma! Alkane C18 IP20 Isoprenoid C20 (Phytane) NC19 No~rna4 A~Carse C19 NC20 Normal Alkane C20 NC21 Norrria4 Alkane C21 C25HBI Highly Branch Isoprenoid C25 NC22 Normal Alkar~ C22 NC23 Normal Alkane C23 NC24 Normal Alkane C24 NC25 Normal Alkane C25 NC26 Normal Alkane C26 NG27 Normal Alkane C27 NC28 Narma4 Alkane C28 NC29 Normal Alkane C29 NC34 Normal A14car~ C30 NC31 Normal Alkane C31 NC32 Normal Afka C32 NC33 Normal Alkane C33 NC34 Nartnat f~lfcane C34 NC35 Normal Alkane C35 NC36 Normal Alkane C36 NC37 Normal Alkane C37 NC38 Normal Alkar~ C38 NC39 Normal Alkane G39 NC40 Nortnaf Alkane C40 NC41 Normal Alkane C41 53.785 63071 18748 5.62 3.64 55.724. 28259 6090 252 , '1.18 57.453 60564 17070 5.40 3.32 57.809 35185 6$65 3.14 1;33 58.846 4546 1204 0.41 0.23 60:935 62997 15596 4;72 3.03 61.392 17693 3181 1.58 0.62 64.252 51146 14680 4.56 2.85 67.416 49714 13917 4.43 2.70 .70.437 44496 12837 3.96 2.49 70.686 2592 645 0.23 0.13 73:331 41624 11782 3.71 2.29 76.105 38498 10571 3.43 2A5 78.764 34552 9743 3.08 1:89 81.321 31223 8502 2.78 1.65 83.783 27214 7583 2.43 1.47 86.156 22701 6322 202 1.23 88.443 17865 4690 1.59 0.91 90.652 17148 4389 1.53 0.85 92.796 12916 3296 1.15 0.64 94.863 10403 2632 0.93 0.51 96.865 7750: 1924 0.69 0.37 98.812 9093 1872 0.81 0.36 100;702. 5790.:. 1249 0.52 0.24 102.563 4261 909 0.38 0.18 '104.581 2485 474 0.22 0>09 106.838 1774 284 0.16 0.06 I 109.4'45:. 1052. '{60 0,09 0.03 112.408 $50 101 0.0$ 0.02 115.$78 513 76 0.05 0.02 i Saturate GC/MS • • ~ BASELINE RES~I~N INC. SATURATE GCMS Company: CONOCOPHILLIPS Client ID: US140552 Country: UNITED STATES Project #: 08-628-A Basin: NORTH SLOPE Lab ID: CP289070 Lease: Sample Type: DST OIL 1.12 Block: .Sampling Point: 2008 DST Field: RENDEZVOUS Formation: Alpine Well Name: RENDEZVOUS-2 Geologic Age: Late Jurassic Latitude: 70.15146 Top Depth: 8,350 ft. Lon itude: -151.6855 Bottom De the 8,390 ft. r~ R]/Z 8: ~(~ teranes M2081229.D IUVIJ~ 1 ~ ~~ ~~ Ir) Z 17: teranes M2081229.D ~ ~ ~~~~ ~ ~~'~'J ~~ ,^ ~r ~ ~ .~.,, ~' ~"' r a¢¢S {218} 32.4 D s a¢¢S {218} 33.4 D a a¢¢S (218} 34.6 D ~ aaaR (217} 35.1 D s aaaR {217} 31.6 D > aaaR (217} 33.4 D }R} (C~ aaa} {217} 0.53 M 0.55 {0.8%} {¢¢S+aaR} {C29} (217} 0.54 M 0.70 {0.9%} `C~}!{Czr~'C28+C2s} (217} 0.13 :~ (a¢¢S) {218} 4.94 D ;zy {a¢¢S) {218} 0.95 D tertaaa Ster {Cr,} {217) 2.65 M/D 1.00 {1.4%} Sierane Irxtex {2i8} 10.64 D OieanartetHopane D/A GammaceranetHopane 0.07 D NorhoparrelHopar~ 4,31 D Bisnofiopane/Hopane 0.04 DiahopanelHapane 0.24 M!D MoretaneMapane 0.11 M 0.05 (0.7°,6} 25-nor-hapanefiopane 8 Tst{Ts+Tm} trisnofiopanes 4.73 M!D 1.00 {1.4°k} C29TslC29 Hopane 0.67 M H32 S/{R+S) Homohopanes - 0.57 M 0.60 {0.6%} H35M3'4 Homohopanes 0.64 D C24 TetracycliclHopane 0.01 D C24 TetracyclictC26 Tricyt~its 0.51 D C23tC24 Tricyclic terpanes 1.06 D C19lC23 Tricyclic terpar~s 0.55 D C26tC25 Tricyclic terpanes 1.33 D {C2g+C2g Tricvdas}Rs 1.28 A ~iopanes 4.26 D terpanesMopanes 0.30 M 1.04 (1.4°k} terpane5lSteranes 1.16 MiEI 1.04 {1.4%} . 'Definition and utility of the ratios can be found on our website www.BaselineDGSl.com ZA=Source Age; D=Depositional environment; M= Maturity; 6=Possible Biodegradation 'Thermal equilibrium value of the biomarker ratio and in brackets the approximate VR value at which this value is reached u • Company: CONOCOPHILLIPS Client ID: US140552 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289070 Sam lin Point: File Name: M2081229.D 217 CHOL 5~3 cholane {internal standard) 125 H30_125 C30 17a{ki}-hopar~ (125} 125 GGAR y-carotane 125 SGAR (3-carotane 177 L246NR1 24,28-bisnoriupane isomer 177 LA248NR 17a(H}24,28-bisnodupane 177 L624BNR 17(3{H}24,28-bisnorlupane 177 i24$NRZ 24,28-bisnortupane isomer 177 L24NOR 24-nortupane 191 TR19 C19 tricyclic terpane 191 TR20 C20 tricyclic terpane 191 TR21 C21 tricyclic terpane 191 TR22 C22 tricyclic terpane 191 TR23 C23 tricyclic ferpane 191 TR24 C24 tricyclic terpane 191 G24DEOL C24 des-A-oleanane 191 C24DElUP C24 des-A-lupane 191 TR25A C25 tricyclic terpane (a) 191 7R25B C25 tricyclic terpane {b) 191 C24DEURS G24 des-A-ucsane 191 C24DEHOP C24 des-E-hopane 191 TET24 C24 tetracydic terpane (TEl} 191 TR26A C26 tricyclic terpane {a) 191 TR268 C26 tricyciic terpane (b) 191 TR28A C28 tricyclic terpane (a) 191 TR288 G28 tricyclic terlrane (b} 191 TR29A C29 tricyclic terpane (a} 191 TR298 C29 tricyclic terpane (b) 191 TS Ts 18a{H}-trisnarhopane 191 TM Tm 17a(H}trisnorhopane 191 TR30A C30 tricyclic terpane (a) 191 TR30i3 C30 tricyclic terpane (b} 191 H28 C28 17a18a21 ~(H)-bisnorhopane 191 NOR25H G29 Na=25-hopane 191 H29 G29 Tm 17a(H)21 ~(H}-norhopane 191 G29TS C2S Ts 18a(H}-nomeohopane 191 DH30 C3017a{H}-diahopane 191 M29 C29 normoretar~ 191 O~ oleanane 191 H30 C3017a(H}-hopane 191 M30 G30 moretane 191 TARAX Taraxerat>e 191 H31S C31 22S 17a(H}hopane 191 H31R G31 22R 17a(H} hopane 191 GAM gammacerane 62.343 10591 2251 100.0 100.0 76535 6116 765 57.7 34.0 88.062 2911 358 27.5 15.9 44.612 1295 218 12.2 9.7 47.666 1328 234 12.5 10.4 50.742 1278 250 321 11.1 53.450 803 96 7.6 4.3 56.428 2358 498 22.3 22.1 57.988 2231 440 21.1 19.5 61.087 832 .200 7.9 8.9 61.152 1164 221 11.0 9.8 63.058 1347 279 12:7 12.4 63.297 1169 261 11.0 11.6 63.492 1478 263 1440 11.7 68.150 1628 368 t 5.4 16.3 68.475 1655 355 15.6 15.8 69.515 2073 454 19.6 20.2 69.905 1650 386 .15,6 17,1 70.902 5466 1223 51.6 54.3 71.794 2071 467 19.6 20.7 72.094 1535 360 14.5 16.0 72.527 167$ 333 15.8 14.8 73.827 872 120 8.2 5.3 74.759 fi344 1468 59.9 65.2 74.889 4276 936 40.4 41.6 75.235 4782 i QO6 45.2 44.7 75.799 784 142 7.4 6.3 76.557 20296 4256 191.6 189..1 77.359 2202 512 20.8 22.7 78.615 7299 1611 68.9 71.6 78.$75 5262 1165 49.7 51.8 79.200 1378 265 13.0 11.8 • .'7 • • • • :ompany: CONOCOPHIL~IPS Client tD: US140552 'Nell Name: RENDEZVOUS-2 Project #: 08-628-A )epth: - Lab ID: CP289070 >ampling Point: Flle Name: M2081229.D 191 H32S C32 22S 17a(H) hopane 80.240 5112 1207 48.3 53.6 191 H32R C32 22R 17a{H) hopane 80.587 3801 846 35.9 3T.6 191 H33S C33 22S 17a(H) hopane 82.104 3916 850 37.0 37.8 .191 H33R C33 22R 17a{H} hopane 82.581 2659 627 25.1 27.9 191 H34S C34 22S 17a{H) hopane 84.054 2726 610 25.7 27.1 191 H34R G34 22R 17a{H) hopane 84.639 2063 391 19.5 17.4 191 H35S C35 22S 17a(H) hopane 86.047 1561 350 14.7 15.5 191 H35R C35 22R 17a{H) hopane 86.827 152t 288 14.4 12.8 217 S21 G21 sterane 53.861 2683 462 25.3 20.5 217 DtA2'tS C27 ~a 20S diasterane 65.723 5985 1418 56.5 83.0 217 C27R C27 as 20R sterane 70.360 2259 369 21.3 16.4 217 C28R C28 as 20R sterane 72.787 2032 217 13.2 9.6 217 C295 C29 as 20S sterane 73.415 2401 453 22.7 20.1 2i7 C296BR C29 f31120R sterane(+5 {Zaa} 73.784 3470 655 32.8 29.1 217 C296BS C29 (3(3 20S sterane 73.935 2504 505 23.6 22.4 217 C29R C29 as 20R sterane 74.715 2148 373 20.3 16.6 218 C27A$BR C27 RR 20R sterane 69.645 4285 920 40.5 40.9 218 C27ABBS G27 ~¢ 20S sterane 69.862 3272 617 30.9 27.4 218 G28ABBR C28 RR 20R sterane 71.942 2561 481 24.2 21.4 218 C28AB8S C28 ¢~ 20S sterarte 72.115 3331 606 31.5 26.9 218 C29ABBR C29 aQ 20R sterane 73.784 3994 823 37.7 36.6 218 G29ABBS C29 ~~ 20S sterane 73.935 3496 744 33.0 33.1 218 C30ABBR G30 6R 20R sterane 75.322 1242 279 11,7 12.4 218 C30A88S C30 ~¢ 20S sterane 75.409 1203 240 11.4 10.7 259 D27S C27 (3a 20S diasterane 65.723 3344 741 31.6 32.9 259 D2?R C27 ~a 20R diastera~ 66.568 2397 534 22.6 23.7 259 D28SA C28 (ia 20S diasterane a 67.803 1598 403 15.1 17.9 259 E?28SB C28 Ra 20S diasteracre b 67.933 1973 380 18.6 16.9 259 D28RA C28 (3a 20R diasterane a 68.714 1607 336 15.2 14.9 259 D28RB G28 ~ 20R diasterane b 68.81)0 1009 26i 9.5 11.6 259 D29S C29 (ia 20S diasterane 69.645 3730 648 35.2 28.8 259 D29R C29 ~a 20R diasterane 70.599 3309 435 312 19.3 259 G30TP1 C30 tetracydic potyprenoid 75.647 363 71 3.4 3.2 259 C30TP2 G30 tetracydic potyprenoid 75.734 356 78 3.4 3.5 • • Company: CONOCOPHILLIPS Client ID: US140552 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289070 Sam lin Point: File Name: M2081229.D 135 IMAM 1-Methyladamantane 135 2MAM 2- damaruane 135 1EAM 1-Ethyladamantane 135 2EAA~! 2-EthyEada~mantane 136 AM Adamantane 149 13QMAM 1,3-Dimethyladamantar~ 149 C14DMAM 1,4-Dimethyiadamantane, cis 149 T14DMAM 1,4-t?imethytadamantane, trans 149 12DMAM t,2-Dimethyladamantane 149 1E3MAM 1-Ethyl-3-methyladamantar~ 163 135TMAM 1,3,5-Trimethyladamantane 163 136TMAM 1,3,6-Tc~nethytadamarstarte 163 Ct34TMAM 1,3,4-Trimethyladamantane, cis t63 T134TMAM t,3,4-Tri~nethytadamantane. trans 163 1E35DMAM 1-Ethyl-3,5-dimethyladamantane 1.77 1357TMAM 1,3.5,7-Tetrarr~ethyt~iamarrtar~ 177 1257TMAM 1,2,5,7-Tetramethyladamantane 1$7 4Mt}t 4-fi+lethytdiarrtarKar~e 187 iMDI 1-Methyldiamantane 187 3MDC 3-Methy~iamantaane 188 D( Diamantane 201 49DMDt 4,9-C~nethykiiamantane 201 1424DMDI 1,4 and 2,4-dimethyldiamantane 204 4,8-Di~nethytdiamantane 201 34DMD! 3,4-Dimethyidiamantane 21fi TrrNnnethytdiamantar~ 13.422 15z6o 17.141 17.976 13.819 15.553 15:699 16.451 17.454 14.132 15.887 16.639 16.765 17.705 1 s.86s 25.560 27.085 28.151 25.121 25.999 27.169 27,378 28.x52 27.413 so 22 a.s 1.0 259 78 2.4 3.5 587 170 5.5 7.6 3112 843 29.4 X7.5 73 21 0.7 4,9 344 114 3.2 5.1 326 124 3.1 5.5 653 237 6.2 10.5 865 257. $.2 11.4. 55 16 0.5 0.7 243 88 2.3 3.3 447 157 4.2 7.0 533 188 5.4 8.4 692 164 6.5 7.3 355 115 664 144 81a 158 790 157 689 172 188 35 287 61 396 76 595 99 208 38 3.4 ss 7.6 7:5 6.5 i.8 2.7 3.7 5.s 2:d • 5.1 6.a 7.0 7.0 ; 7.6 t.6 I~ 2.7 3:4 4.4 1S i• • • • Company: CONOCOPHlLLlPS Client ID: US140552 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289070 Sam lin Point: File Name: M2081229.D Steroids • • %Cy~ a(3(3S (218} 32.4 31.4 °~~ a~~s (218} 33.a 30.8 %CZy a(i~S {218} 34.6 37.8 C~/C~ (a~SS} (218} 0.94 0.83 C~/C~ {a~~S} (218} 0.95 0.81 C~1CM (a~~S} (218} 1.07 1.21 %Cn aaaR (217} 35.1 38.5 %C~ a«aR (217} 31.6 22.6 %C29 aaaR (217} 33.4 38.9 S/R {C~ aaa} (217} 1.12 1.21 Sl{S+R} (C~ a«a} (217} 0.53 0.55 ¢Rl(aa+R¢} {C29) (217} 0.57 0.58 a~~S/aa«R {C~} {217} 1.17 (C~+G~}t(CZT+G~+C~} (217} 0.13 0.12 t?iastedaaa Ster (Cz,} (217} 2.65 3.84 Terpenoids C191C23 Tricyclic terpanes 0.55 0.44 C23/C24 Tricyclic terpanes 1.06 1.13 C26JC25 Tricyclic terpanes 1.33 1.24 C24 Tetracychc/C26 Tticyc6cs 0.52 0.53 C24 TetracycliGHopane 0.07 0.07 Ts/Tm trisnofiopanes 264 2.62 Tsf{Ts+Tm} trisnonc~~panes 0.73 0.72 C29T5lC29 Hopane 0.67 0.64 BisnofiopaneMopane 0.04 0.03 t+tofiopane/liopane 0.31 4.34 t0iahopane/Hoparte 0.24 0.24 t~leananeJHopane GammaceraneMopane 0.07 0.06 Moretar~t{Maretane+Hopane} 0.10 0.11 H32 S!(S+R} Homohopanes 0.57 0.59 H35M:i4 t-lomohopanes 0..64 0.64 (Steranesj/[Hopanesj 0.26 0.23 [Tricyclic terpanes]![Hopanes] 0.30 0.28 [Tricyclic terpanes~[Steranesj 1.16 1.24 DIAAAONDOtD Ratios Methyl Adamantane Index 0.19 0.22 Methyl ~iamantane Index 0.29 0.31 • • Steranes (m/z 217; 218 °loCY7 a[3[iS (2i8} 100`C27ABBS/{C27ABBS+C28ABBS+C29ABBS} %C28 a(3(3S (218} 100"C28ABBS){C27ABBS+C28ABBS+C29ABBS} °loC~ a(3[iS (218) 100'C29ABBS/{C27ABBS+C28ABBS+C29ABBS) %C27 aaaR (217} 100"C27R1(C27R+C28R+C29R) °1oC28 aaaR {217) 100'G28R!(C27R+C28R+C29R} °loC2q aaaR (217) 100'C29R/(C27R+C28R+C29R} S/R {C~ aaa} (217} C29S/C29R S/(S+R} {C~ aaa) {217} C29St(C29S+C29R} ~¢St(aaR+Q~S} (C~) {217} (C29BBS+C29BBS)/(C29R+C29BBS+C29BBS+C29R) ~#3/(aa+R~) (C~} (217) {C29BBR+C29BBS)/(C29S+C296BR+C29BBS+C29R) as[3SIaaaR (C~) (217) C29BBS/C29R (G27+G22)/{G27+G28+C'29) (217) (S21+S22)/(DIA27S+DIA27R+DIA28SA+DIA28S6+DIA28RA+DIA28RB+C27S+BB_D29S+C27BBS+C27R+ DIA29R+C28S+C288BR+C286BS+C28R+C29S+C29BBR+C29BBS+C29R} C2?/Cny (a~[3S) (218) C27ABBS/C29ABBS C2s/CZy (a~[iS} (218) C28A68S/C29ABBS C~(C27 {a(3~S) (218} C29ABBS/C27ABBS Diaster/aaa Ster (C2~} {217} (DIA27S+DIA27R}!(C27S+C27R) C30 Sterane Index (218} 100*C30ABBS/(C27ABBS+C28ABBS+C29ABBS+C30ABBS} Terpanes (mfz 191) OleananeMopane OLtH30 GammaceranetHopane GAM/H30 Norhopane/Hopane H29/H30 Bisnorfiopane/Hopane H28lH30 Diahopane/Hopane DH30/H30 Moretane/Hopane M30/H30 Moretane/(Moretane+Hopane) M30i(M30+H30} 25-nor-hopaneihopane Nor25H/H30 Ts/Tm trisnorhopanes TSiTM Ts!(Ts+Tm) trisnorhopanes TS!{TS+TM} G29Ts/C29 Hopane C29TS/H29 H32 S/(R+S} Homahopanes H32Sf{H32R+H32S} H35/H34 Homohopanes {H35R+H35S}/(H34R+H34S} C24 TetracycliGHopane (TET24)lH30 G24 TetracydiGC26 TricyGics (TET24)/(TR26A+TR26B} C23/C24 Trcycic terpanes Tr23/T24 C19/C23 Trcycic terpanes Tr19/T23 C26IC25 Trcycic terpanes (TR26A+TR26B}/(TR25A+TR25B} (C28+C29 Tricyclics}ITs {Tr28A+Tr286+Tr29A+Tr296}ti'S Various (mlz 191; 217) (DIA27S+DIA27R+DIA2$SA+DlA28SB+DIA28RA+DIA28RB+C27S+BB D29S+C27BBS+C27R+DIA29R+ [Steranesj![Hopanes] C2&S+C288BR+C28BBS+C28R+C29S+C29BBR+C29BBS+C29Ru(TS+TM+H2&+H29+C29TS+DH30+H30+ H31R+H31S+H32R+H32S+H33R+H33S+H34R+H34S+H35R+H35S} (TR19+TR20+TR21+TR22+TR23+TR24+TR25A+TR25B+TR26A+TR26B+TR28A+TR286+TR29A+TR29B+ [Tricyclic terpanes]/[Hopanes] TR30A+TR308}!(TS+TM+H28+H29+C29TS+DH30+H30+H31R+H31S+H32R+H32S+H33R+H33S+H34R+ H34S+H35R+H35S) (TR19+TR20+TR21+TR22+TR23+TR24+TR25A+TR25B+TR26A+TR26B+TR28A+TR2$B+TR29A+TR29B+ [Tricyclic terpanes]![Steranes] TR30A+TR30B)/(DIA27S+DIA27R+DIA28SA+DIA28S8+DIA28RA+DIA28RB+C27S+BB D29S+C27BBS+ C27R+DIA29R+C28S+C288BR+G2866S+C28R+C29S+C29BBR+C296BS+C29R) DIAMONDOID Ratios MethylAdamantane index 1MAMI(1MAM+2MAM) Methyl Diamantane Index 4MDI/(1MDI+3MDI+4MDI} Saturate GC/MS/MS • • • ~ BASELINE R~I~J~ION, INC. SATURATE GCMSMS RESULTS SATURATE GCMSMS ANALYSIS CLIENT ID: FRACTION: BASELINE ID: DATAFILE: US140552 SATURATE CP289070 MS080260.D • • LJ U BASEI~NE RE50LUTiON, INC. SATURATE GCMSMS Company: CONOCOPHILLIPS Project #: 08-628-A Country: UNITED STATES Lab ID: CP289070 Basin: NORTH SLOPE Client ID: US140552 Lease: Sample Type: DST OIL 1.12 Block: Sampling Point: 2008 DST Field: RENDEZVOUS Formation: Alpine Well Name: RENDEZVOUS-2 Geologic Age: Late Jurassic Latitude: 70.15146 Top Depth: 8,350 ft. Lon itude: -151.6855 Bottom De the 8,390 ft. Steranes 31.4 D Steranes 28.3 D Steranes 40.3 D Diasteranes 38.5 D Diasteranes 28.4 D Diasteranes 35. i D Sterane Index 0.11 D isoln-propyl sterane Index A a¢¢i(aaa+a¢¢} 0.69 M a¢¢i(aaa+a¢¢} 0.74 M a¢¢r`(aaa+a¢¢} 0.72 M a¢¢'(aaa+a¢¢} 0.70 M s~(s+R} o.s2 M S!(S+R} 0.50 M S/{S+R) 0.57 M S/(S+R} 0.41 M teranestSteranes 2.22 ordiachotestane ratio (NDR} 0.20 A orcholestane ratio {NCR} 0.42 A orchoiestane ratio 0.17 DIM sterane ratio A ethyl sterane ratio 0.19 A ane Index (%) A Oleanane Index (°!°} A iacerane Index (°!°} 0.3 D Wane Index (°!°} A/D pane Index (°!°) 15.8 D 0.10 D ur website www.BaselineDGSl.com ZA=Source Age; D=Depositional environment; M= Maturity 'Thermal equilibrium value of the biomarker ratio and in brackets the approximate VR value at which this value is reached • • • Company: CONOCOPHI~LIPS Client ID: US140552 Well Name: RENDEZVOUS-2 Lab ID: CP289070 Top Depth: Fraction: SATURATE Bottom Depth: File Name: MS080260.D ACgU1SItlOn Parameters: SAT 0.2UL 1000/1 RES 70EV 700UA 250C AR=5E-7MBAR CE=25 330.3->217.2: intemai Standard ISTD 5¢-Chotane 50.574 830913 1~.0 100.0 358.3->217.2: C26 Desmethyisteranes D26N24baS 13¢,17«,24-nordiacholestane20S 51.667 13221 1.6 1.6 D26N24baR 13¢,17«,24-nordiacholestane20R 52.734 13025 1.6 1.6 D26N27baS 13¢,17«,27-nordiacholestane20S 53.560 56165 6.8 6.8 D26N24abS 13«,17¢,24-nordiacholestane 20S 53.720 7088 0.9 0.9 D26N24abR 13«,17¢,24-nordiacholestane20R 54.413 10955 1.3 1.3 D26N27baR 13¢,17«,27-nordiacholestane20R 54.627 47225 5.7 5.7 D26N27abS 13a,17p,27-nordiacholestane 20S 55.693 16207 2.0 2.0 D26N27abR 13«,17¢,27-nordiacholestane 20R 56.199 20788 2.5 2.5 S26N24aaaS 5«,14«,17«,24-norcholestane 20S 57.293 3514 0.4 0.4 S26N24abbR 5«,14¢,17¢,24-norcholestane 20R 57.479 8467 1.0 1.0 S26N24abbS 5«,14¢,17¢,24-norcholestane 20S 57.932 12113 1.5 1.5 S26N24aaaR 5«,14«,17«,24-norcholestane20R 58.599 6032 0.7 0.7 S26N21 21-norcholestane 58.759 14942 1.8 1.8 S26N27baaR 5¢,14«,17«,27-norcholestane20S 58.945 3531 0.4 0.4 S26N27aaaS 5«,14«,17«,27-norcholestane 20S 59.079 11504 1.4 1.4 S26N27abbR 5«,14¢,17¢,27-norcholestane 20R 59.239 10706 1.3 1.3 S26N27abbS 5«,14¢,17¢,27-norcholestane 20S 59.559 10450 1.3 1.3 S26N27aaaR 5«,14«,17«,27-norcholestane 20R 60.252 9656 1.2 1.2 372.3->21T.2: C27 [3esmethyisteranes 027baS 13¢,17«-diacholestane 20S 55.640 580207 69.8 51.4 D27baR 13¢,17«-diacholestane 20R 56.973 367738 44.3 45.6 D27abS 13«,17¢-diacholestane20S 57.932 164171 19.8 12.2 D27abR 13«,17¢-diacholestane 20R 58.626 180643 21.7 20.5 S27aaaS Sa,14a,17a-cholestane20S 61.292 73838 8.9 6.1 S27abbR Sa,14¢,17¢-cholestane20R 61.611 99645 12.0 13.4 S27abbS 5«,14¢,17¢-cholestane 20S 61.905 86180 10.4 12.5 S27aaaR 5«,14«,17«-cholestane 20R 62.705 60292 7.3 5.7 38&.4->21T.2: C28 Desmethyfstecanes D28baSA 13¢,17«-diaergostane 20S (24S) 58.786 235904 28.4 22.1 D28baS6 13¢,17«-diaergostane 20S (24S) 58.999 239750 28.9 22.3 D28baRA 13¢,17«-diaergostane 20R (24R) 60.252 160997 19.4 12.6 D28baR6 13¢,17«-diaergostane 20R (24R) 60.358 171524 20.6 18,7 D28abS 13«,17¢-diaergostane 20S 61.158 133353 16.0 16.0 D28abRA 13«,17¢-diaergostane20R 62.065 79025 9.5 9.5 D28abR6 13«,17¢-diaergostane 20R 62.145 76928 9.3 9.3 C28UNK9 C28 Unknown 9 62.918 58932 7.1 7.1 S28aaaSA Sa,14a,17a-ergostane 20S 64.651 18725 2.3 1.9 S28aaaS6 5«,14«,17«-ergostane 205 64.757 30251 3.6 2.6 S28baaR 5¢,14«,17«-ergostane20R S28abbR 5«,14¢,17¢-ergostane20R 65.131 99016 11.9 13.7 S28abbS Sa,14¢,17¢-ergostane20S 65.397 81775 9.8 11.5 S28N21 21-norstigmastane 65.850 18275 2.2 2.2 S28aaaR 5«,14«,17«-ergostane 20R 66.410 44768 5.4 4.4 • • • . • • Company: CONOCOPHILLIPS Client ID: US140552 Well Name: RENDEZVOUS-2 Lab ID: CP289070 Top Depth: Fraction: SATURATE Bottom Depth: File Name: MS080260.D ACgUlSitlOn Parameter3: SAT 0.2UL 1000/1 RES 70EV 700UA 250C AR=SE-7MBAR CE=25 4~.4->217.2: C29 Desm~ethylsteranes D29baS 13p,17a-diastigmastane 20S D29baR 13p,17a-diastigmastane 20R D29abS 13a,17~3-diastigmastane 20S D29abR 13a,17R-diastigmastane 20R C29UNK5 C29 Unknown 5 S29aaaS 5a,14a.17a-stigmastane 20S S29abbR Sa,14(3,17(i-stigmastane 20R S29baaR 5p,14a,17a-stigmastane 20R S29abbS Sa,14(3,17~3-stigmastane 20S S29aaaR 5a,14a,17a-stigmastane 20R 414.4->217.2: C30 Desmett7ytsteranes D30nPbaSA 13p,17a-dia-24-n-propylcholestane 20S D30nPbaSB 13p,17a-dia-24-n-propylcholestane 20S D30nPbaR 1313,17a-dia-24-n-propylcholestane 20R D30nPabSA 13a,17(3-dia-24-n-propylcholestane20S D30nPabS6 13a,17p-dia-24-n-propylcholestane 20S D30nPabR 13a,17(i-dia-24-n-propylcholestane 20R DC30UNK7 dia-C30 Unknown 7 DC30UNK8 dia-C30 Unknown 8 DC30UNK8A dia-C30 Unknown 8A S30nPaaaS 5a,14a,17a-24-n-propylcholestane 20S C30UNK10 C30 Unknown 10 S30iPaaaS 5a,14a,17a-24-iso-propylcholestane 20S S30nPabbR Sa,14(3,17(3-24-n-propylcholestane20R S30nPabbS Sa,14p,17p-24-n-propylcholestane20S S30nPbaaR Sp,14a,17a-24-n-propylcholestane 20R S30iPabbR Sa,14p,17p-24-iso-propylcholestane 20R S30nPaaaR 5a,14a,17a-24-n-propylcholestane 20R C30UNK14 C30 Unknown 14 S30iPaaaR 5a,14a,17a-24-iso-propylcholestane 20R C30UNK16 C30 Unknown 16 38fi.4->231.2: C28 Nlethytsteranes 61. 638 583256 70.2 48.5 63. 158 450638 54.2 45.0 63. 798 158039 19.0 19.0 64. 971 211254 25.4 25.4 65. 770 123977 14.9 14.9 67 .423 81892 9.9 7.8 68 .010 132164 15.9 16.8 68 .197 150006 18.1 17.9 69 .423 71413 8.6 5.9 63. 851 86540 10.4 7.6 63. 931 87767 10.6 7.3 65 .531 126558 15.2. 13.8 65. 904 21036 2.5 2.5 66. 064 24409 2.9 2.9 67. 343 60627 7.3 7.3 67. 850 22873 2.8 2.8 68. 010 9196 1.1 1.1 68. 170 21940 2.6 2.6 69. 636 22425 2.7 1.9 69. 796 6525 0.8 0.8 70 .383 43926 5.3 6.0 70. 516 39045 4.7 4.9 70. 623 9657 1.2 1.2 71. 929 24649 3.0 2.8 D283MbaS 3(i-Methyl-13a,17a-diacholestane ZOS 57.133 26945 3.2 3.2 DC28UNK16 dia-C28 Unknown 16 57.932 34107 4.1 4.1 D283MbaR 3(3-Methyl-13p,17a-diacholestane 20R 58.519 22177 2.7 2.7 DC28UNK3 dia-C28 Unknown 3 58.759 10172 1.2 1.2 DC28UNK17 dia-C28 Unknown 17 59.292 26744 3.2 3.2 D284MbaS 4a-Methyl-13(i,17a-diacholestane20S 59.745 62291 7.5 7.5 D284MbaR 4a-Methyl-13p,17a-diacholestane 20R 61.052 33571 4.0 4.0 S283MaaaS 3(3-Methyl-Sa,14a,17a-cholestane20S 62.838 15764 1.9 1.9 S283MabbR 3p-Methyl-5a,14p,17p-cholestane20R 63.211 22199 2.7 2.7 S283MabbS 3p-Methyl-5a,f4(3,17p-cholestane20S 63,478 22755 2.7 2.7 S284MaaaS 4a-Methyl-Sa,14a,17a-cholestane 20S 63.984 10956 1.3 1.3 S284MabbR 4a-Methyl-5a,14(3,17R-cholestane 20R 64.144 18858 2.3 2.3 S283MaaaR 3p-Methyl-5a,14a,17a-cholestane 20R 64.224 10452 1.3 1.3 S284MabbS 4a-Methyl-5a,14p,17p-cholestane 20S 64.437 16589 2.0 2.0 S284MaaaR 4a-Methyl-5a,14a,17a-cholestane20R 65.371 11096 1.3 1.3 XS28aaaR Sa,14a,17a-ergostane 20R • • Company: CONOCOPHILLIPS Client ID: US140552 Well Name: RENDEZVOUS-2 Lab ID: CP289070 Top Depth: Fraction: SATURATE Bottom Depth: File Name: MS080260.D AC UISItIOn Parameters: SAT 0.2UL 100011 RES 70EV 700UA 250C AR=5E-7MBAR CE=25 400.4-->231.2: C29 Methylsteranes D293MbaSA 3p-Methyl-13(3,17a-diaergostane 20S 60.199 11948 1.4 1.4 D293MbaS6 3(3-Methyl-13(3,17a-diaergostane 20S 60.438 9562 1.2 1.2 DC29UNK27 dia-C29 Unknown 27 60.945 16361 2.0 2.0 DC29UNK28 dia-C29 Unknown 28 61.185 15972 1.9 1.9 D293MbaRA 3p-Methyl-13p,17a-diaergostane 20R 61.745 6779 0.8 0.8 D293MbaRB 3p-Methyl-13R,17a-diaergostane 20R 61.851 7675 0.9 0.9 D294MbaSA 4a-Methyl-13(3,17a-diaergostane 20S 62.785 39295 4.7 4.7 D294MbaS6 4a-Methyl-13(3,17a-diaergostane 20S 62.998 40392 4.9 4.9 D294MbaRA 4a-Methyl-13p,17a-diaergostane 20R 64.251 24610 3.0 3.0 D294MbaR6 4a-Methyl-13p,17a-diaergostane 20R 64.357 28521 3.4 3.4 D294MabS 4a-Methyl-13a,17p-diaergostane 20S 65.157 22121 2.7 2.7 D294MabRA 4a-Methyl-13a,17p-diaergostane 20R 66.064 24607 3.0 3.0 S293MaaaSA_4abRB 3p-Methyl-Sa,14a,17a-ergostane 20S + 66.117 16127 1.9 1.9 4a-methyl-13a,17b-diaergostane 20R S293MaaaS6 3p-Methyl-5a,14a,17a-ergostane 20S 66.250 6282 0.8 0.8 S293MabbR 3(3-Methyl-5a,14p,17(3-ergostane 2oR 66.677 17010 2.0 2.0 S293MabbS 3(3-Methyl-5a,14(3,17(3-ergostane 20S 66.944 23137 2.8 2.8 S294MaaaSA 4a-Methyl-Sa,14a,17a-ergostane20S 67.290 6918 0.8 0.8 S294MaaaS6 4a-Methyl-5a,14a,17a-ergostane20S 67.370 8342 1.0 1.0 S294MabbR 4a-Methyl-5a,14p,17p-ergostane 20R 67.583 19997 2.4 2.4 S294MabbS_3MaaaR 4a-Methyl-5a,14p,17p-ergostane20S+ 67.877 36846 4.4 4.4 3b-Methyl-Sa,14a,17a-ergostane 20R S294MaaaR 4a-Methyl-5a,14a,17a-ergostane20R 68.970 11698 1.4 1.4 XS29aaaR Sa,14a,17a-stigmastane20R 69.450 5410 0.7 0.7 414.4->23L2: C30 Methylsteranes S302MaaaS 2a-Methy{-5a,14a,17a-stigmastane 20S 68.383 8996 1.1 1.1 S303MaaaS 3(3-Methyl-5a,14a,17a-stigmastane 20S + (coelution) 68.863 44066 5.3 5.3 S302MabbR 2a-Methyl-5a,14(3,17p-stigmastane 20S + (coelution) 69.050 5085 0.6 0.6 S302MabbS 2a-Methyl-5a,14p,17(3-stigmastane20S 69.130 6786 0.8 0.8 S303MabbR 3p-Methyl-Sa,14p,17p-stigmastane 20R 69.476 28950 3.5 3.5 BBDINO RR-lino (?) S303MabbS 3b-Methyl-Sa,14b,17b-stigmastane 20S + (coelution} 69.69 24790 2.9 2.9 S304MaaaS 4a-Methyl-5a.14a,17a-stigmastane 20S 69.983 10516 1.3 1.3 S304MabbR 4a-Methyl-Sa,14p,17R-stigmastane 20R 70.383 18845 2.3 2.3 S304MabbS_2MaaaR 4a-Methyl-Sa,14p,17(3-stigmastane 20S + 70.623 22331 2.7 2.7 2a-Methyl-Sa,14a,17a-stigmastane 20R + (coelution) S303MaaaR 3p-Methyl-5a,14a,17a-stigmastane 20R + (coelution) 70.836 18927 2.3 2.3 DS4aSS20R 4a,23S,24S-trimethyl-20R-cholestane DS4aSR20R 4a,23S,24R-trimethyl-20R-cholestane S304MaaaR 4a-Methyl-Sa,14a,17a-stigmastane 20R 71.929 11464 1.4 1.4 DS4aRR20R 4a,23R,24R-trimethyl-20R-cholestane DS4aR520R 4a,23R,24S-trimethyl-20R-cholestane • • • • C~ • Company: CONOCOPHILLIPS Client ID: US140552 Well Name: RENDEZVOUS-2 Lab ID: CP289070 Top Depth: Fraction: SATURATE Bottom Depth: File Name: MS080260.D AC UISItIOn Parameters: SAT 0.2UL 100011 RES 70EV 7000A 250C AR=SE-7MBAR CE=25 414.4->259.2: Tetracyclic polyprenoids and C30 3~propylsteranes S303PaaaS 3p-Propyl-Sa,14a,17a-cholestane 20S 70.756 5010 0.6 0.6 PP1 Tetracyclic polyprenoid 70.916 8390 1.0 1.0 PP2_S303PabbR Tetracyclic polyprenoid+ 3p-propyl-5a,14p,17p-cholestane 20R 71.049 11098 1.3 1.3 S303PabbS 3p-Propyl-Sa,14p,17p-cholestane 20S 71.316 7296 0.9 0.9 S303PaaaR 3p-Propyl-5a,14a,17a-cholestane 20R 72.089 5590 0.7 0.7 414.2->191.2: Petnacyclic Triter~noids REARNGHOP Rearranged hopane 64.571 34935 4.2 4.2 OLEANOIDI3 5{4-~3)abeo-3a(H), 5p-Oleanane TRITERPI4 C30 unknown triterpane OLEANOIDI5A Oleanoid OLEANOIDIS Oleanoid OLEANOIDI6 Oleanoid C30UNKT2 5(4-->3)abeo-3{3(H)-Oleanane 69.103 37399 4.5 4.5 OLEANOIDI7 3(3-methyl-24-nor-1(10->5)abeo-10p(H), 18a-oleanane 69.503 8721 1.1 1.1 TRITERPI7A C30 plant terpane DH30 Diahopane 70.116 147974 17.8 17.8 TRITERPIB C30 unknown triterpane 70.596 15204 1.8 1.8 OL18a 18a Oleanane OL18b 18(3 Oleanane H30ab 17a, 21 p-Hopane 72.142 536807 64.6 95.1 H30N30 30-Norhomohopane 72.382 16778 2.0 2.0 H30TS 18a,17p-Neohopane 72.782 32283 3.9 3.9 H30aa 17a, 21a-Hopane 73.049 22167 2.7 2.7 H30ba 17p, 21a-Hopane (Moretane} 73.342 37702 4.5 8.6 GamA Gammacerane-A 76.008 4703 0.6 0.2 GamB Gammacerane-B 76.141 4236 0.5 0.1 414.2->3i3.3: Bicadinanes B30W Bicadinane W (cis,cis,trans) 630T Bicadinane T (trans, trans, trans) 830T1 Bicadinane T1 B30R Bicadinane R 274.3->203.2: Norpregnanes NORPREGI Norpregnane-1 NORPREG2 Norpregnane-2 NORPREG3_4 Norpregnane-3+Norpregnane-4 31.192 15319 1.8 1.8 NORPREGS Norpregnane-5 31.432 3948 0.5 0.5 NORPREG6 Norpregnane-6 31.752 15460 1.9 1.9 NORPREG7 Norpregnane-7 32.312 4363 0.5 0.5 NORPREG8_9 Norpregnane-8+Norpregnane-9 32.819 51452 6.2 6.2 NORPREGIO Norpregnane-10 33.112 15640 1.9 1.9 NORPREGII Norpregnane-11 33.832 12514 1.5 1.5 NORPREGI2 Norpregnane-12 34.605 3428 0.4 0.4 • • • Company: CONOCOPHILLIPS Client ID: US140552 Well Name: RENDEZVOUS-2 Lab ID: CP289070 Top Depth: Fraction: SATURATE Bottom Depth: File Name: MS080260.D AC UlSltlon Parameters: SAT 0.2UL 1000!1 RES 70EV 7000A 250C AR=5E-7MBAR GE=25 • • • • • r~ ~~ Steranes °kC27 Steranes (372->217,386->217,400->217} %CZB Steranes (372->217,386->217,400->217} %C~ Steranes (372->217,386->217,400->217} %Cpl Diasteranes {372->217,386->217,400->217) %CZg Diasteranes (372->217,386->217,4~->217) °!°CZy Diasteranes (372->217,386->217,400->217} 100`(S27aaaS+S27abbR+S27abbS+S27aaaR}/(S27aaaS+S27abbR+S27abbS+S27aaaR+S28 aaaSA+S28aaaSB+S28abbR+S28abbS+S28aaaR+S29aaaS+S29abbR+S29atrbS+S29aaaR) 100'(S28aaaSA+S28aaaSB+S28abbR+S28abbS+S28aaaR)/(S27aaaS+S27abbR+ S27abbS+S27aaaR+S28aaaSA+S28aaaSB+S28abbR+S28abbS+S28aaaR+S29aaaS+ S29abbR+S29abbS+S29aaaR) 100`(S29aaaS+S29abbR+S29abbS+S29aaaR}!(S27aaaS+S27abbR+S27abbS+S27aaaR+S28 aaaSA+S28aaaSB+S28abbR+S28abbS+S28aaaR+S29aaaS+S29abbR+S29abbS+S29aaaR) 100'(D27baS+D27haR}J(D27baS+D27baR+D28baSA+D28baSB+D28baRA+D28baRB+ D29baS+D29baR) 100*(D28baSA+O28baS6+D28baRA+D28baRB)/(D27baS+D27baR+D28baSA+D28baSB+028 baRA+D28baR6+D29baS+D29baR) 100`(D29baS+D29baR}f(D27baS+D27baR+D28baSA+D28baS6+D28baRA+D28baR6+ D29baS+D29baR) (S30NPaaaS+S30NPabbR+S30NPabbS+S30NPaaaR}!(S27aaaS+S27abbR+S27abbS+ C~ SteraneEndex{414->217} S27aaaR+S28aaaSA+S28aaaSB+S28abbR+S28abbS+S28aaaR+S29aaaS+S29abbR+ S29abbS+S29aaaR+S30NPaaaS+S30NPabbR+S30NPabbS+S36NPaaaR} C~ iso/n-propyl Sterane index (414->217} (S30iPaaaS+S30iPaaaR)/{S30NPaaaS+S30NPaaaR+530iPaaaS+S30iPaaaR} C27 a~(it(aaa+a{i(3j (372->217) (S27abbR+S27abbS}/{S27aaaS+S27abbR+S27abtrS+S27aaaR} C28 a(i~/(aaa-ru(in) (386->217} (S28abbR+S28abbS}!(S28aaaSA+S28aaaSB+S28abbR+S28abbS+S28aaaR} C29 a~(i`(aaa+aQ(i} (400->217} {S29abbR+S29abbS}!{S29aaaS+S29abbR+S29abbS+S29aaaR} C30 a(3~r(aaa+a(3(i) (414->217) {S30NPabbR+S30NPabb5)/{S30NPaaaS+S30NPabbR+S30NPabbS+S30NPaaaR} Cz7 S!{S+R) {372->217} S27aaaS/(S27aaaS+S27aaaR} C~ S%(S+R} {386->217} (S28aaaSA+S28aaaSB}!(S28aaaSA+S28aaaSB+S28aaaR} CZy S/(S+R) (400->217} S29aaaSt{S29aaaS+S29aaaR} C~ S!(S+R} (414->217) (S30NPaaaS}/(S30NPaaaS+S30NPaaaR) (D27baS+D27baR+D28baSA+D28baS6+D28baRA+D28baR6+D29baS+D29baR! Diasteranes/Steranes (S27aaaS+S27abbR+S27abbS+S27aaaR+S28aaaSA+S28aaaSB+S28abbR+S28abbS+ S28aaaR+S29aaaS+S29abbR+S29abbS+S29aaaR) 24-Nordiacholestane Ratio (NDR} (358->217} 24-Norchotestane Ratia (NCR) (358->217) 21-Norcholestane Ratio (358->217} Dinosterane Ratio (414->231) 4-Methyl Sterane Ratio (400->217,414->231) Terpanes Oteanane Index (°!°} (412->191} Gammacerane Index (%} (412->191) Diahopane tndex (%} (412->191) Bicadinane Index (°I°) (412->191,412->369) DesA Oleanane Index (%} (330->191} TPP (358->217,414->259) (D26N24baS+D26N24baR}!{D26N24baS+D26N24baR+D26N27baS+D26N27baR) 24abbS+S26N24aaaR+S26N27aaaS+S26N27abbR+S26N27abbS+S26N27aaaR) S26N21!(S26N21+S26N24aaaS+S26N24abbR+S26N24abbS+S26N24aaaR+ S26N27aaaS+S26N27abbR+S26N27abbS+S26N27aaaR) (DS4aSS20R+DS4aSR20R+DS4aRR20R+DS4aRS20R}1{S303MaaaR+OS4aSS20R+ DS4aSR20R+OS4aRR20R+DS4aRS20R} S304MaaaR/(S29aaaR+S304MaaaR} 100'(OL18a+OL18b)!{H30ab+OL18a+O118b) 100'{GamA+Gam6}/{H30ab+GamA+Gam6} 100"DH30/(DH30+H30ab} 100"(6307+63071+B30R)/{H30ab+B30T+63071+630R} 100'DesAOU(DesAOL+DesEHQP} (2`PP1}!(2`PP1+D26N27baS+D26N27baR+S26N27aaaS+S26N27abbR+S26N27abbS+ S26N27aaaR} C Aromatic GC/MS • • i ~ BASELINE RESOLUTION INC. AROMATIC GCMS Company: CONOCOPHILLIPS Client ID; US140552 Country: UNITED STATES Project #: 08-628-A Basin: NORTH SLOPE Lab ID: CP289070 Lease: Sample Type: DST OIL 1.12 Block: Sampling Point: 2008 DST Field: RENDEZVOUS Formation: Alpine Well Name: RENDEZVOUS-2 Geologic Age: Late Jurassic Latitude: 70.15146 Top Depth: 8,350 ft. Lon nude: -151.6855 Bottom De the 8,390 ft M1081236.D • * ~.. {C20+C21}f£ TAS .. 0.48 M 1.0 {1.3%) TAS #1 20/20+27 0.77 M TAS #2 21121+28 0.87 M %26 TAS 19.5 D %27 TAS 28.2 D %28 TAS d2.0 D %29 TAS 10.a D C28lC26 20S TAS 2.51 C28IC27 20R TAS t.49 Dia/Regular C27 MAS 2.23 °I°27 MAS 36.t D %28 MAS 30.2 D °k29 MAS 33.8 D (C21+C22)J?` MAS 026 M 1 A (1.3%} TASt(AAAS+TAS) 0.62 M TAZ$(([A28+MA29) 0.61 M lA(0.8°l0) .. Dinosteroid index 0.22 A Cwt/C3+C4 Nester 0.48 A R ~ MPf-1 0.83 M Rc(a} if RO < 1.3 (Ro%) 0.87 M Rc{b) if Ra > 1.3 (Ro%) 1.80 M MPI-2 0.86 M DNR-1 7.19 M DNR-2 3.08 M TfYf21 0.95 M TDE-1 3.10 M TDE-2 0.2fl M MDR 4.22 M Rm (Ro%} 0.82 M MDR23 128 M MDt~i 0.51 M DBT/Phenanthrene 0.11 D 'Definition and utility of the ratios can be found on our website www.f3aselineDGSl.com ZA=Source Age; D=Depositional environment; M= Maturity 3Thermal equilibrium value of the biomarker ratio and in brackets the approximate VR value at which this value is reached • • Company: CONOCOPHILLIPS Client ID: US140552 Well Name: RENDEZVOUS-2 Project #: 0$-628-A Depth: - Lab ID: CP289070 Sampling Point: File Name: M1081236.D 230 OTF Ortho-terphenyf (internal standard) 92 16A6 C16 Aikyi Benzene 92 17A6 C17 Alkyl Benzene 92 18A6 C18 Atkyt Benzene 92 1THi092 Dimethy{ dihenzothiophene 1 92 2TH1092 Dimethyi dibenzothiapher~ 2 92 19AB C19 Alkyl Benzene 92 20AB C20 Alkyl Benzene 92 21 A6 C21 Alkyl Benzene 92 22A8 C22 Alkyl Benzene 92 23AB C23 Alkyl Benzene 92 AHYBz Fhytanyi Benzene 92 24A6 C24 Atkyi Benzene 92 25AB C25 AIkyI Benzene 92 26A6 C26 Alkyl Benzene 106 16ATmA C1SAtkyl7otuene(meta} 106 16AT0 C16 Alkyl Toluene {ortho) 106 17ATM C17 AHcyl Toluene (meta} 1 ~ 17AT0 C17 Alkyl Toluene (ortho) 106 18ATM C18 Adcyl Toh~ene (meta} 106 18AT0 C18 Alkyl Toluene {ortho) 106 1TIi10106 Dimethyl dibenzothiophene 1 106 2THI0106 Dimethyl dit>enzothiophene 2 106 i9ATM C19 Agryl Toluene (meta} 106 19AT0 C19 Alkyl Toluene (ortho) i ~ 20ATM C20 ANcyl Toluene (meta} 106 20AT0 C20 Alkyl Toluene {ortho} 106 21ATM C21 Alkyl Toit.~ne (meta} 106 21AT0 C21 Alkyl Toluene (ortho) 106 22ATM C22 Alkyl Toluene (meta} 106 22AT0 C22 Alkyl Toluene (ortho) 106 23ATM C23 Alkyl Toluene {meta} 106 23AT0 C23 Alkyl Toluene {ortho) 106 24ATM C24 Alkyl Toluene (meta} 106 24AT0 C24 Alkyl Toluene (ortho) 106 PHYI'L Phytarryl Toluene 106 25ATPll C25 Alkyl Toluene {meta) 106 25AT0 C25 Allcyt Toluene (ortho} 106 26ATM C26 Alkyl Toluene (meta) 106 26AT0 C26 Atkyi Toluene (ortho} 134 15Ai C15 Aryl Isoprenoids 134 16A1 C16 Ar}~ Isoprenoids 134 17AI C17 Aryl Isoprenoids 134 18A1 C18 Aryl lsoprenoids 134 19Ai C19 Aryi Isoprenoids 134 20AI C20 Aryt Isoprenoids 134 21AI C2t Aryl Isoprenoids 134 22A1 C22 Aryl Isoprenoids 134 fSOR lsorenieratane 74.994 57849 13263 300.0 300.0 66.725 18084 3906 93.8 .88.4 71.563 15893 34$8 82.4 78.9 75.768 13246 3206 68.7 .72.5 77.474 4535 694 23.5 15.7 78.231 4431 702 23.0 15.9 79.515 13074 2865 67.8 64.8 82.946 i 1500 2746 59.6 62.1. 86.165 11339 2841 58.8 64.3 89.173 9971 2232 5t.7 50.5 92.041 92$8 2419 48.2 54.7 94.011 3062 803 15.9 18.2 94.750 7507 1676 38.9 37.9 97.372 6642 1186 34.4 26.8 99.870 5963 1216 30.9 27.5 65.986 31423 7213 163.0 f 63.2 66.936 16803 3047 87.1 68.9 70.877 29901 7300 155.1 165.1 71.721 13347 3212 69.2 72.7 75.117 27472 7083 142.5 160.2 75.908 12191 2735 63.2 61.9 77.474 5129 i 053 26.6 23.8 78.266 2767 563 14.3 12.7 78.899 21791 5893 113.0 133.3 79.656 11429 2638 59.3 59.7 82.365 21097 5413 109.4 122.4 83.086 9080 2474 47.1 56.0 85.567 16592 4225 86.0 95.6 86.288 10187 2134 52.8 48.3 88.610 17473 4628 90.6 104.7 89.314 9fi30 2123 49.9 48.0 91.478 14198 3187 73.6 72,1 92-164 6699 1582 34.7 35.$ 94.205 13303 33911 69.0 76.7 94.891 6447 1423 33.4 32.2 95.894 16989 2573 88.1 58.2 96.826 9309 2327 48.3 52.6 97.495 4183 1102 21.7 24.9 99.324 9314 2296 48.3 51.9 100.011 3346 998 i7.4 22,5 • • • • Company: CONOCOPHILLIPS Client ID: US140552 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID; CP289070 Sampling Point: File Name: M1081236.D 142 2MN 2-Methytnaphthatene 37.996 489017 81195 2536.0 1836.6 142 1MN #-Methyinaphtha~ 39.227 320137 54228 1&60.2 12'16.6 149 MTTC578 5,7,8,-triMe-MTTChroman 156 2EN 2-Ethytnaphthaler~e 46.141 92566 13811 480.0 312.4 156 1EN 1-Ethytnaphthaiene 46.265 13393 4575 69.5 103.5 156 26DMN 2,6-Dimethythaphthater~e 47.056 358144 53849 1857.3 1218.0 156 27DMN 2,7-Dimethytnaphthalene 47.215 313030 56121 1623.3 1269.4 156 1317t3MIN 1,3 81,7-Dimefltylnaphtttatenes 48.235 682258 87881 3538.1 1987.8 156 16DMN 1,6-Dimethylnaphthalene 48.464 485932 83913 2520.0 1898.1 156 23DWtN 2,3-Diimethytnaptrtfia 43.625 60fI39 12110 311.4 273.3 156 14DMN 1,4-Dimethylnaphthalene 49.730 157792 24434 818.3 552.7 156 15DMN 1,5-Dimethytnaphthatene 49.836 93408 175 4$4.4 396.0 156 12DMN 1,2-Dimethylnaphthatene 50.768 73088 11943 379.0 269.2 161 MTTC8 $-Me-MTTChroman 168 2MBP 2-Methylbiphenyi 46.616 11024 1989 57.2 45.0 168 DPM Diphenyimethane ~ 48.868 10441 2046 53.9 46.3 t68 3MBP 3-Methylbiphenyl 53.302 244380 40260 1267.3 910.7 168 4MBP 4-Methyitr~rt~rtyt 53.953 101614 17237 527,0 383.9 168 DBF Dibenzofuran 55.360 40237 6234 208.7 141.0 174 BB EMN Ethyt-mefhyi-Naphtha~ne 55.114 174928 23868 907.2 539.3 170 EMN AB Ethyl-methyl-Naphthalene 56.328 69127 14458 358.5 236,6 170 _ 137TMN 1,3,7-Trimeihytnaphthalerte 56.767 310712 48383 1611.3 1t?94.4 170 136TMN 1,3,6-Trimethylnaphthalene 57.155 399580 66136 2472.2 1496.0 t74 1461357 (1,4,fi+1,3,5rTrimethykiaphtha~r~s 58.210 301571 44975 1553.9 1017.3 170 236TMN 2,3,6-Trimethytnaphthaiene 58.474 287845 50326 1492.7 1138.3 170 127TMN 1,2,?-Trirriethyinaphtha 59.213 57t}04 9566 295.6 216.4 170 1671267 (1,6,7+1,2,6}-Trimethyinaphthalenes 59.389 283935 43729 1472.5 989.1 170 124TMN 1,2,4-TrarrethylnaphthaJerte 60.304 26622 4691 138.1 106.1 170 125TMN 1,2,5-Trimethyinaphthalene 60.761 82418 13887 427.4 314.1 178 PHEN Phenanthrene 70.261 484693 96567 2513.6 2184.3 184 1357 1,3,5,7-Tetramethylnaphthalene 64.702 105539 17967 547.3 4~.4 184 1367 1,3,6,7-Tetramethytnaphfhatene 65.863 149466 28894 775.1 653.6 184 1247 (1,2,4,7+1,2,4,6+1,4,fi,7}-Tetramethylnaphthalenes 66.619 79247 14879 411.0 336.6 184 1257 1,2,5,7-Tetramethytna~ttraiene 66.795 41799 7996 216.8 180.9 184 2367 2,3,6,7-Tetramethyinaphthalene 67.165 27387 5719 142.0 129.4 184 1267 1,2,6,7-Tetrarnettryinaphthalene 67.605 35476 7031 184:4 159.4 184 1237 1,2,3,7-Tetramethylnaphthalene 67.781 13460 2998 69.8 67.8 184 1236 1,2,3.6-Tetramethyinapfrthaiene 68.044 21755 4249 112.8 96.1 184 1256 1,2,5,6-Tetramethyinaphthalene 68.766 44122 9339 228.8 211.2 184 DBT Dibenzothiophene 68,977 53566 10125 277,8 229.0 191 BH32 C32 Benuohopane 191 BH33 C33 Benzohmpane 191 BH34 C34 Benzohopane 191 BH35 C35 Benzohopane 192 3MP 3-Methyiphenanthrene 75.187 310698 65627 1611.3 1484.4 192 2MP 2-Methytphenanthrene 75.381 332976 67947 172fi.8 1536.9 192 9MP 9-Methyiphenanthrene 76.067 392328 81384 2034.6 1840.9 192 tMP 1-Methy~shenanthrene 76.243 287463 fi1478 1490.8 1390.6 • • Company: CONOCOPHILLIPS Client ID: US140552 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289070 Sampling Point: File Name: M1081236.D • 98 CAD Cadalene 98 12467PMiV 1,2,4,6,7-Pentatnethytnaphthaier~ 73.076 12490 2679 64.8 6f}.6 98 12357PMN 1,2,3,5,7-Pentamethylnaphthalene 73.393 &412 1738 43.6 39.3 98 4MD8T 4 Methyl 10it~nzothiophene 73.533 114478 23074 593.7 521.9 98 23MDBT 2 & 3 Methyl Dibenzothiophenes 74.308 68532 12612 355.4 285.3 98 1MDBT 1 Methyl Dibenzathiophene 75.117 27157 5547 140.8 125.5 O6 36DMP 3,6-Dimethylphenanthrene 79.427 68426 13455 354.9 304.3 t'~ 26DMP 2,6-Dimethyt{~nanttuer~ 79.673 145146 28831 752.7 652.1 ~ 27DMP 2,7-Dimethylphenanthrene 79.779 73200 16902 379.6 382.3 :06 39DMP (3,9+3,10+2,10+1,3}-Dimethylphenanthrenes 80.307 572439 102113 2968.6 2309.7 O6 29OMP (2,9+1,6j-Dimethylphenanthrenes 80.500 276602 49252 1434.4 1114.0 OS 17DMP 1,7-Dimethytphenanthrene 80.641 191625 42977 993,8 972.1 06 23DMP 2,3-Dimethytphenanthrene 80.905 83228 17024 431.6 385.1 06 19DMP 1,9-Dimethylphenanthrene 81.028 147202 25228 555.9 570.6 06 18DMP 1,8-Dimethylphenanthrene 81.450 47434 9660 246.0 218.5 O6 12DMP 1,2-Dimethylphenanthrene 81.960 24413 5161 126.6 116.7 O6 9_lODMP 9,10-Dimefhylphenanthrene 82.594 3168 757 16.4 17.1 12 DMDBT Dimethyktibenzathiophene 19 RET Retene 86.235 27197 4999 141.0 113.1 :26 TMDBT Trimethyldibenzothiophene 81.609 304937 14893 1581.4 336.9 :31 :31 231A20 2311321 C20 Triaromatic Steroid C21 Triaromatic 92287 94.786 24100 21923 4774 4764 125.0 113.7 108.0 107.8 31 231 C26 C26 20S Triaromatic 103.987 5029 1217 26.1 27.5 31 231 D26 C27 20S R G26 20R Triaroma5c 105.605 12450 2581 64.6 58.4 31 TADMDI C28 23,24-Cholestane Triaromatic 31 TADMD2 C28 23,24-Cho~star~ Triaromatic 31 231 F28 C28 20S Triaromatic 106.907 12598 2048 65.3 46.3 '31 231 F27 C27 20R Triaroma6c 107.540 7277 1187 37.7 268 :31 TADMD3 C28 23,24-Cholestane Triaromatic :31 C29TA1 C29 Triaromatic 107.945 2088 632 10.8 14.3 :31 C29TA2 G29 Triaramatic 108.121 2191 613 11.4 13.9 :31 TADMD4 C28 23,24-Chotestar~e Triarortratie :31 231 G28 C28 20R Triaromatic 109.159 10836 2148 562 48.6 :31 TADMD5 C28 23,24-Chotestane Triaromatic :31 C29TA3 C29 Triaromatic 110.496 2675 1027 13.9 232 :45 C3S G27 20S 3-Methyf Triaramatic Sterorci 106.766 978 266 5,1 6.0 :45 C4S C27 20S 4-Methyl Triaromatic Steroid 107.312 1759 428 9.1 9.7 :45 E2S C28 20S 2-Methyl Triaromatic Sterodi 107.839 1262 336 6.5 7.6 :45 E35C3R C28 20S 3-Methyl 8 C27 20R 3-Mettryt TAS 108.191 4785 893 24.8 20.2 :45 E4SG4R C28 20S 4-Methyl 8 C27 20R 4-Methryt TAS 108.788 5453 801 28.3 18.1 45 S2S C29 20S 2-Methyl Triaromatic Steroid 109.053 2632 413 13.6 9.3 '45 DA Triaromatic Dirwsteroid a 109.229 1272 431 6.6 9.7 :45 S3S C29 20S 3-Methyl Triaroma6c Steroid 109.423 5628 976 29.2 22.1 :45 DB Triaromatic Dinosteroid tt 109.827 2129 666 11.4 15.1 '45 S4SE2R C29 20S 4-Methyl 8 C28 20R 2-Methyl TAS 110.003 6886 885 35.7 20.0 :45 E3R C28 20R 3-Methyl Triaromatic Sterodi 114.126 2901 873 15A 19.7 :45 E4R C28 20R 4-Methyl Triaromatic Steroid 110.742 3036 632 15.7 14.3 '45 DC Trraromatic tknosteroid c 110.918 2461 682 12.8 i5.4 45 DD Triaromatic Dinosteroid d 111.041 2195 493 11.4 11.2 • • Company: CONOCOPHILLIPS Client ID: US140552 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289070 Sampling Point: File Name: M1081236.D 245 253 253 253 253 253 253 253 253 1182 182 182 18z 182 182 182 182 182 182 182 182 182 18z 182 182 212 212 212 212 212 212 212 S2R C29 20R 2-Methyl Triaromatic Steroid S3R C29 20R 3-Methyt Triaromat~ Steroid DE Triaromatic Dinostero'rd e S4R C29 20R 4-MeUryl Triaromatic Steroid DF Triaromatic Dinosteroid f S253A C21 Ring-G Monoarorttat~ Steroid S2536 C22 Monoaromatic steroid S253C C27 Reg 5¢(Ft},10¢{CI.13} 26.5 S253D C27 D+a 10¢(H),5¢(CH3) 20S 5253E C27 Dia10¢H,5¢CH3 20R+Reg5¢H,10¢Cti3 20R S253F C27 Reg 5a(H},10¢(CH3} 20S S253D C28 Dia t0aH,5aCH3 20s+RegS¢H,10¢CH3 268 S253H C27 Reg Sa(H),10¢(CH3) 20R S253t C28 Reg 5a(t-t),10¢(CH3} 20S S253D C28 t?;a 10aH,5aCH3 20R+RegS¢H,10¢CH3 20R S253K G29 Dia 14¢H,5¢CH3 20S+RegS¢H,14¢Cti3 265 S253L C29 Reg 5a{H},10¢(CH3) 24S S253M C2$ Reg 5a(H),10¢{CH3} 20R S253N C29 Dia 10¢H,5¢CH3 20R+RegS¢H,10¢CH3 20R 52530 C29 Reg 5a(H},10¢(CH3} 24R DMBP1 Oimethybiphenyl peak 1 DMBP2 Dimethytbiphenyl peak 2 DMBP3 Oimethytbiphenyl peak 3 DMBP4 Dimettiyttxpherryl peak 4 DMBPS Dimethylbiphenyl peak 5 DMBP6 Dimeihyibiphenyl peak 6 DMBP7 Dimethylbiphenyl peak 7 DMBP8 t0irrre#hytbiphenyt peak 8 DMBP9 Dimethytbiphenyl peak 9 OMBP10 Dimethylt>ipheny{ peals 10 DMBP11 Dimethytbiphenyf peak 11 DMBP12 Dimethytbphenyl peak 12 DMBP13 Dimethytbiphenyl peak 13 DMBPi4 Dimethytbiphenyt peak 14 DMBP15 Dimethytbiphenyi peak 15 DMBP16 Demethytb~henyt peak 16 ET4DBT 4-Ethytdibenzothiophene DM46DBT 4,6-Limethyldibenzothiophene DMDBT3 Dimethyldibenzothiophene peak 3 DMDBT4 D"anethyld~enzothldphene peak 4 OMDBT5 Dimethyldibenzothiophene peak 5 DNlE}BT6 DimetilYtdibenzothiapherie peak fi DMI4DBT 1,4-Dimethyldibenzothiophene DMDBT7 [)knethyldibenzothiophene peak 7 DMDBTB Dimethyldibenzothiophene peak 8 DMDBT9 Dimethyldibenzothiophene peak 9 111.464 1858 432 9.6 9.8 111.692 4978 775 25.8 17.5 111.780 2289 475 11.9 10.7 112.255 3401 652 17.6 14.7 112.343 2770 805 14.4 18.2 $4.529 7499 1489 38.9 33.7 86.992 7762 1161 40.3 26.3 96.985 2171 512 11.3 11.5 97.125 4848 1100 25.1 24.9 98.603 3335 1033 17.3 23.4 98.762 3967 1049 20.6 23.7 99.166 3879 1080 20.1 24.4 100.433 1647 593 8.5 13.4 104.626 2190 420 11.4 9.5 100.767 3704 950 19.2 21.5 100.925 7138 1393 37.0 31.5 102.210 2281 510 11.8 11.5 102.544 3573 753 18.5 17.0 102.614 4116 914 21.3 20.7 104.215 1403 494 7.3 11.2 60.022 18627 3358 96.6 76.0 60.831 53363 9980 276.7 225.7 61.043 158691 30656 823.0 693.4 61.201 9388 1759 48.7 39.8 61.658 126860 23160 657.9 523.9 62.081 28015 5578 145.3 126.2 62.256 2918 498 15.1 11.3 62.714 69033 11077 358.0 254.6 62.943 4431 672 23.0 15.2 63.171 53801 10570 279.0 239.1 63.470 70726 9818 366.8 222.1 63.734 15423 2669 84.0 60.4 63.910 40473 7789 209.9 1762 64.249 8847 1772 45.7 40.1 64.456 6223 1128 32.3 25.5 64.772 6665 1195 34.6 27.0 77.144 9447 2276 49.0 51.5 77.509 88298 188655 457.9 422.0 78.072 44040 9584 228.4 216.8 78.266 109994 18174 570.4 411.1 78.899 27106 4964 140.6 112.3 79.075 42261 7140 219.2 161.5 79.550 23727 3584 123.4 81.1 79.656 7415 1799 38.5 40.7 80.14$ 6087 1228 31.6 27.8 •i • • Company: CONOCOPHILLIPS Client ID: US140552 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289070 Sam lin Paint: File Name: M1081236.D ~J 245 P3R C30 20R 3-Methyl 7riaromatic Steroid 245 P4Ft C30 20R 4-NIQthyI Triaromatic Steroid 118'. pFIC_119 C15 Dihydrrrar-txucxurrene from iorr 119 204 DHC_204 Dihydro-ar-curcumene from molecular ion 204 142 A_142 Peak A Alkylnaphthalene 142 B_142 Peak B Alkylnaphthalene 142 C 142 Peak C Alkyinaphthalene 142 pi142 Peak p A~Cylrtaphthalene t47 MpNG~147 C16 [~'hydro-ar-GSr~cumene from ion 147 218 MDHC 218 Oihydro-ar-curcumene from molecular ion 218 197 ROR_197 C20H28 Ring opened Retene from ion 197 268 ROR_268 Ring opened Refet~ from molecular ion 268 252 BZFI_~1 peak #1 252 BZFL_2 Benzofluaranthene peak #2 252 BZEPY Berfzoje~yrene 252 BZAPY Benzo[aJpyrene 252 .PERM 252 F from fort 252 254 2_254 Ur~lcnown i~2 from ion 254 254 3 254 Unknown #3 from ion 254 254 4 254 Unknown #4 from iwt 254 254 5 254 Unknown #5 from ion 254 254 6_254 Unknown #6 from ion 254 254 7 254 Unknown #7 from ion 254 254 8_254 Unknown #8 from ion 254 254 9_254 Unknown #9 from ion 254 254 1U 254 U~tnowm X10 from ion 254 342. A~342 Unknown peak A from iort 342 342 B_342 Unknown peak B from ion 342 342: OHTAIIP C26 Octahydrotetramethytpicerte 342 C 342 Unknown peak C from ion 342 342 p~342 U peals D from i~t 342 342 .. E_342 Unknown peak E cram ion 342 342 E 342 t3rilcnaam peak F frorrt ron 342 • • • • • Company: CONOCOPHILLIPS Client ID: US140552 Well Name: RENDEZVOUS-2 Project #: 08-628-A Depth: - Lab ID: CP289070 Sam lin Point: File Name: M1081236.D i Mona- {MAS) and Triaromatic Steroids (TAS) (C20+C21)!F'TAS (231A20+231621}t(231A20+231821+231C26+231D26+231E28+231F27+231G28+C29TA3) TAS #1 20120+27 {231 A20)/{231 A20+231 F27} TAS #2 21121+28 (231621)/(231821+231 G28} %26 TAS 100`{231 C26}i{231 C26+231 F27+231 G28+C29TA3) °l027 TAS 100`(231 F27}1(231 C26+231 F27+231 G28+C29TA3} %28 TAS 100'{231 G28)/{231 C26+231 F27+231 G28+C29TA3} %29 TAS 100'{C29TA3)!(231 C26+231 F27+231 G28+C29TA3} C28lC26 20S TAS (231 E28)t(231 C26) C28tC27 20R TAS (231G28)/(231F27} DiatRegular C27 MAS (S253D)t(S253C) %27 MAS 100*(S253C+S253D+S253E+S253F+S253H)t(S253C+S253D+S253E+S253F+S253G+S253H+S2531+ S253J+S253K+S253C+S253M+S253N+S2530) %28 MAS 100'{S253G+S2531+S253J+S253M)/{S253C+S253D+S253E+S253F+S253G+S253H+S2531+S253J+ S253K+S253C+S253M+S253N+S2530} %29 MAS 100*(S253K+S253C+S253N+S2530)/{S253C+S253D+S253E+S253F+S253G+S253H+S2531+S253J+ S253K+S253C+S253M+S253N+S2530} {C2i+C22)/E MAS (S253H+S253G}/{S253H+S253G+S253C+S253D+S253E+S253F+S253G+S253H+S253i+S253J+S253K+ S253C+S253M+S253N+S2530} (231A20+231621+231C26+231D26+231E28+231F27+231G28+C29TA3)/((231A20+231821+231C26+ TASI(MAS+TAS) 231D26+231E28+231F27+231G28+C29TA3)+(S253H+S253G+S253C+S253D+S253E+S253F+S253G+ S253H+S253I+S253J+S253K+S253C+S253M+S253N+S2530}) TA28/(TA2$+MA29) {231E28+231G28}i{231E28+231G28+S253K+S253C+S253N+S2530) Triaromatic Methylsteroids Dinosteroid Index (DA+DB+DC+DD+DE+DF)/(C3S+C4S+E2S+E3SC3R+E4SC4R+S2S+DA+S3S+DB+S4SE2R+E3R+E4R+DC+ DD+S2R+S3R+DE+S4R+DF} C4lC3+C4 Mester (C4S+E4R+S4R}/(C3S+C4S+E3R+E4R+S3R+S4R) PhenaMhrenes, Naphthalenes, and Dibenzothiophenes MPI-1 (1.5*{3MP+2MP)}t(PHEN+9MP+1 MP} Rc(a} if Ro < 1.3 (Ro%} ({(.6}*{1.5'{2MP+3MP))/{PHEN+9MP+1MP))+.37} RC(b) if Ro > 1.3 (Ro%} (((-.6)'(1.5'(2MP+3MP}}t(PHEN+9MP+1MP)}+2.3} MPI-2 (3'(2MP))i{PHEN+9MP+1 MP} DNR-1 (26DMN+27DMN)1{15DMN) DNR-2 {26DMN+27DMN}t{14DMN+23DMN} TNR1 (236TMN}/(146135T) TDE-1 (125TMN}/(124TMN) TDE-2 (127TMN)/(167126T) MDR (4MDBT)!(1 MDBT} Rm (Ro%} {0.40+0.30*(4MDBT1IMDBT}-0.094*(4MDBTl1MDBT}*{4MDBTt1MDBT)+ QA11'{4MDBT/1 MDBT)*(4MDBT/1 MDB-f)`(4MDBTt1 MDBT)} MDR23 (23MOBT)t(DBT) MDR1 {1 MDBT)i{DBT} DBT/Ptrenanthrene {DBT}t(PHEN) • • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVE MAY 0 $ 200$ WELL COMPLETION OR RECOMPLETION REP~~Commissi~n 1a. Well Status: Oil ^ Gas Plugged / .Abandoned / Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. WeII Class: Of~Q Development ^ Exploratory Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., A April 4, 2008. 12. Permit to Drill Number: 201-007 & 308-073 / 308-104 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. a e Spudded: April 8, 2001 ~ 13. API Number: 50-103-20363-00 ` 4a. Location of Well (Governmental Section): Surface: 1707' FNL, 2632' FEL, Sec 6, T9N, R2E 7. Date TD Reached: April 19, 2001 ~ 14. Well Name and Number: ~bg Rendezvous #2 ' Top of Productive Horizon: 1707' FNL, 2632' FEL, Sec 6, T9N, R2E 8. KB (ft above MSL): /~ ~ ? Ground (ft MSL): ~ ~ i11 15. Field/Pool(s): (~ NPRA Exploration < Total Depth: 1707' FNL, 2632' FEL, Sec 6, T9N, R2E 9. Plug Back Depth (MD + ND): 8650' 4b. Location of Well (State Base Plane Coordinates): NAD 27 Surface: x- 285382 ~ y- 5913243'- Zone- 4 10. Total Depth (MD + ND): 8650' 16. Property Designation: ADL AA-081781 TPI: x- 285382 y- 5913243 Zone- 4 Total Depth: x- 285382 - 5913243 Zone- 4 11. SSSV Depth (MD + ND): na 17. Land Use Permit: 5126 18. Directional Survey: Yes ^ No Q (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 598' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): Previously submitted 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 65 H-40 surface 115' surface 115' 24" previously submitted 9.625" 40 L-80 surface 2673' surface 2673' 12.25" previously submitted 7" 26 L-80 surface 8602' surface 8602' 8.5" previously submitted 23. Open to production or injection? Yes No / ~ If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 8336' 7952' 8350'-8390' MD 8349'-8389' ND 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~~J ; ~ ~ ~ ~ ~ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ~;,;x,"" `~ ~ ` '~~~ L 8350'-8390' 256795# of 16/30 Badger Sand 26. PRODUCTION TEST Date First Production ~'E'~, February 28, 2008 ~4~C,~~ Method of Operation (Flowing, gas lift, etc.) nitrogen lift - refer to attachment for test results -Plugged and abandoned Date of Test Hours Tested Lb S•S•~g Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE - GASOIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL •~•~ OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No Sidewall Cores Acquired? Yes No / If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and. presence of oil, gas or water u (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~' "''~~~~ So ~~ 1ga,.b.~e1 ~~ /y,QA . ,•4 rr~~~a ~ ~ Previously submitted o /c.- +~:: ~~ ~ /~ ~K~ 4~RtE ~ iT~~~. ~;? ~"`~. ~`~ ~ L[)~~ CioT2+ ~ ~~~ rtiea-~•tn`~.trS cry ~ ~+f.~,G,,S (VJ p~ i Q ~ ~ :. v s. Form 10-407 Revised 2/2007 ., CONTINUED ON REVERSE SIDE t~ ~ 1 ~ A L ~.~~~~~~~~~-~ ~~~~~ ~i~a ~~~~~,~ ~~ ~ s~.so~ ~- - - ~ - ~~ ~ , AD S.eb,o; 28. GEOLOGIC MARKERS (List all formations and mark encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Top Surface surface needed, and submit detailed test information per 20 AAC 25.071. Permafrost -Base 598' 598' Jurassic 8266' 8265' ~~"~- ~L~ /~S~c/T~ ~ ~GL. ~ ~~ ~e-r'~ ~tc~istiT~ ooh.. ~ /tax S rec., ~,l ~ N/A ~, t~, zao% SS Formation at total depth: Jurassic 30. LIST OF ATTACHMENTS ~y Summary of Daily Operations, photos of abandonment 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom BrasSfield @ 265-6377 Printed Name /Clhi~o Alvord Title: Exploration & WNS Team Leader Si ~~Z('ZP9S nature '~~ Ph n D t g o a e e u,~, G t Z.O ~ 0 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 welt sundry report when the downhole welt design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 25. Producin Intervals 26. Perforation Record Formation To Bottom Perforated Interval Size No. Holes Perf Status A) Jurassic 8266' 8392.5' 8350' - 8390' 3-3/8"TCP Unknown Plu ed and Abandoned B) C D) 27. Acid, Fracture, Treatment, Cement Squeeze, etc. De th Interval Amount and T pe of Material 8350' - 8390' H draulic Fracture Stimulation: 1st attempt 71913 al 40# crosslinked borate el YF140ST w/ 534751bs 16/30 white Bad er sand; 2nd attem t 90053 al YF140ST w/ 2569751bs 16/30 white Bad er sand • • d 28. Production -Interval A Date First Produced -Feb 19, 2008 Production Method -Nitrogen Gas Lift Well Status -Plugged and Abandoned Production -Interval A Date Oil BBL Gas MCF Water BBL Oil Gravity Corr. API Gas Gravi Choke Size Tub. Press. Flw .PSI Cs .Press. Oil BBL/D Gas MCF/D Water BBL/D Avg. Gas/Oil Ratio Flow Period #1 19-Feb-2008 64 3.6 37 48/64 15 2711 128 0 7.2 0 20-Feb-2008 829 1040 580.7 37 0.911 56/64 193 894 829 1.04 584.3 1211 21-Feb-2008 1094 1450 171.4 37 0.86 50/64 173 725 1094 1450 171.4 1325 22-Feb-2008 295 360 18.7 36.7 0.853 40/64 194 741 1180 1440 74.8 1220 Flow Period #2 27-Feb-2008 238 200 0 37.8 0.847 14/64 1255 1276 519 436 0 840 28-Feb-2008 460 450 0 38.5 0.824 14/64 1272 1280 460 450 0 978 29-Feb-2008 491 490 0 37.9 0.834 14/64 1195 1286 491 490 0 998 1-Mar-2008 468 480 0 38.6 0.832 14/64 1206 1288 468 480 0 1026 2-Mar-2008 613 640 0 37.9 0.818 16/64 1125 1315 613 640 0 1044 r ~ U • v • Page 1 of 1 • Rendezvous #2 ~~~~~ ~HI~~IPS Alaska Inc. PEA Schematic-FiNA~ ~ Q}21}~€3 ~ '~ A sutasxsaep ~ €~t-f€t_~tt#5 €~Trat~t t=z~ ct»r}nN~t 0,~ arcs 880' oerrtertt coltann in the 3'/:" tbg !f. 3'l=" tbg x T' eye etxttktts on O~antM pBtB = 27.M" ~B'~ 16" 65f H,40 ~ +~-115' MD 31 J2' FMC Gtn Y T ubtlg ttangex, A-Y f2" 4~ Et3E8R0 Pin dovaa 3-1 f2" 9.3/ t--~ E LESRD SPSata3 Pups as Rec7rpti 3-t t2" 9.~Y L-80 E iJEBRD Tut»ng to Svtam Surfax rsg. 9•S+tt" s4.Ort L-806TCM (2673' MD 12873 TYDj oasng mrnentW x 20 td~1,s C1:±100 Warn i0 tkYS at tOS ppg Mur~USMtt ~,,pacs'r 332 tdsts AStit fits ~ t0.T ppg 4.64 ou- t 1sk T2 tits a1 12 Ppg lteCrete s:~ 2.38 ou Rfsk Fut rEduts*,, 6arinPaei t~+g. beta ttt~kl Cetttent from G L7t1 to the btl pert wF approx 8 bbls t away T" casing cdnertad as baoua 2.'0 t~#'As LYN300 Wash 50 txxs MucP t1511XL 80 12_D Ppg lQa~rele ~ 2 4 ci 61 Kdks 15 8 pP9 Gastiodc ~ 12 a DiSPi. v~328 !kits 9.6 PA4 txirrt Lo 9046 retorts ate' 290 Dws tw t~nf~ed Plug. toots tad Float c star ~ sst s• Pror3uci~+caskig. 7" 26.OaY l->~ BTCM (8802' t q ! 8fi07 7YD) 880' cement CMllrttt in itw lbg & atlni~l4 above the'DS tt~tt~ 3.1 t2" Carteo DS' a/2.8T5" proTue set at 892' MD. 880' cemerd cdtwrtn in the 3518" x 7" anmtlus 3.1 r2" 9.31 L-80 E lE~?D tiding to t ry3Ple 3-112" x 1"Corso 7tBtAd-2' marir4'et vJ afi~ar vaWe ~ 2T3D0 Ps. 6' l-lDhixulirg Pups tnsiated eb7ve arM titan. Marxket X2694' MD Tagged TQC in tubi~ 8t 7128 SLhI tm 3!24!88 31J2"x1"C+rmen'KBr~bt2`mayn#d+n~F~}C-StettharzfdtanmY. tt 4£Ottantlaig pups in~atecl d3nwe ax1 t~eiow~ Maw ~ 7854' MD 1 }t 6.1!Y` f 26a<t.-~7 Et~BtxD tubiry 3-1YC Cartco X' n~tte vA2.$13" pole. (stias~e n?j 1 It 3!12" 93l~ t.-&3 EL.1E HiD fttmxq 6dcer P~2 (t tJ)vaModg K-22 ttrg sed nppte. P~2 '~ 39K Ary Pufmrffadln~g_Awntbtlr Salter 7" x A"'S:*>$-3' Packt# pin ffl SW P~ st>~r Top to tsattom: 6° x 3.5" ?:O s>.~, 8' pup, 9 j<s 3.3' 93ppt L~ tuizn9. fi' pup, C~nco 3.5" x t" KBMUd-2 C3t.M *a~t"5 i atxi +.lxnmy ~ 825<', 6' Pup. 1 jt tubing.. B' pop, Camo3 3S' z 1" KBfMt-2 Gift va&1(S ietrh aaxJ umtnY C~ $3U2', 8' pVp, tt7 Pte, 3.5" x 2.75. 3(td nipPte (Plug irr9ated and teaatTl, 1D' tap. PakA sW. Tait (~ 8336' MD Perforetiorss 8350' - 6390' 5 spt 49 T of trey 8 TCP guns (8515' - 86fi5'1 iet in }fie T.~ 4J29 Al$ file://C:\Documents and Settings\sallsup\Local Settings\Temporary Internet Files\OLKB6\... 4/30/2008 • • RENDEVOUS #2 P&A SUMMARY 3/15/08 Rig up Tiger tank and Open top tank. Set choke house and hard lines pack with diesel, prep to kill well. 3/16/08 Slick line unit (Halliburton) pulled orifice valve at 7854', set PXX plug in X nipple at 7906'. Tubing Pressure 800#, Inner Annulus Pressure 1200#. Rig down slick line. 3/17/08 Rig up Hot Oil, Prep to circulate down tubing and up annulus. Pumped approximately 5- 10bbls of 9.6# brine down tubing. Switched flowback from Tiger tank to open top tank. Tank caught fire. Shut in well. Let tank burn out. 3/18/08 TP 700#, IAP 1100#. Clean up after tank fire. 3/19/08 TP 700#, IAP 1100#. Clean up pad area. Remove open top tank and Tiger tank. Spot new tank and rebuild containment. Set choke house and hard line. 3/20/08 Clean pad area and sweep soot covered snow off tundra. 3/21/08 TP700#, IAP1100#. Prep to kill well. Set OV valve at 7854'. Pull PXX plug and prong at 7906'. Rig up Hot Oil, pump 85 bbls 9.6 # brine down tubing, break down pressure 800# pump at 3-4 bpm at 800#. Pump 220 bbls 9.6# brine down annulus. Pump brine at 1-1/2 to 2 BPM at 1800-2000#. Inner Annulus and tubing pressure down to 0#. Pull OSV at 7854'. 3/22/08 TP 400#, IAP 400#. Well not dead prepare to kill well again order brine. 3/23/08 TP 400#, IAP 400#. DS cementers pumped 90 bbls 9.6# brine down tubing and 230 bbls down annulus at 700-800 psi at 4-5 BPM. Shut in well and check pressures. No pressure build up. TP at 0# and IAP at 0#.. Cement lower perfs at 8350'-8390'. Pump 5 bbl water spacer 31 bbls of cement and 5bbl water spacer displace with 9.6# brine. Squeeze perfs with 8 bbls of Class G at 15.6 to 15.8 #/gal. Pump at'/< to'/z BPM with no pressure build up. Open IA valve and pump 13 bbls Class G to annulus. Left a total of 10 bbls cement in tubing. Estimated top of plug at 7130' in tubing. Shut well in. 3/24/08 TP 300# IAP 300#. Bled down tubing and annulus to 0#. Rig up HES slick line, tag top of cement plug at 7128'. Witnessed by Tim Lawlor with BLM. Pressure test casing to 1500# witnessed by BLM. Rig up DS to cement OA. Pump down 9 5/8 by 7 inch annulus. Immediately pressured up to 2000#. Double check all valves and transducers. Pressured annulus up to 2000# and pumped 1/4 of a bbl of water. Bled off pressure and tried to break down annulus again, still at 2000# and no fluid movement. HES pulled dummy valve from mandrel at 2494'. Will circulate hot water down tubing in case annulus is frozen. 3/25/08 Line up equipment to circulate hot water down well.. 3/26/08 Rigged up @ 1130 hr, circulated w/Hot Oil Services, 270 bbl 9.6 brine @ 190 deg, 2 bpm down tbg and out 3-1/2" annulus, temp out 100+ deg, shut down, attempted to pump down 9-5/8 " x 7" annulus w/diesel, press to 2000+ psi, no movement, no pressure bleed off, rigged up using brine returns pumped 200 additional bbl 9.6 brine @ 190 deg in and 140+ deg out, 2 bpm, shut down, rigged up to 9-5/8 x 7" annulus, press to 2500 psi w/diesel, no movement or pressure bleed off. Rigged down, secured well @ 1930 hrs. Witnessed by Tim Lawlor BLM. 3/29/08 Perf w/Schl 2-1/2" HSD Powerflow 6spf f/875-880' thru 3-1/2" tbg and 7" casing. Positive indication of communication between tbg and 9-5/8 x 7" csg annulus. Witnessed by Lawlor BLM. 4/1/08 R/U Dowell/Schl cementers, press test lines, open outer annulus (9-5/8x7) mix and pump36 bbl ARCTICSET 1 @ 15.6 ppg, 1-1.6 bpm down tbg to perfs @ 880' and up outer annulus, shut outer annulus, open inner annulus, mix and pump 28.4 bbl ARCTICSET 1 @ 15.6 L.J ppg, 2.2 bpm down tbg and up inner annulus (3-1/2 x 7") cement to surface, CIP @ 0952 hrs. R/D and secure well. Witnessed by Lawlor BLM. 4/2/08 Nipple down upper tree, remove scaffolding; excavate cellar and wellhead to ~5-1/2' below tundra ground level. 4/3/08 Attempt to cut tree, residual diesel in tree giving false LEL reading, drilled additional holes thru casing and 3-1/2 tubing to aerate the tubing. 4/4/08 Cutoff conductor, casings, 3-1/2 tubing 3' below tundra ground level, prepare casing for witness inspection and P&A marker plate. Witnessed and ok'd by Lou Grimaldi AOGCC. Welded 16" P&A marker plate w/1/4" weep hole in top. Backfilled hole w/excavated soil and cuttings f/drilling conductor.. 4/6/08 Site clearance Ok'd by Robert Lamppe, Nuiqsut subsistence representative and Mary Mae Aschoff COP Exp Environmental. Entrance/ egress to drill site is blocked off. Ray Springer/Dave Chapman/Bob Mead COP Drlg Supv. ~t } '~ ~ = - t ~- P * - -r r~' ;,ter ~ ~ ~c ~°""~ -e:.p ,~,, r~ ~ y; ~} ~ ~ ~ r ~, ye~ a ~rR -. +F ~ ., _ A .., ~ ~ ~: £ ~~ ~'.. - ,~~':~ _ 'sue', ~ ~'~~' ~ ,}~ .. p =~_ ~ ~~ ~a < ~ ~ • ~ ~, . ~.. "a `` V~ r ~' .. .~ ~` ~>, ~ _~ • ;; ,ALA.SIfA OIL Al~TD GAS COI~TSERQATIOI~T CO1rII~II55IOrIT Chip Alvord Exploration & WNS Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, Alaska 99510 • SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Exploration Well, Rendezvous #2 Sundry Number: 308-104 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date. of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair h DATED this ? day of April, 2008 Encl. STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMON ,,rlam APPLICATION FOR SUNDRY APPROVALS 6~3j.7 20 AAC 25.280 ~~ 'r 1. Type of Request: Abandon ^Q ~ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other ^ e ding ^ Repair well ^ Plug Perforations^ Stimulate ^ Time Extension ^ Change ap o d pjra~ [~ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Conoco Phillips Alaska, Inc Development ^ Exploratory ^ 201-007 3. Address: Stratigraphic ^ Service ^ 6. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 50-103-20363-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No Q Rendezvous #2 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL AA-081781 / ALK 5126 97.5 AMSL ~ NPRA Exploration , 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8650 8650 8516 8516 Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 108' 108' NA NA Surface 2645' 9.625" 2673' 2673' 5750 3090 Intermediate Production 8574' 7" 8602' 8602' 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8250'-8290' 8250'-8390' 3-1 /2" L-80 8336' Packers and SSSV Type: Packers and SSSV MD (ft): SAB-3 SAB-3 @ 7952' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory^ ~ Development ^ Service ^ 15. Estimated Date for 3/29/2008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged Q ~ Abandoned ^~ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Tom Maunder 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dave Reimer phone: 263-4347 Printed Name Chip Alvord Title Exploration Team Leader Signature Phone 265-6120 Date 3/27/2008 L ~-- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~U~ ~ / V~ Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~ ~~~~ ~-~~~ Other: ~~ , ,~~ ~`R~C.~f.,, ~3 i 5`5 Op ~~5, C ~~~C..~'1~.~`~.~ C~ Subsequent Form Required: ~~ 4S ~C ~ ~(`e~ ~ ; ~~' °-~ l~ APPROVED BY ~"J ~ MMISSION D t x A THE e: U pproved by: COMMISSIONER a CO s / ~ .G~ Form 10-403 Revised 06/2006. Submit in uplic~ate B • Rendezvous #2 Final P&A • CONFIDENTIAL Revised 3/27/08 Well Status: Rendezvous #2 was drilled/completed during the 2001 winter NPRA exploration drilling season. The well is currently SI after a five day +/- flow test in February/March of this year and will be P&A'd before the ice road system is secured for the season. Proceeded with P&A are described in procedure submitted March 6, 2008. Per procedures, a cement plug was set in the 3-1/2" tubing. The tubing plug was set at 7130' MD, tagged and pressure tested to 1500 psi for 5 minutes. The tag and pressure test was witnessed by the BLM. On March 23, an attempt was made to pump into the OA (9-5/8" x 7") to continue P&A procedures. After pumping about 1/3 of a barrel, the OA pressured up to 2000 psi. Suspect OA frozen. Slickline was used to pull the valve out of the upper GLM at 2494' in preparation to circulate hot brine down the 3-1/2" tubing up the IA (3-1/2" x 7" annulus) to attempt and thaw the OA, if frozen. Began circulating hot brine using Hot Oil services on March 26, 2008. After circulating 470 bbls of 190° brine, there was not movement or pressure bleed off on the 7" x 9-5/8" annulus. Rigged down Hot Oil, secured well, and propose the following procedure to continue P&A operations. 1. Notify BLM/AOGCC 48 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. RIH with tubing plug and set in the `DS' nipple at 892' MD. POOH. Make up a high shot density perforating system, RIH, and perforate 3-1/2" tubing x 7" casing just above the `DS' nipple at 892' MD. POOH. 3. Attempt to establish circulation down the 9-5/8" x 7" annulus and up the tubing. RD eline. If able to establish circulation, RU D/S and pump sufficient AS1 cement down the tubing and up the 9-5/8" x 7" annulus to surface, close the outer annulus, open the inner 3-1/2 x 7" annulus and continue pumping cement filling the inner annulus. Shut in at surface. Clear lines, rig down cementing unit and clean up. NOTE: Notify BLM/AOGCC Inspectors before setting surface plug(s). 4. Cut off wellhead and all casing strings at 3 feet below original ground level. Verify that cement is back to surface in all strings. Add cement as required. Send casing head with stub to Materials for repair / re-dressing , ~C~ ~~--~- ~SC ; , 5. Weld %4" thick cover plate (16" in diameter) over all casing strings with the ~`~,~-~'~ ~'~~ following information bead welded into the top (weep hole required). ConocoPhillips ~~ ~~-~~}~-~~ ~ rr~C ``~'~~~~ Rendezvous #2 PTD # 201-007 s~~~~~ ~ ~ c~~c API # 50-103-20363-00 6. Remove cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level with gravel/fill. Clear and scrape the ice pad location as needed and demobe all materials and equipment. Close out with the appropriate agencies. DJR 3/27/08 FILE: Rendezvous #2 David Reimer Staff Drilling Engineer DJR 3/27/08 • • Page 1 of 1 Rendezvous #2 ~~ PHILLIPS Alaska Inc. P&A Schematic ~ ~ s ~6~$ A Subsidiary of PHILLIPS PETROLEUM COMPANY 0~ ~ 692' cemwtt edam in the 3%^ tbg b 3%^ x T based on am alas Oayon 141 W(B ~ 27.x• 31I2"FtNC Gm V Tubag Hangar, 4-1 f1" LAO EUEBRD pin down (pKB -l.lv 3-t 17 9.3t L-80 E UEBRD Spaosat Pups as R eql 'red 16' 65i H-40 ~ .1-11SMD 3112" 9.3f LAO E UE8RD Tubag to Sur~ce Srrixe a9. 9-54f• 40.0E LAO BTCM ' - 892' cerltent cdurm h the tbg & annubus above the ~S' nipple (7673 MD 12673 TYD) 31I1' Cmo 95 nipple vJ 2.875' prole set et 897 MD. Surface casing oemerted es folows 1066' cement COket111 in the 9-~8' x 7' arntuWs 20 bbls CW t 00 Wash 40 btls of 10.5 ppg MudPUSFDa_ 31 R•9.3I L-80EUEBRD tudrg to kuxli~q nq~ple Spa°ef 332 bbls ASIII Ute ~ 10 7 ppg 3-111" x 1"Cwreo 7(BMA2' mentlrel W shear vaha (~ 2900 psi, 8' LAO hend'eg ' . , 4.W cu. t/sk MD pupsinslaled above and below. Mend+d X2494 72 WtFS of 12 ppg LteCrete Q 2.38 cu tlsk Ful returns, bumped plug, toils hek! 493' cement cd umn In the tbg & annulus above the G LM 3-1 f1' x 1' Canto XBNM2' mandrel vaBK-5latdt end dummy, a L-~ landag pupsimteted above end below. Mandrel X7854' MD 1 jt 41(1" 12.6f LAO EUE BRD tubng Ctutrent Tfom G Lbt to fhe bottom 3112" Cameo X' nipple W 2.813" prole. (que3imabl a D?) petf w1 apploK 8 bbhi squeezed 1 jt 3117' 9311 L-~ EUE 62D tubng awl BakerPBR (t0)vaModd K-22 tbg sad dppb. PBR shearQ39K 17 Baker 7• x 4• SAB-3' Packer pin fM 500 psi shear Top to bottom: 4" x 3.5' XO sub, 6' pup, 9 Jts 7" casing cemented as btovesc 3.S 93ppf LAO tubing, 6' pup, Cameo 3.5" x 20 bids CW 100 Wash 1"KBMM-2 OLM vaHKS latdi and dsnmy Q 50 bbls MurP USHXL 8252', 6' pup, t jt tubing, B' pup, Cameo 3.5' x 60 bbls 12.0 pPg LteCrete ~ 2.4 d.t lsk 1" KBMM-2 OLM vwt3l(S latch end denmy Q 41 bds 15.8 ppg Oasbkxic ~ t .2 cutJsk 8302', 6' pup, 10' pup, 3.5' x 2.75' XN Npple Displ, vd326 bids 9.6 ppg brace. Lost SO - (Plug instated and tested), 10' pip, porbd 90% retrrrts afar 290 bbls pumped. sub. Till (~ 8336' MD Bumped plug, toils hdd PeMOra6ons 8350' -8390' ~ 5 spf 49.7' of trail 8 dropped TCP gum (8515 - 8465) let in Irokf Float Cofer ~ 8516' Produdion caseg. 7" 26.Oi LAD BTCM (8607 MD !8607 TYD) TJB 3720t>0 file://C:\Documents and Settings\reimedj\Desktop\Rondy 2 P&A Schematic TJB 3 20 O8.vsd 3/27/2008 b~ ConocoPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360 • ~~~~~~~~ MAR 2 8 2~Q8 March 27, 2008 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 west 7t" Avenue Anchorage, Alaska 99501 Re: Application for Sundry approval to P&A: Surface Location: Dear Commissioner: AiBSka Oil & Gas Cons. Commission Anchorage Rendezvous #2 1707' FNL, 2632' FEL, Sec. 6, T9N, R2E, UM X=1,425,418 & Y=5,912,987 ASP4 NAD83 ConocoPhillips Alaska, Inc. hereby submits a Sundry to permanently plug and abandon Rendezvous #2, an onshore exploratory well in the National Petroleum Reserve-Alaska. The well was originally drilled and completed in April of 2001 by Doyon rig 141. This Sundry is being submitted as a result of a revision in the P&A procedure that was submitted March 6, 2008. The attached Sundry form 10-403 and back-up information describes the revised P&A procedure for the existing wellbore. The anticipated start date for this revised P&A procedure is March 30, 2008 If you have any questions or require any further information, please contact me at 263-4347 or Chip Alvord at 265-6120. Sincerely, David Relmer Staff Drilling Engineer cc: CONFIDENTIAL -Rendezvous #2 Chip Alvord ATO-1570 Mike Morgan ATO-1392 GRIrINgL Rendezvous P&A Sundry revision • Maunder, Thomas E (DOA) From: Reimer, David J [David.J.Reimer@conocophillips.com] Sent: Friday, March 28, 2008 4:11 PM To: Maunder, Thomas E (DOA) Subject: RE: Rendezvous P&A Sundry revision Tom: Many thanks. I'll contact you if we run into problems and have to make a change in procedures. Have a good weekend! Thanks Dave Page 1 of 1 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 28, 2008 4:08 PM To: Reimer, David J Cc: Alvord, Chip; Chambers, Mark A; Brassfield, Tam J Subject: RE: Rendezvous PBcA Sundry revision Dave, This note follows our conversation regarding the revision to the Rondy procedure. A change is needed due to the inability to pump into the 9-5/8" x 7" annulus. You have attempted to heat the annulus and are still not able to pump in. Perforating the tubing and casing as you plan should establish the needed circulation path to effect cementing. Proceeding as planned is appropriate. Call or message with any questions. Tom Maunder, PE AOGCC From: Reimer, David J [mailto:David.J.Reimer@conocophillips.com] Sent: Thursday, March 27, 2008 6:00 PM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip; Chambers, Mark A; Brassfield, Tom J Subject: Rendezvous P&A Sundry revision Tom: Attached please find a Sundry notice and a revised P&A procedure for the Rendezvous #2 well. «Rendezvous #2 P&A AOGCC cover 3 27 08.rtf» «Rende 2 Sundry P&A 10-403 3-27-08 .xls» «Revised Rondy #2 BlM AOGCC PA Proc by DJR 3 27 08 (3).rtF» «Rondy 2 P&A Schematic TJB 3 20 08.vsd» Please review and let me know if any additional information is needed. Thanks Dave 3/31/2008 Rendezvous Tank fire Maunder, Thomas E (DOA) From: Reimer, David J [David.J.Reimer@conocophillips.com] Sent: Tuesday, March 25, 2008 1:13 PM To: Maunder, Thomas E (DOA) Subject: RE: Rendezvous Tank fire Attachments: BLM Rendezvous Tank Fire update 3-24-08.doc Tom: Page 1 of 1 Here you go. Again, it is very brief, but it does provide you with the highlights of what has been done to date. Thanks Dave From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, March 25, 2008 1:09 PM To: Reimer, David J Subject: RE: Rendezvous Tank fire Yes Dave, we would appreciate that. Tom Maunder, PE AOGCC From: Reimer, David J [mailto:David.J.Reimer@conocophillips.comJ Sent: Tuesday, March 25, 2008 12:57 PM To: Maunder, Thomas E (DOA) Subject: Rendezvous Tank fire Tom: I prepared and sent a brief update to the BLM on the tank fire that occurred on Rendezvous #2 last week. Would you like me to send you the same update? Thanks Dave 3/31/2008 • • ConocoPhillips Box 100360 Alaska 99510-0360 March 24, 2008 Tom Zefenka United States Department of the Interior Bureau of Land Management-Anchorage Field Office 6881 Elmore Road Anchorage, AK 99507 Re: Rendezvous #2 Tank Fire Upate Dear Mr. Zelenka: On March 17, 2008, ConocoPhillips Alaska, Inc. experienced a fire in an open top tank on the Rendezvous #2 location. The following is an update of actions taken since this incident occurred. • A Tap Root incident investigation was conducted. Final report is being prepared. • Conducted and completed on-pad and off-pad clean-up operations. • Waste material bagged. Samples were collected and sent in for lab analysis. • Alt waste material to be properly disposed of pending results of lab analysis. If you have any questions or require further information, please contact Dave Reimer at (907) 263-4347 or Chip Alvord at (907) 265-6120 Sincerely, David Reimer Staff Drilling Engineer cc: CONFIDENTIAL -Rendezvous #2 Chip Alvord ATO-1570 Rendezvous #2 Final P&A CONFIDENTIAL Revised 3/27!08 Well Status: Rendezvous #2 was drilledlcompleted during the 2001 winter NPRA exploration drilling season. The well is currently SI after a five day +/- flow test in February/March of this year and will be P&A'd before the ice road system is secured for the season. Proceeded with P&A are described in procedure submitted March 6, 2008. Per procedures, a cement plug was set in the 3-1/2" tubing. The tubing plug was set at 7130' MD, tagged and pressure tested to 1500 psi for 5 minutes. The tag and pressure test was witnessed by the BLM. On March 23, an attempt was made to pump into the OA (9-518" x 7") to continue P&A procedures. After pumping about 1/3 of a barrel, the OA pressured up to 2000 psi. Suspect OA frozen. Slickline was used to pull the valve out of the upper GLM at 2494' in preparation to circulate hot brine down the 3-1/2" tubing up the IA (3-1/2" x 7" annulus) to attempt and thaw the OA, if frozen. Began circulating hot brine using Hot Oil services on March 26, 2008. After circulating 470 bbls of 190° brine, there was not movement or pressure bleed off on the 7" x 9-5/8" annulus. Rigged down Hot Oil, secured well, and propose the following procedure to continue P8~A operations. 1. Notify BLM/AOGCC 48 hours in advance of all pressure testing and well suspension operations. Hold pre job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. RIH with tubing plug and set in the `DS' nipple at 892' MD. POOH. Make up a high shot density pertorating system, RIH, and perforate 3-1/2" tubing x 7" casing just above the `DS' nipple at 892' MD. POOH. 3. Attempt to establish circulation down the 9-5/8° x 7" annulus and up the tubing. RD eline. If able to establish circulation, RU D/S and pump sufficient AS1 cement down the tubing and up the 9-5/8" x 7" annulus to surface, close the outer annulus, open the inner 3-1/2 x 7" annulus and continue pumping cement filling the inner annulus. Shut in at surface. Clear lines, rig down cementing unit and clean up. NOTE: Notify BLM/AOGCC Inspectors before setting surt'ace plug(s). 4. Cut off wellhead and all casing strings at 3 feet below original ground level. Verify that cement is back to surface in all strings. Add cement as required. Send casing head with stub to Materials for repair / re-dressing 5. Weld %." thick cover plate (16" in diameter) over all casing strings with the following information bead welded into the top (weep hole required). ConocoPhillips Rendezvous #2 PTD # 201-007 API # 50-103-20363-00 6. Remove cellar. Back fill cellar with gravellfill as needed. Back flll remaining hole to ground level with grave~ll. Clear and scrape the ice pad location as needed and demobe all materials and equipment. Close out with the appropriate agencies. DJR 3/27/08 FILE: Rendezvous #2 David Reimer Staff Drilling Engineer DJR 3/27/08 '~ , Rendezvous #2 ""i"'~ PHILLIPS Alaska InG. P&A Schematic ~ ~ ~ 316/08 A Subsidiary of PHILLIPS PETAGLEUM GUMFWNY Dep9w ere BD2' c9meM columm in the 3:~" tbg b 3%" tbD x T' based on annuals Doyont4l RND - 27.96' 3-1?FMC Gen tl Tubirq Heigx, l-1?LAO EUEBRD pin dn~n (PJ(B -Lip 3-1?8.3i l-BDEUEENtD Spaoeout PyisasRequtrad 1 B' BSt Hd0 ~ +I-11 S MD 3-1?9.3t 1-80 E UEBRD hbkg to S~ateoe Surface m11. 8.518' 40AI LAO BTCM ~2' 09111Bnt COh1n91 in the tbt)i b 9nneti!ffi Ibove the'DS' ttippb (7873' MD ! 2873 TW) 3.1? Caeca OS' dpPle W 2.873' protb ad d 897 MD. Surface cedrg oemeried ea tdk>Hc t00D' CefnBRt coh9ml bl the 9-518' x T 9nIM1111ffi 20 bbISCW 100 Weab 40 btla of 10S ppp MudPIiSFIXL 3-1?9.3/ L-BDEUEBRD tWirgto lendrg nfppb 3pecor 3-1? x t' Carrco %BMN2' rcAndt'al W shear vaM @ 290D paf, 8' LAO heridkg 332 bda ASIII Llle Q 10.7 ppg, pupairWaled ebova end bdox Merxtd Q2494'MD 4.44 cu, tJek 72 hWa o} 12 ppg LRaCrde •$ 2.38 cu flak Ful retuma, hooped plug, bds held 4a9' CelllBitt COl Won In the tb() b dlBldnB above the G LM 3-1? x t' cerrco %BMMY merMrel weKSlettli and dimny, B L-80 tiendtg pupslndMed ebore end below. Mendrd Q7954' MD 1 Jt 41? 12.6/ LAD ELiEBRD tubfng C9meM Tfeln G LM to the bott9ttl 3-1? Cameo 7t'rYppie W 2.613' proffie. (grrodfmable DT) pelt WlapproK 8 bblffi ffiqu9e2ed 1 p 3-1? 93t+L-80 El1E6RD IWtg 9YY0y Bdcer PBR (10)wModel K 22lb8 aed rippb. PBR shear®39K i9 Baker T x 4' SAB-.3' Pedca ph fM 500 pei diver Top to hc9arn: 4" x 3.5' XO sub, 6' pup, 9 /a 7' osskg oemerted ea Iolows 3.3' 93ppf LAO tubing, B' pup, Cenxxt 3.5' x Bf< I h d " 20 bola CW 100 Wash 50 bhis MucP USHXL KBMM-2 OLM w dc end anmy ~ 1 S 8257, 8' PuP. 1 Jt tubig, e' Pup. Cemco 3S" x BO hbls 12.0 pDg lJleCrde Q 2.4 dt>rtt 1 • KBMM-2 OI.M w9KA letdr oral dAnmY Q 41 bMs 15.8 ppg Oesbladc ®1.2 cu.t.r33ir 8307, B pup, 10' pup, 3.5" x 2.75" XN Nppb Dlspl. W326 hbls 8.8 ppg hrkie. Lost 50 - plug ItttleAad and te4ad), 10' pig, Ported 90% rettaro afar 290 hhls pumped. Sub. Tail ~ 8338' MO d.mped Pwg, tods held Perfwdlans 6350' • 8390' ~ 5 apt 48.7' of bed 8 dNpped TCP gone (BS15' - 648591aR )n hob Flod CdlarQ 8516' Prodidlarl Cesing. T 28.OA LAO DTCM (8802' MD J8607 TW ) TJB 3J20A8 Page I of 1 file://C:\Docurnents and Settings\reimedj\Desktop\Rondy 2 P&A Schematic TJB 3 20 08.vsd 3/2712008 FW: Sundry Notice for CPAI Rendezvous #2 and Spark DD -Weekly Progress Report Page 1 of 2 Maunder, Thomas E (DOA) From: Morgan, Mike R [Mike.R.Morgan@conocophillips.com] Sent: Sunday, March 23, 2008 8:53 AM To: Maunder, Thomas E (DOA) Subject: FW: Sundry Notice for CPAI Rendezvo~ #2 and Spark DD -Weekly Progress Report ~-~~ -®~~ From: NSK Expl Env Sent: Saturday, March 22, 2008 5:46 PM To: 'Mike_Worley@ak.blm.gov'; 'donna_wixon@ak.blm.gov'; 'Shane_Walker@blm.gov' Cc: &assfield, Tom J; Morgan, Mike R; Kralick, Jack T; Chambers, Mark A; Alvord, Chip; Reimer, David J Subject: Sundry Notice for CPAI Rendezvous #2 and Spark DD -Weekly Progress Report Mike, Donna, Shane - Under the BLM Sundry Notice for CPAI's Rendezvous #2 well, CPAI is filing a progress report as required under Surface Operations Requirements. We will also provide the BLM with weekly reports for continuing CPAI drilling and testing activities in the NPRA. Rendezvous #2 Testing • On 3117/08, a fire occurred in an open-top tank. The tank was staged on the pad for well prep activities prior to the P&A and the tank had hydrocarbon fluids inside at the time of the fire. The Alpine fire department responded and it was decided by the response team to let the fire burn itself out. • A < 1-gallon, non-reportable spill occurred on the ice pad immediately prior to the fire. The spit! material was a very light misting of crude. • The fire burned the insulation on the outside of the tank and the resultant ash covered the ice pad downwind of the tank as well as approximately 150 feet off the pad on the snow surface. . Analytical samples of the off-pad ash were collected on 3/20/08 and run for cyanide, semi-volatiles, and total metals. Preliminary results are expected by Wednesday, 3/26/08 and will be reported to the ADEC and the BLM. . Cleanup of the on-pad and off-pad ash was completed on 3/20/08. • P8A operations have been resumed but not completed. • A CPAI internal investigation is being conducted as to the root cause of the incident. Spark DD Drilling . Doyon 141 rig is currently drilling at location. An ice pad extension was built on the east edge of the pad to accommodate the testing equipment for later test activities. • No spills or other environmental incidents to report at this location. Chris Brown Chris Brown/Mary Mae Aschoff Exploration Environmental Coordinators Office: (907) 659-7217 Fax: (907) 659-7706 Truck Phone: (907) 659-0780 3/24/2008 Page 1 of 2 Maunder, Thomas E (DOA) From: Roby, David S (DOA) Sent: Tuesday, March 18, 2008 9:54 AM To: Maunder, Thomas E (DOA) Cc: Birnbaum, Alan J (LAW) Subject: RE: CPAI Confidential Request The record is clear, to me anyways, that this well is not subject to extended confidentiality and therefore the data related to it must be made public. Dave Roby Phone: 907-793-1232 email: dave.roby@alaska_gov From: Maunder, Thomas E (DOA) Sent: Tuesday, March 18, 2008 9:12 AM To: Roby, David S (DOA) Cc: Birnbaum, Alan J (LAW) Subject: RE: CPAI Confidential Request Yes, there is quite a bit of correspondence in the well file. From:. Roby, David S (DOA) Sent: Tuesday, March 18, 2008 9:11 AM To: Maunder, Thomas E (DOA) Subject: RE: CPAI Confidential Request Do we have a letter from the DNR revoking the extended confidentiality? Dave Roby Phone: 907-793-1232 email: dave.roby@alaska.gov From: Maunder, Thomas E (DOA) Sent: Monday, March 17, 2008 4:25 PM To: Birnbaum, Alan J (LAW) Cc: Seamount, Dan T (DOA); Foerster, Catherine P (DOA); Davies, Stephen F (DOA); Roby, David S (DOA) Subject: CPAI Confidential Request Alan, ConocoPhillips has conducted formation tests on well Rendezvous #2 (201-007} a well drilled and suspended in NPRA in 2001. They have been submitting weekly reports as required by the sundry notice filed to re-enter and test the well. In the transmittal letters, they include: "We request that this exploratory well information be held confidential as required under AS 31.05.035 (c) and 20 AAC 25.537 (d), and AS 45.50.940(3) and State v. Arctic Slope Regional Corporation, 834, P.2d 134 (Alaska 1991)." This well and several others were granted extended confidentiality, but were ultimately release to the public when acreage in the Immediate area was leased. The total area that contains the wells has recently been included in the Great Moose's' Tooth Unit established by BLM. 3/18/2008 Page 2 of 2 I request you council and assessment as to how the submitted information should be handled. Until a determination is made, I am holding all filed information in my confidential box. Thanks in advance, Tom Maunder, PE Sr. Petroleum Engineer 3/18/2008 Rendezvous #2 Weekly Report. • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Sunday, March 16, 2008 2:36 PM To: 'Morgan, Mike R' ao~-~o~ Cc: Lemke, Sandra D; Allsup-Drake, Sharon K; Brassfield, Tom J Subject: RE: Rendezvous #2 Weekly Report Thanks Mike. That is fine. 1 will look forward to the report next week. Tom Maunder, PE AOGCC From: Morgan, Mike R [maitto:Mike.R.Morgan@conocophillips.com] Sent: Saturday, March 15, 2008 9:28 AM To: Maunder, Thomas E (DOA) Cc: Lemke, Sandra D; Allsup-Drake, Sharon K; Brasfield, Tom J Subject: Rendezvous #2 Weekly Report Tom, The Rendezvous #2 well has been shut-in (downhole) over the past week (3/7-3/14), with no activity to report. We will pull the gauges this coming week and begin the well abandonment. I or Tom Brassfield will submit the next weekly summary on 3/21. Best regards, Mike Morgan ConocoPhillips, Alaska Inc. 3/16/2008 • • SARAH PALIN, GOVERNOR nilt~.a7~ OI~ ~`~/ ~ 333 W. 7th AVENUE, SUITE 100 COI~TSERYATIOi~T CO1~iAIISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Exploration & WNS Team Leader ConocoPhillips Alaska, Inc. `~,~,~~,~~ ~~ z ~~~ PO Box 100360 Anchorage, Alaska 99510 Re: Exploration Well ,Rendezvous #2 Sundry Number: 308-073 t~ ©~ °' ~~ Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such fiu-ther time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~ day of March, 2008 Daniel T. Seamount. Jr. Chair Encl. • C~ocoPhillips Box 100360 Alaska 99510-0360 March 6, 2008 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for P&A: Rendezvous #2 Surface Location: 1707' FNL, 2632' FEL, Sec 6, T9N-R2E X=1,425,418 & Y=5,912,987 ASP4 NAD83 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a Sundry to permanently plug and abandon an onshore exploratory well in the NPRA -Alaska. The well was originally drilled and completed in April of 2001 by Doyon 141. More recently the well was stimulated and a flow test performed. Please find attached the 10-403 Sundry and procedural outline for the P&A. The anticipated start date for this P&A is March 15, 2008. If you have any questions or require further information, please contact Tom Brassfield at (907) 265-6377 or Chip Alvord at (907) 265-6120 Sincerely, Tom Brassfield Senior Drilling Engine r cc: CONFIDENTIAL -Rendezvous #2 ~~~~~~~~ Chip Alvord ATO-1570 N[~R ~ ~ ~,~~ Mike Morgan ATO-1392 ~ ~ ~, ~Yt'~tfS~fl' ~~~ ORIGINAL 2-~ ~o~ RE~~11l~~ ~'' ,ti STATE OF ALASKA ,1'3 MAR 0 7 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION ~.~ APPLICATION FOR SUNDRY APPRO~AA~#ka 4ii & Gas Cons. 20 AAC 25.280 A11d10fd9e 1. Type of Request: Abandon Q Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Pertorations ~ Stimulate ^ Time 6ctension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^~ 201-007 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20363-00 7. KB Elevation (ft): 9. Well Name and Number: 97.5' AMSL Rendezvous #2 8. Property Designation: 10. Field/Pools(s): ~ ADL AA-081781 / ALK 5126 NPRA Exploration 11. PRESENT WELL CONDIT ION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured) . Junk (measured): 8650' ~ 8650' 8516' 8516' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 108' 108' na na Surface 2645' 9.625" 2673' 2673' 5750 3090 Intermediate Production 8574' 7" 8602' 8602' 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8250'-8290' 8250'-8390' 3-1/2" L-80 8336' Packers and SSSV Type: Packers and SSSV MD (ft): SAB-3 SAB-3 @ 7952' 12. Attachments: Description Summary of Proposal Q 13. Well Ciass after proposed work: Detailed Operations Program^ BOP Sketch ^ Exploratory^ Development ^ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/15/2008 Oil ^ Gas ^ Plugged ^~ Abandoned ^~ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Brassfield na. 265-6377 Printed Name C ip Alvord Title Exploration & WNS Team Leader Signature Phone 265-6120 Date 3/6/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: "`~ c~~3 Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~ (`(~ '-. ~~ ~~o~-~-~~~c.ss c~~-,bhS , ~ ~~ ~c~c~r'~~ C~O-~-r h ~ ~ er: ~ ~~~~~~ Ot ~cs~L-~ ~ctE~c~~c~ ~~~c-~ r~ r Subsequent Form Required: 1_-~ .. ~ ~ APPROVED BY Approved by' COMMISSIONER THE COMMISSION Date:3/I~/~ ~ ~ Form 10-403 Revised 7/2005 ORIGINAL ~`~ ~~~~~ SUBMIT IN DUPLICATE Rendezvous #2 Final P&A CONFIDENTIAL Revised 3/6/08 • Well Status: Rendezvous #2 was drilled/completed during the 2001 winter NPRA exploration drilling season. The well is currently SI after a five day +/- flow test in February/March of this year and will be P&A'd before the ice road system is secured for the season. The work should be completed prior to 5/1/04. The 9-5/8" x 7" annulus has a diesel freeze protect- depth unknown at this time. The 3-1/2" x 7" annulus has been evacuated with nitrogen down to the GLM at 7854' MD. The 3-1/2" tubing will have produced fluids to surface- note SITP. 1. Notify BLM/AOGCC 48 hours in advance of all pressure testing and well suspension operations. Hold pre job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Confirm with Wells Group that dummy valves are set in both GLM's at 7854', and 2494' M D 3. Mobilize and rig up D/S for well P&A operation. 4. Bullhead 9.6 ppg NaCI Brine to the top perforation at 8350' or approx. 73 bbl -note injection rate and pressures, pump an additional 5 bbls. RU slickline and pull dummy from the GLM at 7854'. RD slickline. Open the 3-1/2" x 7" annulus and circulate 9.6 ppg NaCI brine until diesel is displaced from backside or approx. 207 bbl. Close the 3- 1/2"x7" annulus valve. 5. Mix approx. 25 bbls. (2874' of tubing volume) cement (Class G with additives) and displace w/9.6 ppg brine down tubing to the top perforation at 8350'. Hesitate squeeze cement (approx 8 bbls planned) into perfs as required. Open 3-1/2"x7" annulus valve and displace an additional 7.9 bbls to the backside- SI. This should leave approx. 300' of cement in the annulus and in the tubing above the GLM at 7854'. 6. RU cementing unit to 7" x 9-5/8" annulus. Confirm injection rate into the annulus with . diesel, swap to fresh water and flush with 100 bbls, followed by approx. 28 bbls (1000' of annular volume) of AS1 cement. RD D/S. 7. Rig up slickline unit and RIH to tag top of cement plug inside tubing to verify placement. Record and report results. Pressure test casing to 1500 psi. BLM/AOGCC may want to witness tag of cement and pressure test. 8. RIH with tubing plug and set in the 'DS' nipple at 892' MD. POOH. Make up 2' of 1-, 11/16" Puncher gun loaded at 4spf (designed to perforate the 3-1/2" 9.3 ppf L-80 tbg), RIH, and perforate tubing just above the `DS' nipple at 892' MD. POOH. Open 3- 1/2"x7" annulus to establish circulation down the tubing up the annulus. SI. RD slickline. 9. RU D/S. Open 3-1/2"x7" annulus. Circulate AS1 cement (approx. 32 bbls) down the tubing up the casing/tubing annulus to surface. SI and wait 30 minutes. Confirm the 3- 1/2"x7" annulus stays full- SI. RD D/S. NOTE: Notify BLM/AOGCC Inspectors before setting surface plug(s). 10. Clear lines and shut down pumps. Rig down cementing unit and clean up. 11. Cut off wellhead and all casing strings at 3 feet below original ground level. Verify that cement is back to surface in all strings. Add cement as required. Send casing head with stub to Materials for repair / re-dressing. TJB 3/6/08 • Rendezvous #2 Final P&A CONFIDENTIAL Revised 3/6/08 • 12. Weld'/<" thick cover plate (16" in diameter) over all casing strings with the following information bead welded into the top (weep hole required). ConocoPhillips Rendezvous #2 PTD # 201-007 API # 50-103-20363-00 13. Remove cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level with gravel/fill. Clear and scrape the ice pad location as needed and demob all materials and equipment. Close out with the appropriate agencies. TJB 3/6/08 TJB 3/6/08 FILE: Rendezvous #2 Rendezvous #2 PHILLIPS „w_Y..., P&A Schematic °' r '` Depths are based on Doyon 141 RKB = 27.85' (RKB - LR) 16" 65# H-40 @ +/- 115' MD Surface csg. 9-5/8" 40.0# L-80 BTCM (2673' MD 12673' TVD) 3/6/08 ~'- 892' cement column in the 3'/z" tbg 8~ 3'/z" tbg x 7" annulus Surface casing cemented a; follows: 20 bbls CW 100 Wash 40 bbls of 10.5 ppg MudPUSHXI Spacer 332 bbls ASIII Lite @ 10.7 ppg 4.44 cu. ft./sk 72 bbls of 12 ppg LiteCrete 2.38 cu ft/sk Full returns, bumped plug, float; held r1 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 3-1l2" FMC Gen V Tubing Hanger, 4-1 /2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 892' cement column in the tbg & annulus above the `DS' nipple 3-1/2" Camco'DS' nipple w/ 2.875" profile set at 892' MD. 1000' cement column in the 9-5/8" x 7" annulus 3-1 /2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" x 1" Camco 'KBMM-2' mandrel w/ shear valve @ 2900 psi, 6' L-80 handling pups installed above and below. Mandrel @ 2494' MD 300' cement column in the tbg & annulus above the GLM 3-1/2" x 1" Camco 'KBMM-2' mandrel w/BK-5 latch and dummy, 6' L-80 handling pups installed above and below. Mandrel @ 7854' MD Cement from GLM to the be pert w/ approx. 8 bbls sque away 1 jt 4-1/2" 12.6# L-80 EUE8RD tubing 3-1/2" Camco 'X' nipple w/ 2.813" profile. (questionable ID?) 1 jt 3-1 /2" 9.3# L-80 EUE8RD tubing Baker PBR (10') w/Model K-22 tbg seal nipple. PBR shear @ 39K #) Assembl casing cemented as follows: i bbls CW 100 Wash i bbls MudPUSHXL i bbls 12.0 ppg LiteCrete @ 2.4 c1 bbls 15.8 ppg Gasblock @ 1.2 c spl. w/326 bbls 9.6 ppg brine. Lc i% returns after 290 bbls p~ imped plug, floats held Baker 7" x 4" 'SAB-3' Packer pin f/1500 psi shear Top to bottom: 4" x 3.5" XO sub, 6' pup, 9 jts 3.5" 9.3ppf L-80 tubing, 6' pup, Camco 3.5" x 1" KBMM-2 GLM w/BK-5 latch and dummy @ 8252', 6' pup, 1 jt tubing, 6' pup, Camco 3.5" x 1" KBMM-2 GLM w/BK-5 latch and dummy @ 8302', 6' pup, 10' pup, 3.5" x 2.75" XN nipple (Plug installed and tested), 10' pup, ported sub. Tail @ 8336' MD Perforations: 8350' - 8390' @ 5 spf 49.7' of fired & dropped TCP guns (8515' - 8465') left in hole Float Collar @ 8516' Production casing. 7" 26.0# L-80 BTCM (8602' MD / 8602' TVD) TJB 3/6/08 DRAFT NOTES: 1. BASIS OF COORDINATES: OPUS SOLUTION OF GPS STATIC OBSERVATIONS 2. COORDINATES ARE NAD 83, ALASKA STATE PLANE ZONE 4. 3. ELEVATIONS ARE REFERENCED TO NAVD88 VERTICAL DATUM. 4. DISTANCES ARE TRUE. ALL DISTANCES AND ELEVATIONS ARE IN ENGLISH FEET. 5. DATE OF SURVEY 1/22/08. of d n Vicinity Map CP07-21-56A N: 5,913,397.479 E: 1, 425, 586.073 NAVD88: 94.426' ~ 2" AL CAP ON 5/8" o~ Z REBAR, 0.20 AGL CP07-21-56B N: 5, 913, 227.744 E: 1,425,064.274 NAVD88: 98.506' 2' AL CAP ON 5/8" REBAR, 0.25 AGL !4Z`6- N 5912998.9829 E 1425275.8388 ~v~ a ~ 1 ° ~,a 4 ~ ~ ~ o I s~ , ~ ~ , HARRISON ~ BAY o ~ b 1 o p o C - ~ 0 Q D- ~ ~ 's o RENDEZVOUS-2 LOCATED WITHIN PROTRACTED SECTION 6, T. 9 N., R. 2 E. UMIAT MERIDIAN. ALASKA 1707' FNL 2632' F'EL N 5912811.0244 E 1425344.0428 NAD83 Datum N 70°09'55.9" W 151°43'48.7 ASPC ZN4 (Y) 5,912,987.04 (X) 1,425,418.32 96, 5 N 591312x9308 E 14138327219 / AS-STAKED ICE ROAD 99 5 ~ fi..8. N 99 5 N 59' r E 14: KU U KP I K CONOCOPHILLIPS OF ALASKA, INC. RENDEZVOUS-2 ~~~~ SITE TOPONRAPH~tKASURVEY __ 'aeea~~e""" """'°"I°"""'°'°aao' "°^z~'°'° DATE: 1/22/2008 DRAWN BY: CZ SHEET: 1 - ~ IWne OHca (9011 fi10A139 Alpine Survey Office SCALE: 1` = 200' CHECKED BY: DB W.O. No: 07-11-20-1D 0 200 SCALE IN FEET • • Page 1 of 2 Maunder, Thomas E (DOA) From: Morgan, Mike R [Mike.R.Morgan@conocophillips.com] Sent: Wednesday, March 12, 2008 7:28 PM To: Maunder, Thomas E (DOA) Subject: RE: Rendezvous #2 Status Report 3/7 r~~ ~'~ ~~~ Yes, at the beginning of post-frac clean up period (2/19-2/22); we then shut the well in for a build and to run the downhole shut-in tool for the diagnostic flow period (2/27 -3/2). From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, March 12, 2008 7:23 PM To: Morgan, Mike R Subject: RE: Rendezvous #2 Status Report 3/7 Did you lift using nitrogen? From: Morgan, Mike R [mailto:Mike.R.Morgan@conocophillips.com] Sent: Wednesday, March 12, 2008 7:22 PM To: Maunder, Thomas E (DOA) Subject: RE: Rendezvous #2 Status Report 3/7 We had the OV at 7854' MD. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, March 12, 2008 7:20 PM To: Morgan, Mike R Cc: Regg, James B (DOA); Brasfield, Tom J; Yoakum, Vance D.; Kralick, Jack T Subject: RE: Rendezvous #2 Status Report 3/7 Thanks Mike. How much nitrogen head was in the IA? Tom From: Morgan, Mike R [mailto:Mike.R.Morgan@conocophillips.com] Sent: Wednesday, March 12, 2008 7:18 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Brassfield, Tom J; Yoakum, Vance D.; Kralick, Jack T Subject: RE: Rendezvous #2 Status Report 3/7 Tom, Once we confirmed the downhole shut-in on 3/2, we bled the tubing pressure down to 378 psig and the annulus pressure remained at 1302 psig, indicating no tubing x IA communication. While the pressures on the tubing and annulus were similar during this final test they were not in communication, as evidenced by the limited IA pressure response to the more variable tubing pressures during the 4.5 day flow. However, as the wellbore temperature increased (39F on 2/27; 63F on 3/2) there was a gradual increase on the annulus pressure due to thermal expansion of the gas (nitrogen) in the annulus. The well remains shut-in until 3114 PM. 3/16/2008 Page 2 of 2 I hope this addresses your question. Mike Morgan ConocoPhillips, Alaska Inc. 907-263-4332 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, March 11, 2008 11:30 AM To: Morgan, Mike R Cc: ]im Regg Subject: RE: Rendezvous #2 Status Report 3/7 Mike, Thanks for the information. One question ... what was the response on the tubing x casing annulus when the well was SI? Based on page 3 of the plots it would appear that there is some son` of communication to the annulus. At the end, the annulus and tubing pressures are essentially equal. Look forward to your reply. Tom Maunder, PE AOGCC From: Morgan, Mike R [mailto:Mike.R.Morgan@conocophillips.com] Sent: Friday, March 07, 2008 7:23 PM To: Maunder, Thomas E (DOA) Cc: Yoakum, Vance D.; Soria, pora I; Allsup-Drake, Sharon K; Lemke, Sandra D; Sykes, Gary R.; Snyder, Frank C; West, Nancy(Doyon Associated, LLC); CPA Wells Supt; NSK Expl Env; Barreda, Brian B Subject: Rendezvous #2 Status Report 3/7 Tom, On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips Alaska, Inc. submits the attached status report for the Rendezvous #2 Well, Sundry Number 308-011. The reports are preliminary field copies and may be edited prior to final submission following completion of weN operations. We request that this exploratory well information be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d), and AS 45.50.940(3) and State v. Arctic Slope Regional Corporation, 834 P.2d 134 (Alaska 1991). Sincerely, Mike R. Morgan Exploration Engineer 907-263-4332 3/16!2008 • ConocoPhillips Alaska, Inc. Exploration ~ Land Department P.O. Box 100360 Anchorage, AK 99510-0360 John K. Norman Chairman. State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501-3539 March 7, 2008 • RECEtVEI~ MAR 1 1 2008 glaska Oil & Gas Cons. Commission Ancha~ - Re: Exploration Wildcat, Rendezvous #2 Status Report Sundry Number: 308-011 R Dear Mr. Norman: On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips Alaska, Inc. submits the attached status report for the Rendezvous #2 Well, Sundry Number 308-011. The reports are preliminary field copies and may be edited prior to final submission following completion of well operations. We request that this exploratory well information be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d), and AS 45.50.940(3) and State v. Arctic Slope Regional Corporation, 834 P.2d 134 (Alaska 1991). Sincerely, Mik ~ R. Morgan Exp oration Engi eer 907-263-4332 Cc: Von Cawvey, COP Sharon Allsup-Drake, COP Sandra Lemke, COP Dora Soria, COP Attachments (3): Rendezvous #2 Status Report 03.07.08 (1 page) 03.03.08 Final Diagnostic Flow Interim Plots (3 pages) Diagnostic Well Test Sheet 02.29 -03.03 (4 pages) • AR3B-6001-B Ex~ation Wildcat, Rendezvous #2 Status Fort Sundry Number: 308-11 March 7, 2008 3/1 (Saturday/ Summary o Flow status 05:00: 14/64th choke, 1302 psi WHP, 54F WHT, 0.47 MMSCFPD gas, 524 STBOPD, 899 SCF/STBO GOR, 0%watercut; field API @ 37.9, gas SG @ 0.84, cumulative diagnostic flow period oil @ 1285 STBO and gas @ 1.24 MMSCF (flared). 3/2 (Sunday/ Summary o Flow status 05:00: 9/64th choke, 1266 WHP, 57F, 0.54 MMSCFPD, 434 BOPD, 1248 SCF/STBO GOR, Field API 37.6; Cumulative test period flow: 1.72 MMSCF, 1758 STBO o Flow status 23:30: 16/64th choke, 1287 psi WHP, 63F WHT, 0.67 MMSCFPD gas, 614 STBOPD, 1094 SCF/STBO GOR, 0% watercut; field API @ 37.9, gas SG @ 0.82, cumulative diagnostic flow period oil @ 2270 STBO and gas @ 2.26 MMSCF. o Down-hole shut-in tool closed at 23:40, 3/2. o Flushed lines and equipment in preparation for rig down and move to Char 3/3 (Monday- Summary o Camp, test site rig down and move to Char staging pad 80% complete o Crude volume summary transferred to CD4 (Alpine) for sale -unofficial volumes. Crude Volume to Crude Date Hydrocarbon Recycle Cum Vol. (bbls) (bbls) 21-Feb 1069 1069 22-Feb 275 1344 27-Feb 227 1571 28-Feb 461 2032 29-Feb 491 2523 1-Mar 469 2992 2-Mar 622 3614 3/4 (Tuesdav- Summary o Equipment off location o Well shut-in (down-hole) for pressure build-up until 3/14 PM (12 day shut-in) 3/4 (Wednesday) to 3/7/08 Summary o Well shut-in (down-hole) for pressure build-up until 3/14 PM (12 day shut-in) On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips, Alaska Inc request that this exploratory well information be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d), and AS 45.50.940(3) and State v. Arctic Slope Regional Corporation, 834 P.2d 134 (Alaska 1991). Rendezvous #2 Final Diagnostic Flow Production Plot On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips, Alaska Inc request that this exploratory well information 02/27 13:00 to 03/2 23:40 be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d), and AS 45.50.940(3) and State v. Arctic Slope Constrained Flow to ^•500 BPD, 1150-1300 psi WHP Regional Corporation, 834 P.2d 134 (Alaska 1991). .., ® EXPRO ~o~~~h;;;;,>= Rena«zron:1 F,ow_:rF; ,n COt'tOCOPhllllp5 i o .'"" o.s 0.6 o.~ 0.6 • Ti • e =05 z ~ ..• 0.4 0.3 0.2 0.1 0.0 8 8 8 B 8 8 8 S 8 8 8 8 S 8 S 8 B S 27~F@b-Oe v GAS -~ WAiHP iom ego 600 3 3 400 200 -.+ 0 }Mar-00 it u Rendezvous #2 Final Diagnostic Flow Production Plot On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips, Alaska Inc request that this exploratory well information 02/27 13:00 to 03/2 23:40 be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d), and AS 45.50.940(3) and State v. Arctic Slope Constrained Flow to 'x500 BPD, 1150-1300 psi WH P Regional Corporation, 834 P.2d 134 (Alaska 1991). • ®EXPRO ~~~«ovn;a;,,: a°,r,,e`vu,rs2 F,aw=2(F;,rap ConocoPhillips ,~ 2000 ,~ ,~ l' >o „~ e ~ _ 7200 vr ~ ~ ~ fl . ~~~ e 4+, µ N ~. ~ ~ ~f ~ ((p Ib Y W SO ti a '°°° J a f O f ~ J y 1s J ~ ~ • 30 600 ~ sll r00 10 200 ° o s. s S. 8 8 8 8 8. 8. e. 8 8 8 8 8 8 8 8 m ~ n m ~ •- .- m ~ n m ~ ~ n ~ rii Tlms }Mar-06 27~FeD-0B --Goa ~ escw Rendezvous #2 Final Diagnostic Flow Production Plot 02/27 13:00 to 03/2 23:40 Constrained Flow to 500 BPD, 1150-1300 psi WHP ® EXPRO ,~ ,~ a F`a 50 a 40 10 0 ConocoRhllllps RenMZVOln2 Fbw II2 (Finan On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips, Alaska Inc request that this exploratory well information be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d), and AS 45.50.940(3) and State v. Arctic Slope Regional Corporation, 834 P.2d 134 (Alaska 1991). ConocoPhillips TIRIY _. trwrrE ~. Nnrr ...- vv~n csc ,~ ,~ ,~ ,~ A eoo fi00 X00 100 0 3-Ma-00 • • CUSTOMER : ConocoPhillips PERFORATON INTERVAL :0000.0 - 0000.0 m WELL TEST DATA SHEET WELL NAME : Rendezvous 2 TEST No.: Main Flow ~ q EXPRG DATE : 27-FebAB 13:00 l0 3-Mar-08 00:30 ~~ CUSTOMER REP.: Jack Kralick {/~~! ~~ BASE: ARChOrdfle, Aldskd RIG : Rigless EXPRO SUPERVISOR : Roland Taylor DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS&W WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BS&W GAS OIL WATER OIL GAS REMARKS (dd-mmm hh:mm) (64ths) (%) (psig) (°F) (psig) (MMscfd) (stb/d) (sib/d) (scf/stb) (psig) (°F) (%) (MMscf) (stb) (sib) (APIQ60°~ (Air-1) On behalf of itself and Anadarko Petroleum Corporation, Conoco Phillips, Alaska I nc reques t that this explora tory well informat ion be h eld confi dential as required u nder AS 31.05.035(c) and 20 AAC 25.537(d), and AS 45.50.940(3) and State v. Arctic Slope Region al Corpo ration, 8 34 P.2d 134 (Alas ka 1991) . Diverted from Tk #2 to Tk #3. BS8W=0 % . 29-Feb 05:00 14 1345 51 1284 0.51 463 1091 61 92 0.75 800 Diverted from Tk #3 to Tk #2. 29-Feb 05:30 14 1337 51 1284 0.50 504 993 61 87 0.77 811 Schlumber Broil hale started to take Diverted from Tk #2 to Tk #3. BS&W=0 % . 29-Feb 06:00 14 1331 52 1284 0.51 443 1146 61 81 0.78 820 Diverted from Tk #3 to Tk #2. 29-Feb 06:30 14 1334 52 1285 0.51 564 903 62 87 0.79 832 Diverted from Tk #2 to Tk #3. BSSW=O %. 29-Feb 07:00 14 1338 52 1286 0.51 524 982 61 90 0.80 843 39.0 Corr Oil Grav= 39 de PI. Diverted from Tk #3 to Tk #2. Gas SG= 29-Feb 07:30 14 1336 52 1286 0.52 544 960 61 94 0.81 854 0.832 0.832 Diverted from Tk #2 to Tk #3. BS&W=0 %. 29-Feb 08:00 14 1331 52 1287 0.52 483 1082 60 96 0.82 864 Diverted from Tk #3 to Tk #2. 29-Feb 08:30 14 1327 52 1286 0.52 544 961 60 95 0.83 875 29-Feb 09:00 14 1322 52 1286 0.52 504 1024 59 98 0.84 886 Diverted from Tk #2 to Tk #3. BS&W=0 % . Diverted Tram Tk #3 to Tk #2. 29-Feb 09:30 14 1322 53 1286 0.51 423 1212 59 95 0.85 895 Diverted from Tk #2 to Tk #3. BS8W=0 % . 29-Feb 10:00 14 1319 52 1286 0.52 504 1025 59 97 0.86 905 29-Feb 10:30 14 1316 52 1286 0.51 483 1049 57 96 0.87 915 Diverted from Tk #2 to Tk #3. BS&W=0 %. 29-Feb 11:00 14 1319 52 1285 0.49 483 1010 56 98 0.88 925 38.1 Corr Oil Grav= 38.1 de PI. Diverted from Tk #3 to Tk #2. Gas SG= 29-Feb 11:30 14 1313 52 1285 0.50 504 985 58 94 0.89 936 0.830 0.830 Diverted from Tk #2 to Tk #3. BS8W=0 % . 29-Feb 12:00 14 1304 53 1285 0.49 483 1021 58 89 0.90 946 29-Feb 12:30 14 1299 53 1286 0.50 483 1044 59 93 0.91 956 Diverted from Tk #3 to Tk #2. Diverted Tram Tk #2 to Tk #1. BS&W=0 %. 29-Feb 13:00 14 1314 53 1287 0.48 483 1003 59 91 0.92 966 Diverted Trom Tk #1 to Tk #2. 29-Feb 13:30 14 1309 52 1286 0.49 446 1091 59 94 0.93 975 Diverted from Tk #2 to Tk #1. BS&W=0 % . 29-Feb 14:00 14 1292 52 1285 0.46 483 959 58 91 0.94 985 Observed decrease in WHP and 29-Feb 14:30 14 1264 52 1285 0.45 446 1015 58 93 0.95 995 Diverted from Tk #1 to Tk #2. Diverted from Tk #2 to Tk #1. BS&W=0 % . 29-Feb 15:00 14 1227 51 1283 0.43 403 1066 58 9t 0.96 1003 Continued decrease in WHP and Diverted from Tk #1 to Tk #2. Corr Oil 29-Feb 15:30 14 1148 52 1283 0.42 539 785 58 91 0.97 1014 38.7 0.838 Grav= 38.7 d API. Gas SG= 0.838 Diverted from Tk #2 to Tk #1. BS8W=0 %. 29-Feb 16:00 14 1122 52 7284 0.43 443 973 58 93 0.98 1023 Diverted from Tk #1 to Tk #3. Started 29-Feb 16:30 14 1081 51 1283 0.41 465 880 57 90 0.99 1033 transfer from Tk #2 to Tk #5. Diverted from Tk #3 to Tk #1. BS&W=0 %. 29-Feb 17:00 14 1048 51 1284 0.38 446 842 57 85 1.00 1042 Observed ossible freezin at X-mas tree. Diverted from Tk #1 to Tk #3. Stopped 29-Feb 17:30 14 812 39 1282 0.33 781 427 57 81 1.00 1059 transfer from Tk #2 to Tk #5. Diverted from Tk #3 to Tk #1. BS&W=0 % . 29-Feb 18:00 14 1289 50 1285 0.43 446 956 59 74 1.01 1068 Observed ossiblefreezin at X-mas tree. Diverted from Tk #1 to Tk #2. BS&W = 29-Feb 18:30 14 1307 51 1263 0.45 558 814 58 69 1.02 1080 0%. Diverted from Tk #2 to Tk #4. Corr Oil 29-Feb 19:00 14 1330 53 1292 0.46 521 888 59 75 1.03 1091 38.7 0.838 Grav= 38.2 API. BS&W= 0 % . Diverted from Tk it4 to Tk #2. 29-Feb 19:30 14 1324 53 1288 0.51 521 970 60 88 1.04 1101 Diverted from Tk #2 to Tk #4. BS &W= 29-Feb 20:00 14 1311 53 1288 0.54 446 1218 61 90 1.05 1111 0%. 29-Feb 20:30 14 1252 52 1287 0.53 446 1193 60 94 1.06 1120 Diverted from Tk #2 to Tk #4. BS &W= 29-Feb 21:00 14 1235 52 1287 0.51 446 1148 59 96 1.07 1129 0%. Diverted from Tk #4 to Tk #2. 29-Feb 21:30 14 1246 52 1277 0.51 446 1133 60 96 1.09 1139 Diverted from Tk #2 to Tk #4. BS&W= 0 29-Feb 22:00 14 1267 53 1285 0.52 446 1164 60 98 1.10 1148 Diverted from Tk #4 to Tk #2. 29-Feb 22:30 14 1223 53 1286 0.49 446 1108 59 97 1.11 1157 Diverted Tk #2 to Tk #4. Corr Oil Grav= 29-Feb 23:00 14 1212 53 1288 0.49 502 971 59 98 1.12 1168 37.9 0.834 37.9 API. Gas SG= 0.844. BS&W= 0 Diverted from Tk #4 to Tk #2. 29-Feb 23:30 14 1227 53 1290 0.49 521 935 59 100 1.13 1179 Diverted from Tk #2 to Tk tf4. 01-Mar 00:00 14 1195 52 1286 0.48 484 999 59 98 1.14 1189 Page 1 of 4 CUSTOMER: ConocoPhillips PERFORATON INTERVAL:0000.0-OOOO.Om + EXPRO WELL TEST DATA SHEET WELL NAME : Rendervous 2 TEST No.: Main Flow ~ q , / ~ / ~ //~ U DATE : 27-Feb-08 13:00 to 3-Mar-08 00:30 l ~ CUSTOMER REP.: Jack Kralick ~ { / ~ p ~' BASE: Anchorage, Alaska RIG : Rigless EXPRO SUPERVISOR : Roland Taylor DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BSBW WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BSBW GAS OIL WATER OIL GAS REMARKS (dd-mmm hh:mm) (64ths) (%) (psig) (°F) (psig) (MMsdd) (sib/d) (sib/d) (scf/stb) (psig) (°F) (%) (MMSCf) (s[b) (stb) (API@60°t) (Air-1) On behalf of itse lf and An adarko P etroleum Corp oration, Conoco Phillips, Alaska I nc reques t that this explora tory well informat ion be h eld confi dential as required under AS 31.05.035(c) and 20 AAC 25.537(d), and A S 45.50. 940(3) a nd State v. Arct ic Slope Region al Corpo ration, 8 34 P.2d 134 (Alas ka 1991) . 01-Mar 00:30 14 1198 52 1288 0.48 446 1068 58 99 1.15 1198 Diverted from Tk #4 to Tk #2. Diverted from Tk #2 to Tk #4. 01-Mar 01:00 14 1184 52 1288 0.47 465 1018 58 100 1.16 1208 Diverted from Tk #4 to Tk #2. BSBW= 0 01-Mar 01:30 14 1176 52 1286 0.47 446 1060 59 100 1.17 1217 Diverted from Tk #2 to Tk #4. 01-Mar 02:00 14 1295 53 1283 0.50 446 1115 60 101 1.18 1226 01-Mar 02:30 14 1309 53 1286 0.48 446 1074 58 101 1.19 1235 Diverted from Tk #4 to Tk #2. Diverted from Tk #2 to Tk #4. Corr Oil 01-Mar 03:00 14 1313 52 1286 0.42 409 1031 57 98 1.20 1244 37.5 0.844 Grav= 37.5 API. Gas Grav' = 0.844. Diverted from Tk #4 to Tk #2. Pumped 01-Mar 03:30 14 1280 53 1283 0.46 446 1033 60 99 1.21 1253 methanol and diesel throw h 2" s ar in Diverted from Tk #2 to Tk #4. 01-Mar 04:00 14 1307 29 1287 0.48 477 1009 62 110 1.22 1263 01-Mar 04:30 14 1270 53 1289 0.51 538 947 62 97 1.23 1274 Diverted from Tk #2 to Tk #4. BSBW= 0 % . 01-Mar 05:00 14 1302 54 1288 0.47 524 899 61 98 1.24 1285 Diverted(rom Tk #4 to Tk#2. 01-Mar 05:30 14 1314 53 1287 0.46 423 1086 62 98 1.25 1294 Diverted from Tk #2 to Tk #4. BSBW= 0 % . 01-Mar 06:00 14 1306 53 1287 0.48 423 1134 61 98 1.26 1303 Diverted from Tk #4 to Tk#2. 01-Mar 06:30 14 1287 53 1285 0.47 403 1179 61 101 1.27 1311 Diverted from Tk #2 to Tk #4. BSBW= 0 % . 01-Mar 07:00 14 1252 52 1286 0.48 504 951 61 98 1.28 1322 Diverted from Tk #4 to Tk#2. 01-Mar 07:30 14 1269 54 1286 0.50 564 879 62 101 1.29 1334 Diverted from Tk #2 to Tk #1. BSBW= 0 % . 01-Mar 08:00 14 1269 54 1286 0.50 483 1041 62 98 1.30 1344 Diverted from Tk #1 to Tk#4. Corr Oil O1-Mar 08:30 14 1286 55 1289 0.50 465 1070 63 96 1.31 1353 38.0 Grav-- 38 API. Diverted from Tk #4 to Tk #2. BSBW= 0 % . 01-Mar 09:00 14 1287 55 1288 0.51 403 1277 63 96 1.32 1362 0.836 Gas Gravit - 0.836 Diverted from Tk #2 to Tk#4. 01-Mar 09:30 14 1279 54 1288 0.50 504 1002 62 97 1.33 1372 Diverted from Tk #4 to Tk #2. BSBW= 0%. 01-Mar 10:00 14 1273 55 1288 0.51 524 975 62 95 1.34 1383 Diverted from Tk #2 to Tk#4. Ot-Mar 10:30 14 1264 55 1285 0.51 504 1013 62 97 1.35 1394 Diverted from Tk tf4 to Tk #2. BSBW= 0 % . 01-Mar 11:00 14 1243 55 1285 0.50 483 1037 62 95 1.36 1404 Diverted from Tk #2 to Tktf4. Corr Oil 01-Mar 11:30 14 1269 42 1287 0.48 483 1002 61 94 1.37 1414 37.9 0.830 Grav= 37.9 API. Gas Gravit = 0.830 Diverted from Tk #4 to Tk #2. BSBW= 0%. 01-Mar 12:00 14 1208 55 1287 0.47 443 1070 61 91 1.38 1423 Divertedfrom Tk #2 to Tk#4. 01-Mar 12:30 14 1220 55 1287 0.47 483 963 60 93 1.39 1433 Diverted from Tk tf4 to Tk #2. BSBW= 0%. 01-Mar 13:00 14 1197 55 1288 0.47 463 1013 60 91 1.40 1443 Diverted from Tk #2 to Tk#4. 01-Mar 13:30 14 1187 55 1287 0.47 443 1053 60 92 1.41 1452 01-Mar 14:00 14 1176 55 1288 0.45 463 973 60 88 1.42 1462 O1-Mar 14:30 14 1176 55 1288 0.45 504 887 59 89 1.43 1472 Diverted from Tk #2 to Tk#4. Diverted from Tk #4 to Tk #2. BSBW= 0 % . 01-Mar 15:00 14 1158 55 1286 0.45 443 1016 59 89 1.44 1481 38.6 0.832 Corr Oil Grav= 38.6 API. Gas Gravit = Diverted from Tk #2 to Tk#4. 01-Mar 15:30 14 1143 55 1284 0.43 423 1026 59 87 1.45 1490 Diverted from Tk #4 to Tk #2. Switched 01-Mar 16:00 18 1124 55 1286 0.43 443 977 60 89 1.45 1499 choke from 14/64th sitive to 18/641h Diverted from Tk #2 to Tk#4. BSBW= 0 Ot-Mar 16:30 8 1197 53 1293 0.58 584 985 61 87 1.47 1512 01-Mar 17:00 14 1272 55 1292 0.50 524 951 60 85 1.48 1522 Diverted from Tk #2 to Tk #3. 01-Mar 17:30 14 1284 55 1291 0.50 504 988 61 92 1.49 1533 Diverted from Tk #3lo Tk #2. Finished 01-Mar 18:00 14 1256 54 1291 0.51 524 980 61 92 1.50 1544 transferrin toTrodc#115. Diverted from Tk #2 to Tk #3. BSBW=O % . 01-Mar 18:30 14 1249 54 1290 0.52 443 1178 62 94 1.51 1553 Diverted from Tk #3 to Tk #1. Started to 01-Mar 19:00 14 1234 55 1288 0.48 463 1031 60 92 1.52 1563 38.6 0.832 um Tk #2 to Truck #116. 01-Mar 19:30 14 1234 55 1287 0.47 502 943 61 95 1.53 1573 Page 2 of 4 • CUSTOMER : ConocoPhillips PERFORATION INTERVAL :0000.0 - 0000.0 m WELL TEST DATA SHEET WELL NAME : Rendezvous 2 TEST No.: Main Flow M EXPRO DATE : 27-Feb-OS 13:00 l0 3-Mar-0B 00:30 ~ ~ CUSTOMER REP.: Jadc Krelick (L~/~~{/f~ ' BASE: Anchorage, Alaska RIG : Rigless EXPRO SUPERVISOR : Roland Taybr DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS&W WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BSBW GAS OIL WATER OIL GAS REMARKS (dd-mmm hh:mm) (64ths) (%) (psig) (°F) (psig) (MMSCfd) (sib/d) (sib/d) (scf/s[b) (psig) (°F) (%) (MMscf) (stb) (stb) (API~60°f) (Air-1) On behalf of itse lf and An adarko P etroleum Corp oration, Conoco Phillips, Alaska I nc reque st that this explora tory well informat ion be h eld confi dential as required u nder AS 31.05.035(c) and 20 AAC 25.537(d), and A S 45.50. 940(3) a nd State v. Arct ic Slope Region al Corpo ration, 8 34 P.2d 134 (Alas ka 1991) . 01-Mar 20:00 14 1226 55 1287 0.48 463 1037 60 92 1.54 1583 Diverted from Tk #3 to Tk #4. Diverted from Tk #4 to Tk #2. BS&W= 0 % . 01-Mar 20:30 14 1226 55 1289 0.48 446 1068 60 94 1.55 1592 Ot-Mar 21:00 14 1226 55 1289 0.46 409 1132 60 90 1.56 1601 Diverted from Tk #2 to Tk #4. Diverted from Tk #4 to Tk #2. BS&W =0 % . 01-Mar 21:30 14 1222 55 1290 0.47 484 967 61 91 1.57 1611 01-Mar 22:00 14 1220 55 1289 0.47 409 1140 60 90 1.58 1619 Diverted from Tk #2 to Tk #4. 01-Mar 22:30 14 1218 55 1289 0.47 446 1051 61 94 1.59 1629 Diverted from Tk #41o Tk #2. Diverted from Tk #2 to Tk #4. Gas SG = Ot-Mar 23:00 14 1217 55 1290 0.47 484 967 61 95 1.60 1639 38.6 0.832 0.832. Corr Oil Grav= 38.1 API. BS&W= 01-Mar 23:30 14 1206 55 1288 0.47 446 1054 61 95 1.61 1648 Diverted from Tk #4 to Tk #2. 02-Mar 00:00 14 1206 56 1288 0.47 446 1049 61 97 1.62 1657 Diverted from Tk #2 to Tk #4. Diverted from Tk #4 to Tk #2. 02-Mar 00:30 14 1198 55 1289 0.47 446 1043 61 97 1.63 1667 Diverted from Tk #2 to Tk #4. BS&W= 0 % . 02-Mar 01:00 14 1195 56 1288 0.47 465 1002 60 97 1.64 1676 Diverted from Tlc #4 to Tk #2. 02-Mar 01:30 14 1199 55 1288 0.47 446 1049 60 98 1.65 1686 02-Mar 02:00 14 1194 56 1289 0.46 465 994 59 97 1.66 1695 Diverted. from Tlc #2 to Tk iW. Diverted from Tk #4 to Tk #2. Corr Oil 02-Mar 02:30 14 1190 56 1288 0.46 446 1037 60 98 1.67 1705 Grav= 37.6 API. BS&W= 0%. 02-Mar 03:00 9 1113 57 1291 0.59 521 1139 61 98 1.68 1715 37.6 Diverted from Tl< #2 to Tlc #4. BS&W= 0%. 02-Mar 03:30 9 1215 57 1292 0.53 521 1026 61 97 1.69 1726 Diverted from Tlc tf4 to Tk #2. Diverted from Tlc #2 to Tlc #4. Gas SG = 02-Mar 04:00 9 1240 58 1293 0.56 558 995 61 99 1.70 1738 0.843 0.843. Diverted from Tk #4 to Tk #2. 02-Mar 04:30 9 1267 57 1293 0.54 521 1039 61 97 1.71 1749 Diverted from Tl<#2 to Tk #4. 02-Mar 05:00 9 1266 57 1291 0.54 434 1248 60 97 1.72 1758 02-Mar 05:30 16 1178 58 1292 0.62 564 1095 63 100 1.74 1770 Diverted from Tlc #4 to Tk #2. Diverted from Tk #2 to Tk #4. BS&W= 0 % . 02-Mar 06:00 16 1232 59 1295 0.63 604 1050 63 98 1.75 1782 02-Mar 06:30 16 1316 60 1300 0.67 685 978 64 99 1.76 1796 Diverted from Tk #4 to Tk #2. Diverted from Tl< #2 to Tk #4. BS&W= 0%. 02-Mar 07:00 16 1312 59 1301 0.73 645 1130 65 93 1.78 1810 38.7 0.812 Corr Oil Grav= 38.7 API. BSBW= 0 % .Gas 02-Mar 07:30 16 1316 60 1301 0.71 685 1035 64 86 1.79 1824 Diverted from Tlc #4 to Tk #2. Diverted from Tk #2 to Tk #4. BS&W= 0%. 02-Mar 08:00 16 1311 60 1304 0.72 624 1154 65 98 1.81 1837 Diverted from Tk #4 to Tk #2. 02-Mar 08:30 16 1304 60 1303 0.73 685 1064 65 99 1.82 1851 Diverted from Tk #2 to Tk #4. BS&W= 0%. 02-Mar 09:00 16 1303 60 1307 0.72 624 1159 65 101 1.84 1864 02-Mar 09:30 16 1298 61 1304 0.71 705 1010 65 102 1.85 1879 Diverted from Tk #4 to Tk #2. Diverted from Tk #2 to Tk #4. BS&W= 0 %. 02-Mar 10:00 16 1292 61 1306 0.71 624 1132 64 100 1.87 1892 Diverted from Tk #4 to Tk #2. 02-Mar 10:30 16 1295 61 1307 0.71 705 1001 64 100 1.88 1907 Diverted from Tk #2 to Tk #4. BS&W= 0 % . 02-Mar 11:00 16 1298 62 1308 0.69 624 1111 64 102 1.90 1920 38.4 0.832 Corr Oil Grav= 38.4 API. BS&W= 0 % .Gas Diverted from Tk #4 to Tk #2. 02-Mar 11:30 16 1292 62 1309 0.69 685 1006 63 100 1.91 1934 Diverted from Tk #2 to Tk #4. BS&W= 0%. 02-Mar 12:00 16 1292 62 1308 0.68 624 1093 63 99 1.93 1947 Diverted from Tk #4 to Tk #2. 02-Mar 12:30 16 1292 62 1310 0.67 624 1074 63 100 1.94 1960 Diverted from Tk #2 to Tk #4. BSBW= 0%. 02-Mar 13:00 16 1292 62 1312 0.67 665 1012 63 95 1.95 1974 Diverted from Tk #4 to Tk #2. 02-Mar 13:30 16 1292 62 1312 0.67 665 1006 63 99 1.97 1988 Diverted from Tk #2 to Tk #4. BS&W= 0%. 02-Mar 14:00 16 1294 62 1311 0.68 645 1048 63 95 1.98 2001 38.3 Corr Oil Grav= 38.3 API Diverted from Tk #4 to Tk #2. 02-Mar 14:30 16 1292 62 1313 0.68 665 1018 63 96 2.00 2015 Diverted from Tk #2 to Tk #4. BS&W= 0%. 02-Mar 15:00 16 1293 62 1312 0.67 665 1009 63 96 2.01 2029 0.824 Gas SG= 0.824 Page 3 d 4 CUSTOMER : ConocoPhillips PERFORATON INTERVAL :0000.0 - 0000.0 m WELL TEST DATA SHEET WELL NAME: Rendezvous 2 TEST No.: Main Fbw is ~p EXPRO DATE : 27-Feb-0B 13:00 to 3-Mar-08 00:30 ~ CUSTOMER REP.: Jack Krelidc (~/~~j~//~ I®! BASE: Anchorage, Alaska RIG : Rigless FJCPRO SUPERVISOR : Roland Taybr DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS&W WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BS&W GAS OIL WATER OIL GAS REMARKS (dd-mmm hh:mm) (64ths) (%) (psig) (°F) (psig) (MMscfd) (stb/d) (stb/d) (scf/sib) (psig) (°F) (%) (MMscf) (sth) (sib) (API@60°f) (Air-1) On behalf of itself and Anadarko P etroleu m Corp oration, ConocoPhillips, Alaska I nc reque st that this explora tory well informa tion be h eld confi dential as required u nder AS 31.05.035(c) and 20 AAC 25.537(d), and AS 45.50.940(3) a nd State v. Arct ic Slop e Regional Corporation, 8 34 P.2d 134 (Alas ka 1991) . 02-Mar 15:30 16 1294 63 1313 0.68 665 1016 63 95 2.02 2043 Diverted from Tk #4 to Tk #2. 02-Mar 16:00 16 1294 63 1315 0.66 665 990 62 88 2.04 2057 Diverted from Tk fY2 to Tk fR3. BS&W= 0%. 02-Mar 16:30 16 1292 63 1315 0.66 645 1028 64 95 2.05 2070 Diverted from Tk #3 to Tk #2. 02-Mar 17:00 16 1287 63 1315 0.67 645 1034 63 93 2.06 2083 Diverted from Tk ff2 to Tk #3. BS&W= 0 % . 02-Mar 17:30 16 1290 63 1315 0.67 645 1040 64 95 2.08 2097 Diverted from Tk #3 to Tk #4. Diverted from Tk #4 to Tk #3. Generator 02-Mar 18:00 16 1290 63 1316 0.66 577 1147 63 89 2.09 2109 #1 shut down, Switched to enerator #2. Diverted from Tk #3 to Tk #4. BSRW 02-Mar 18:30 16 1292 63 1316 0.65 663 975 63 83 2.11 2123 =0.25% Water Diverted from Tk #4 to Tk #2. Gas SG= 02-Mar 19:00 16 1289 63 1315 0.64 686 933 63 83 2.12 2137 0.818. BS&W=0.35 % Water. Diverted from Tk #2 to Tk #4. BSBW 02-Mar 19:30 16 1289 63 1316 0.67 668 998 64 93 2.13 2151 38.3 0.818 =0.25%. Cort Oil Grav= 38.3 API. Diverted from Tk #4 to Tk #2. 02-Mar 20:00 16 1288 63 1316 0.67 649 1029 64 97 2.15 2164 37.9 0.818 BS&W=0.25%. Diverted from Tk #2 to Tk #4. 02-Mar 20:30 16 1289 63 1314 0.67 649 1034 64 94 2.16 2178 BS&W=0.25 % . Diverted from Tk #4 to Tk #2. 02-Mar 21:00 16 1287 63 1314 0.67 612 1097 64 97 2.18 2191 BS&W=0.25 % . Diverting from Tk #2 to Tk ff4. 02-Mar 21:30 16 1288 63 1316 0.67 649 1027 63 96 2.19 2204 BS&W=0.25%. 02-Mar 22:00 16 1290 63 1315 0.67 614 1099 64 98 2.20 2217 Diverting from Tk #4 to Tk #2. Diverted from Tk #2 to Tk #4. 02-Mar 22:30 16 1287 63 1316 0.66 631 1050 63 92 2.22 2230 BS&W=0.25%. Diverted from Tk #4 to Tk #2. 02-Mar 23:00 16 1287 63 1317 0.65 667 981 64 91 2.23 2244 BS&W=0.35%. 02-Mar 23:30 16 1287 63 1317 0.67 614 1094 64 96 2.24 2257 Diverted from Tk #2 to Tk #1. 03-Mar 00:00 16 1125 62 1315 0.65 618 1045 81 91 2.26 2270 03-Mar 00:30 378 61 1302 Page 4 of 4 • ConocoPhillips Alaska, Inc. Exploration ~ Land Department P.O. Box 100360 Anchorage, AK 99510-0360 John K. Norman Chairman State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7t" Avenue, Suite 100 Anchorage, AK 99501-3539 February 29, 2008 Re: Exploration Wildcat, Rendezvous #2 Status Report Sundry Number: 308-011 Dear Mr. Norman: • RECEIVE® MAR 0 4 2008 giaska Oii & Gas Cons. Commission Anchorage On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips Alaska, Inc. submits the attached status report for the Rendezvous #2 Well, Sundry Number 308-011. The reports are preliminary field copies and may be edited prior to final submission following completion of well operations. We request that this information be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). Sincerely, o` . `° Mik R. Morgan Exploration Eng 907-263-4332 Cc: Von Cawvey, COP Sharon Allsup-Drake, COP Sandra Lemke, COP • Attachments (5): Rendezvous #2 Status Report 02.22-29 (2 pages) Preliminary Petredat Plot 01.26.08 (1 page) Rendezvous #2 Final Diagnostic Flow Production Plot 02.27-02.29 (1 page) Rendezvous #2 Final Diagnostic Flow Production Ratios 02.27-02.29 (1 page) Diagnostic Well Test Sheet 02.27-02.29 (4 pages) AR36-6001-B Exploration Wildcat, Rendezvous #2 Status i~rt Sundry Number: 308-11 February 29, 2008 2/22 (Friday) Summary o Shut-In at 06:00 2/22 for post-clean-up pressure build-up. 0 2/22 6AM Rates ifinal hour average flow rate before shut-in): ^ 1390 BLPD ^ 1300 BOPD ^ 90 BWPD (7%) ^ 1.43 MMSCFPD ^ 1077 SCF/STBO ^ 192 psi WHP ^ 95F WHT o Transferring fluids to Alpine o Freeze protect lines and equipment o Standby and monitor wellhead pressure (WHP) o Equipment checks and maintenance 2/23 (Saturday) Summary o Standby and monitor wellhead pressure (WHP) ^ 6AM: 1418 psi WHP o Equipment checks and maintenance 2/24 (Sundayl Summary o Standby and monitor wellhead pressure (WHP) ^ 6AM: 1451 psi WHP o Equipment checks and maintenance 2/25 (Monday) Summary o Standby and monitor wellhead pressure (WHP) ^ 6AM: 1460 psi WHP o Rig up slickline, tag top of pert guns at 8352' SLM; fish moved 5' down hole. o Pull memory gauges o Pull and replace orifice valve at 7854' MD o Run memory pressure gauges 2/26 (Tuesday) Summary o Run CaTS gauges, stopping 14 times for channel checks; lock set early; pull tool out of hole to redress o Rerun CaTS gauge with downhole shut-in tool. On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips, Alaska Inc. request that this information be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). Exploration Wildcat, Rendezvous #2 Status I~rt Sundry Number: 308-11 February 29, 2008 2127 (Wednesdayl Summary o Open well at 5/64ths to test separator (02:36 AM) o Flowline frozen, shut-in well o CaTS gauge not transmitting, pull tool from well (will not rerun) o Pull & reprogram downhole shut-in tool and set at 7906' MD o Opened well to flow @ 1:45 PM for four day constrained rate diagnostic flow and fluid sampling (Shut-in, downhole, programmed for 3/2 @ 11:40 PM) 2128 (Thursdayl Summary o Flow status 07:30: 14/64th choke, 1143 WHP, 47F, 0.44 MMSCFPD, 524 BOPD, 831 SCF/STBO GOR, Field API 37.6; Cumulative test period flow: 0.35 MMSCF, 381 STBO o Flow status 23:30: 14/64th choke, 1224 WHP, 50F, 0.45 MMSCFPD, 504 BOPD, 887 SCF/STBO GOR, Field API 38.5; Cumulative test period flow: 0.64 MMSCF, 688 STBO 2/29 (Friday) Summary o Flow status 05:00: 14/64th choke, 1345 WHP, 51 F, 0.51 MMSCFPD, 463 BOPD, 1091 SCF/STBO GOR, Field API Not Measured; Cumulative test period flow: 0.75 MMSCF, 800 STBO On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips, Alaska Inc. request that this information be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). Preliminary Petredat Guage from Station #4 @ 8302' MD 1~.CcC.OC t10.C0 9.€se.ao t7o.oo 7.c°c.GC 1',^..00 ~~ p ~ ~ 7 %J :Cf.n. i~ : E~~ ~ a -.82-. C C 90.00 O LL !~ ~ ~ ~ fl O U pp - m ~L :12 CG 2 ~i c~ U a ~ o ~D.Do . . ~ ~. C N ~ ~ co O U a ~~ U d° i~ i c~ ~ Q~ ~ c.cc 10.00 C7:C0:01 C8:1?:1~ 03:26:25 10:39:36 11:52:48 13:06:00 14:19:12 1c:32:2: 16:46:°$ 17:58:8 19:12:00 2;15108u1c~C8u17;08 2.18;08 2'19;08 2;20;08 2/21/08 2~2;C8 2;23/08 2;2-~C8 2"25108 Real-Time • On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips Alaska, Inc. requests that this information be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). • a M N QU Q 0 N C U N M O O M Q N C 0 0 W a N g W a ~ Gas-Oil Ratio (SCF/STB) ~ 0 0 0 0 ° 0 0 0 0 ° 0 o 0 0 0 0 0 0 0 0 0 0 0 13 00 : - m 16 00 - : X 00 - 19 - _-__-- ° ... - - -- -- -- : 22 00 : n 0 0 1 00 . - __ __ -- --.-_ o : ~ s ~' H 4 00 : N 00 - 4I~ 7 __.-_- ------_ __ _ _ O ~ O : G y ~ -a N e ID 10 00 __ -_ - --- 11 o : y ~ ~ ~ ~ N T 13 00 - ~ : -- _ O of 16 00 -...-------- - -. . - 0 y : _ 19 00 : -- 22:00 - -- - _ _. - -- 1 00 -- : ~~ fV 4 00 ~ : - - - . T m ~ ° ° 0 0 0 0 0 0 0 0 0 0 ~ ° (%) M'8S9 a~lo4~ CJ CUSTOMER :ConocoPhillips PERFORATION INTERVAL :0000.0 - 0000.0 m ~~r/ Ii WELL TEST DATA SHEET WELL NAME :Rendezvous 2 TEST No. :Flow #2 (Final) ,/~ i I /' ~ ~ EXPRO \~ / DATE : 27-Feb-08 13:00 to 29-Feb-OS 05:00 CUSTOMER REP. :Jack Kralick sasE: Anchorage, Alaska RIG : Rigless EXPRO SUPERVISOR : Denis Henrion DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BSBW WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BS&W GAS OIL WATER OIL GAS REMARKS (dd-mmm hh:mm) (64ths) '(%) (psig) (°F) (psig) (MMscfd) (stb/d) (stb/d) (scf/stb) (psig) (°F) (%) (MMscT) (stb) (stb) (API~60°~ (Air-1) 27-Feb 13:00 98 1210 Completed Halliburton slickline operations. Tank#1=1' 2.5", Tank#2=1' 3", Tank#3=4", 27-Feb 13:30 100 1209 Tank#4=1', Tank #5= 7.5", Tank #6= 5.5", At 13:45 Opened well for final flow. 27-Feb 14:00 8 1214 32 1225 0 65 62 0 Diverted Tk #3 to Tk #1. Started dum in 27-Feb 14:30 8 1254 36 1235 37 206 89 1 Diverted Tk #1 to Tk #3. 27-Feb 15:00 8 1286 39 1242 0.46 595 772 115 89 0.01 13 Diverted Tk #3 to Tk #1. Diverted Tk #1 to Tk #3. Switched choke 27-Feb 15:30 12 1281 39 1247 0.46 744 614 83 104 0.02 29 from 8/64th ad' to 12/64th ositive. Diverted Tk #3 to Tk #1. Decreased choke 27-Feb 16:00 16 1255 44 1258 0.87 1116 783 87 116 0.04 52 from 20/64th ositive to 16/64th ad~. 27-Feb 16:30 14 1278 45 1262 0.64 595 1080 61 123 0.05 64 Diverted Tk #1 to Tk #3. Diverted Tk #3 to Tk #1. BS&W= 0%, 27-Feb 17:00 14 1290 44 1260 0.52 298 1744 59 127 0.06 71 37.8 0.846 Corr. Oil rav= 37.8 de API, Gas SG= 27-Feb 17:30 14 1285 44 1263 0.52 893 585 58 123 0.07 89 Diverted Tk #1 to Tk #3. 27-Feb 18:00 14 1283 45 1263 0.51 521 982 57 119 0.08 100 Diverted Tk #3 to Tk #1. BS&W= 0% 27-Feb 18:30 14 1288 45 1266 0.47 818 574 58 126 0.09 117 Diverted Tk #1 to Tk #3. BS&W= 0% Diverted Tk #3 to Tk #1. BS&W= 0%, 27-Feb 19:00 14 1294 46 1267 0.53 446 1177 59 127 0.10 126 37.5 0.866 Corr. Oil rav= 37.5de API, Gas SG= 27-Feb 19:30 14 1298 46 1269 0.51 620 824 58 119 0.11 139 Diverted Tk #1 to Tk #3. 27-Feb 20:00 14 1304 46 1270 0.49 595 831 57 113 0.12 152 Diverted Tk #3 to Tk #4. BS&W= 0% 27-Feb 20:30 14 1299 47 1272 0.48 446 1086 57 106 0.13 161 Diverted Tk #4 to Tk #3. 27-Feb 21:00 14 1297 47 1272 0.47 521 908 56 98 0.14 172 Diverted Tk #3 to Tk #4. BS&W= 0% 27-Feb 21:30 14 1289 47 1272 0.46 595 777 57 91 0.15 184 Diverted Tk #4 to Tk #3. 27-Feb 22:00 14 1284 47 1274 0.45 558 812 56 84 0.16 196 Diverted Tk #3 to Tk #4. 27-Feb 22:30 14 1282 47 1275 0.44 521 854 57 83 0.17 207 Diverted Tk #4 to Tk #3. Diverted Tk #3 to Tk #4. BS&W= 0%, 27-Feb 23:00 14 1266 47 1275 0.47 403 1166 58 95 0.18 215 37.8 0.847 Corr. Oil rav= 37.8 de API Gas SG= • On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips, Alaska Inc. request that this information be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). CUSTOMER : ConocoPhillips PERFORATION INTERVAL :0000.0 - 0000.0 m ~ • li WELL TEST DATA SHEET WELL NAME :Rendezvous 2 TEST No. :Flow #2 (Final) /~ [ / , ~ EXPRO y~ / DATE : 27-Feb-08 13:00 to 29-Feb-08 05:00 CUSTOMER REP. :Jack Kralick i~" BASE: AnChOrdg@, Alaska RIG : Rigless EXPRO SUPERVISOR : Denis Henrion - DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS&W WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BS8~W GAS OIL WATER OIL GAS REMARKS (dd-mmm hh:mm) (64ths) (%) (psig) (°F) (psig) (MMscfd) (stb/d) (stb/d) (scf/stb) (psig) (°F) (%) (MMscf) (stb) (stb) (API@60°f) (Air-1) 27-Feb 23:30 14 1263 47 1276 0.50 595 834 59 110 0.19 227 Diverted Tk #4 to Tk #3. 28-Feb 00:00 14 1255 47 1278 0.52 483 1067 58 121 0.20 238 Diverted Tk #3 to Tk #4. BS8~W= 0% 28-Feb 00:30 14 1243 48 1277 0.52 335 1541 59 127 0.21 245 Diverted Tk #4 to Tk #3. 28-Feb 01:00 14 1234 48 1277 0.51 504 1004 57 123 0.23 255 Diverted Tk #3 to Tk #4. 28-Feb 01:30 14 1231 48 1277 0.49 502 969 56 116 0.24 265 Diverted Tk #4 to Tk #3. 28-Feb 02:00 14 1221 48 1276 0.47 504 943 55 110 0.25 276 Diverted Tk #3 to Tk #4. 28-Feb 02:30 14 1214 48 1277 0.48 465 1036 57 117 0.26 286 Diverted Tk #4 to Tk #3. Diverted Tk #3 to Tk #4. BS&W= 0%, 28-Feb 03:00 14 1203 48 1280 0.50 463 1070 57 127 0.27 295 37.0 0.860 Corr. Oil rav= 37.0 de API Gas SG= 28-Feb 03:30 14 1183 48 1278 0.49 454 1068 57 125 0.28 305 Diverted Tk #4 to Tk #3. 28-Feb 04:00 14 1187 48 1277 0.46 504 919 56 118 0.29 315 Diverted Tk #3 to Tk #4. BS&W= 0% 28-Feb 04:30 14 1195 47 1280 0.47 463 1010 57 121 0.30 325 Diverted Tk #4 to Tk #3. 28-Feb 05:00 14 1187 48 1279 0.48 443 1079 58 128 0.31 334 Diverted Tk #3 to Tk #4. BS&W= 0% 28-Feb 05:30 14 1175 48 1278 0.47 423 1120 57 125 0.31 343 Diverted Tk #4 to Tk #3. 28-Feb 06:00 14 1160 48 1279 0.46 463 998 56 121 0.32 353 Diverted Tk #3 to Tk #4. BS&W= 0% Diverted Tk #4 to Tk #3. Adjusted down 28-Feb 06:30 14 1156 48 1278 0.45 423 1061 56 117 0.33 361 Heater tem erature. Observed gas rate rate decreasing, 28-Feb 07:00 14 1152 48 1281 0.44 403 1081 55 111 0.34 370 started methanol in'ection manifold. Diverted Tk #4 to Tk #3. BS&W= 0%, 28-Feb 07:30 14 1143 47 1280 0.44 524 831 56 104 0.35 381 37.6 0.842 Corr. Oil rav= 37.6 de API, Gas SG= 28-Feb 08:00 14 1148 47 1279 0.43 504 847 56 100 0.36 391 Diverted Tk #3 to Tk #4. BS&W= 0%. 28-Feb 08:30 14 1121 48 1280 0.42 443 959 56 98 0.37 400 Diverted Tk #4 to Tk #3. Diverted Tk #3 to Tk #4. Taken 1 liter oil 28-Feb 09:00 14 1152 48 1279 0.42 483 862 56 93 0.38 411 sam le se arator inlet while in'ectin Diverted Tk #4 to Tk #2. Given a 50 cc oil 28-Feb 09:30 14 1146 48 1272 0.42 403 1041 56 87 0.39 419 sam le to Customer after sto in • On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips, Alaska Inc. request that this information be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). CUSTOMER : ConocoPhillips PERFORATION INTERVAL :0000.0 - 0000.0 m ~ WELL TEST DATA SHEET WELL NAME :Rendezvous 2 TEST No.: Flow #2 (Final) ~ EXPAO DATE : 27-Feb-08 13:00 to 29-Feb-08 05:00 CUSTOMER REP.: Jack Kralick ~/~ \ II' ~'- easE: Anchorage, Alaska RIG : Rigless EXPRO SUPERVISOR : Denis Henrion DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS&W WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BSSW GAS OIL WATER OIL GAS REMARKS (dd-mmmhh:mm) (64ths) (%) (psig) (°F) (psig) (MMscfd) (stb/d) (stb/d) (scf/stb) (psig) (°F) (%) (MMsc~ (stb) (stb) (APIQ60°~ (Air=1) Diverted Tk #2 to Tk #4. BS&W= 0% 28-Feb 10:00 14 1148 49 1276 0.41 372 1109 55 86 0.40 427 Diverted Tk #4 to Tk #2. 28-Feb 10:30 14 1139 49 1276 0.42 383 1103 56 90 0.40 435 Diverted Tk #2 to Tk #4. BS&W= 0%, 28-Feb 11:00 14 1132 50 1274 0.41 521 794 55 87 0.41 445 37.8 0.844 Corr. Oil rav= 37.8 de API Gas SG= Diverted Tk #4 to Tk #3. Started transfer 28-Feb 11:30 14 1123 50 1276 0.41 483 854 55 89 0.42 456 from Tk #1 to Tk #5. Diverted Tk #3 to Tk #4. BS&W= 0% 28-Feb 12:00 14 1148 51 1276 0.43 521 820 56 94 0.43 466 Diverted Tk #4 to Tk #3. 28-Feb 12:30 14 1147 51 1276 0.43 504 855 55 91 0.44 477 Diverted Tk #3 to Tk #4. BS&W= 0% 28-Feb 13:00 14 1154 52 1276 0.42 502 835 55 87 0.45 487 Diverted Tk #4 to Tk #3. 28-Feb 13:30 14 1147 52 1275 0.42 483 858 55 82 0.46 497 Diverted Tk #3 to Tk #4. BS&W= 0% 28-Feb 14:00 14 1151 52 1277 0.42 409 1030 56 86 0.47 506 Diverted Tk #4 to Tk #3. 28-Feb 14:30 14 1148 53 1280 0.42 443 956 57 86 0.47 515 Diverted Tk #3 to Tk #4. BS&W= 0%. 28-Feb 15:00 14 1160 51 1277 0.42 353 1196 57 89 0.48 523 38.6 Corr. Oil rav= 38.6 de API. Sto ed Diverted Tk #4 to Tk #3. Gas SG= 0.833 28-Feb 15:30 14 1162 52 1277 0.43 483 896 57 89 0.49 533 0.833 Diverted Tk #3 to Tk #4. BS&W= 0% 28-Feb 16:00 14 1168 52 1275 0.43 428 999 56 86 0.50 542 Diverted Tk #4 to Tk #3. 28-Feb 16:30 14 1173 52 1278 0.42 483 870 56 82 0.51 552 Diverted Tk #3 to Tk #4. BS&W= 0%. 28-Feb 17:00 14 1188 52 1275 0.42 484 869 57 78 0.52 562 Started transfer from Tk #5 to Truck #115. Diverted Tk #4 to Tk #3. 28-Feb 17:30 14 1197 52 1275 0.44 483 910 59 85 0.53 572 Diverted Tk #3 to Tk #4. BS&W= 0%. 28-Feb 18:00 14 1199 52 1276 0.45 484 924 59 85 0.54 582 Diverted Tk #4 to Tk #2. BS&W= 0%. 28-Feb 18:30 14 1204 52 1275 0.44 443 1002 59 82 0.55 591 Diverted Tk #2 to Tk #4. BS&W= 0%. Corr 28-Feb 19:00 14 1202 52 1277 0.45 446 1013 60 87 0.56 600 38.6 0.832 Oil Grav= 38.5 de API. Gas SG = 0.832. Diverted Tk #3 to Tk#2. BS&W=0%. 28-Feb 19:30 14 1201 53 1275 0.46 372 1230 59 87 0.57 608 Diverted Tk #2 to Tk #3. 28-Feb 20:00 14 1196 52 1277 0.45 372 1206 58 84 0.57 616 • On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips, Alaska Inc. request that this information be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). CUSTOMER : ConocoPhillips PERFORATfON INTERVAL :0000.0 - 0000.0 m WELL TEST DATA SHEET WELL NAME : Rendezvous 2 TEST No. :Flow #2 (Final) EXPRO DATE : 27-Feb-OS 13:00 to 29-Feb-08 05:00 ~y~~~1i CUSTOMER REP. :Jack Kralick 111"'""" BASE: AnChOrage, Alaska RIG : Rigless EXPRO SUPERVISOR : Denis Henrion DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS&W WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BSBW GAS OIL WATER OIL GAS REMARKS (dd-mmm hh:mm) (64ths) (%) (psig) (°F) (psig) (MMscfd) (stb/d) (stb/d) (scf/stb) (psig) (°F) (%) (MMsc~ (stb) (stb) (API@60°f) (Air-1) Diverted Tk #3 to Tk #2. 28-Feb 20:30 14 1206 50 1276 0.45 521 867 60 91 0.58 627 Diverted Tk #2 to Tk #3. BS&W=0 %. 28-Feb 21:00 14 1200 51 1278 0.46 558 829 60 90 0.59 638 Diverted Tk #3 to Tk #2. 28-Feb 21:30 14 1199 51 1279 0.46 465 989 60 91 0.60 648 Diverted Tk #2 to Tk #3. 28-Feb 22:00 14 1233 50 1280 0.45 446 1019 59 90 0.61 657 Diverted Tk #3 to Tk #2. 28-Feb 22:30 14 1210 50 1278 0.47 524 897 60 92 0.62 668 Diverted Tk #2 to Tk #3. Gas SG = 0.824. 28-Feb 23:00 14 1178 50 1279 0.45 446 1019 59 89 0.63 678 BS&W= 0%. Diverted Tk #3 to Tk #2. Corr Oil Grav= 28-Feb 23:30 14 1224 50 1279 0.45 504 887 59 85 0.64 688 38.5 0.824 38.3 API. Diverted Tk #2 to Tk #3. 29-Feb 00:00 14 1272 50 1280 0.45 468 966 59 81 0.65 698 Diverted Tk #3 to Tk #2. 29-Feb 00:30 14 1275 50 1280 0.47 504 931 60 87 0.66 708 Diverted Tk #2 to Tk #3. 29-Feb 01:00 14 1282 50 1282 0.47 483 965 60 88 0.67 718 Diverted to Tk #3 to Tk #2. 29-Feb 01:30 14 1316 51 1280 0.46 483 943 59 84 0.68 728 Diverted to Tk #2 to Tk #3. 29-Feb 02:00 14 1281 50 1281 0.49 504 977 61 87 0.69 739 Diverted to Tk #3 to Tk #2. 29-Feb 02:30 14 1334 51 1282 0.51 423 1198 61 89 0.70 748 Diverted from Tk #2 to Tk #3. 29-Feb 03:00 14 1347 51 1280 0.50 463 1086 61 91 0.71 757 Diverted from Tk #3 to Tk #2. Corr Oil 29-Feb 03:30 14 1354 51 1283 0.52 584 886 61 92 0.72 770 38.3 0.824 Grav= 38.2 API. BS&W=0%. Diverted from Tk #2 to Tk #3. 29-Feb 04:00 14 1354 51 1283 0.53 504 1061 62 93 0.73 780 Diverted Tnk #3 to Tnk #2. 29-Feb 04:30 14 1350 51 1284 0.53 504 1044 61 94 0.74 791 Diverted from Tnk #2 to Tnk #3. 29-Feb 05:00 14 1345 51 1284 0.51 463 1091 61 92 0.75 800 On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips, Alaska Inc. request that this information be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). s ~onocoPhillips Alaska, Inc. Exploration 8~ Land Department P.O. Box 100360 Anchorage, AK 99510-0360 John K. Norman Chairman State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501-3539 February 22, 2008 Re: Exploration Wildcat, Rendezvous #2 Status Report Sundry Number: 308-11 Dear Mr. Norman: ~aa~~~ X - ~ ~~ ~ ~~~8 ~lii Cis Cans. Anchorag8 Corrunissi0~ ao~ -~o~ On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips Alaska, Inc. submits the attached status report for the Rendezvous #2 Well, Sundry Number 308-11. The reports are preliminary field copies and may be edited prior to final submission following completion of well operations. We request that this information be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). Sincerely, ~ ~`_ Mike R. Morgan Exploration Eng 907-263-4332 Cc: Von Cawvey, COP Sharon Allsup-Drake, COP Sandra Lemke, COP Dora Soria, COP Attachments (4): AOGCC and BLM Well History Report (1 page) AOGCC Tank Farm Report (4 pages) Rendezvous 2 Expro Sequence of Operations (5 pages) Rendezvous 2 Expro Well Test Sheet (7 pages) AR3B-6001-B AOGCC Well History Report RENDEZVOUS 2 arc-~~~ API ! UWI Field Name 5010320363 NATIONAL PETROLEUM RESERVE ___ Well Type Original KB Elevation (ft) Well Status Legal WeBName TH IRENDEZVOUS2 Dail O erations Start Date Last 24hr Sum 2/21/2008 Continued Gean-up portion of the well test -shut-in well for 72 hour build-up @ 0600 hrs 2/20/2008 *** EXPRO *'"`: Continued flowing well to Expro Weli Testing and tanks -wail slugging water and sand 2/19/2008 *** EXPRO ***: ~ Begin N2 down annulus taking returns to Expro Testing unit 2/18/2008 *** SLU214 ***: SCOPE: FISH TREE SAVER/ SET ORIFICE VLV. PULLED DMY VLV @ 7854' RKB. REPLACED WITH 1/4" ORIFICE VLV. ***RECOVERED 8 SMALL PIECES OF TREE SAVER IN CATCHER*`. READY FOR FLOW BACK. JOB COMPLETE. 2/18/2008 *** FRAC ***• PUMPED FRAC TO COMPLETION WITH A TOTAL OF 256795# OF 16/30 BADGER SAND, PLACING 256795# INTO FORMATION 7 ppa. PUMPED A TOTAL OF 2403 BBLS OF SW @ AN AVERAGE TREATING PRESSURE OF 4980 PSI. iSiP = 2833 PSi. (J08 COMPLETE) 2/17!2008 *'"' CTU8 ***: FCO'0 TUBING DOWN TO 8346' CTMD (TAG TOP OF FISH) CLEAN BOTTOMS UP WITH NO SOLIDS, WELL LEFT SHUT IN AND LOADED WITH DIESEL, READY FOR FRAC. - 2/16/2008 *** FRAC ***: EST BHP = 3954 PSI 2/1612008 *** FRAC ****: Attempt to Frac, well pugged after premature shut down due to equipment failure. Road motor died.170 BBLS OF THE 290 BBL 3 ppg stage pumped. PUMPED 53475# OF 16/30 BADGER SAND, PLACING 47992# INTO FORMATION 3 ppa. Rig down Frac equipment and FCO. EST BHP = 3954 PSI 2/15/2008 *** SLU214 ***• PULLED 1" DMY VLV @8302' RKB. REPLACED WITH 1" PETRADAT SPG. READY FOR FRAC TREATMENT. JOB COMPLETE. ~ 2/13/2008 *** SLU214 ***: RUN LIB, SHOW PiC OF CUT TBG @ 5:00 ON LiB. PUMPED 50 BBL OF 15°~ HCL DISPLACED WITH DIESEL TO DISLODGE FISH. 2/11/2008 *** LRS44 ***: Pumped several stages of diesel at 6-8 bpm to try to dislodge the stuck pert guns and allow them to fall in to the rat hole. Surged the well back several times from 2000 to 500 psi. SI well to allow SL to investigate fish. 2!9/2008 *** SLU214 **"• RUN LIB 834T SLM, GET CLEAR PICTURE OF CUT TUBING LAYING OFF SET FROM TUBING. ATTEMPT TO DISLODGE PERF GUNS W/ BLIND BOX, HANG UP AFTER BEATING DN LIGHTLY. JOB SUSPENDED 2!9/2008 *** ELU2196:**: STAND-BY FOR POSSIBLE SECOND TUBING CUT 2!8/2008 *** SLU214 ***: MEASURE SBHP (cry 8350' RKB 8 GRADIENT Q 8250' RKB. SLB E-LINE JET CUT TBG Q 8331` MD, PERF GUNS DID NOT FALL INTO RATHOLE. ATTEMPT TO KNOCK OFF GUNS W! SLICKLINE, BEAT HARD, NO SUCCESS. LRS ABLE TO PUMP INTO WELL IN PROGRESS 2/8/2008 *** ELU2196 ***: CUT TUBING IN MIDDLE OF 10' PUP ABOVE FIRING HEAD AT 8331.2' 2/7/2008 *"` SLU214 *'*: ASSIST FMC W/CRANE TO PULL BPV. DHD PERFORM, PACKOFF TEST. MIT TBG TO 4000 PSI, PASS. MIT lA TO 3500 PSI, PASS. MIT OA TO 1500 PSI, FAIL. PULL XXN PLUG @ 8325' MD. RUN Lf8 ON 2.73" X 10' DUMBELL DMY DRIFT, CLEAN P1C OF SUPPOSED FIRINIG HEAD @ 8345' MD. iN PROGRESS 4/28/2001 SLICKLINE- TIGHT HOLE 4/27/2001 SLICKLINE- TIGHT HOLE 4/27/2001 4/26/2001 SLICKLINE- TIGHT HOLE 4/26/2001 4/25/2001 _ _ 4/24/2001 _ _ 4/23/2001 _ 4/22/2001 4/21/2001 4%20/2001 4/19/2001 4/18/2001 4/17/2001 ~, rnrww.peloton.com Page 1/Z Report Printed: 2/2212008 ~= AOGCC Well History Report ~onOCOPhi~~ips RENDEZVOUS 2 --~ f wrww.peloton.com Page 2/2 Report Printed: 2/22/2UU8 API / l>\!VI 5010320363 Field Name NATIONAL PETROLEUM RESERVE i Well Type Original KB Elevation (ft) Well Status TH Legal WeIlName RENDEZVOUS 2 Dail O rations Start Date Last 24hr Sum 4/16/2001 4/15/2001 _ 4/14/2001 4!13!2061 -- --- 4/12!2001 4l11l2001 - --- 4!10/2001 4!9/2001 ~ 4/8!2001 4/7/2001 __ _ ___ _ i I I I i This document was created with Win2PDF available at http://www.win2pdf.com. The unregistered version of Win2PDF is far evaluation or non-commercial use only. This page will no# be added after purchasing Win2PDF. Customer: ConocoPhflllps Well: Rendezvous 2 Start Date: 19-Feb-08 End Date: Flow Period: Clean-up Flow PeNod PRODUCTION TANK DATA SHEET Total Fluid Production: 201.00 bbls Total Oil Production: 0.00 bbls Total Water Production: 0.00 bbls Total Volume From Sand Tank: 201 bbls ConocoPhilli~s (Volume was taken from 4he vac truck 251. 15:00 21-Feb-i On behalf of itself and Anadarko Petroleum Corporation, ConocoPhAlips, Alaska Inc. submits the attached data for the Rendezvous #2 Well pursuant to the conditions of Sundry approval, number 308-011. We request that this data be held confidential as required under AS 31. Gr..~ ~.,n ~n eer ~s rz~r.~r Start End Tank Previous Strap Curcent Strap Fluid Inc. BSBrW H2O Inc. H2O Cum H2O Rate Oil Inc. Oil Cum Oil Rate Date 8 Time Date & Tlme No. feet in feet in bbl Solids Water bbl bbl bbUd bbl bbl bblld 19-Feb-08 11:51 19-Feb-08 12:00 1 0.00 0.25 1.00 3.00 22.86 0.00% 0.00% 0.00. 0.00 0.00 22.88 22.86 3658.31 19-Feb-08 12:00 19-Feb-OS 12:30 3 0.00 0.00 1.00 1.00 20.15 0.00% 0.00% 0.00 0.00 0.00 20.15 43.02 987.28 19-Feb-08 12:30 19-Feb-OS 13:00 1 1.00 3.00 1.00 5.00 3.10 0.00% 0.00% 0.00 0.00 0.00 3.10 46.12 148.81 19-Feb-08 13:00 19-Feb-08 13:30 3 1.00 1.00 1.00 2.00 1,55 0.00% 0.00% 0.00 0.00 0.00 1.55 47.87 74.41 19-Feb-OS 13:30 19-Feb-08 14:00 1 1.00 5.00 1.00 5.25 0.38 0.00% 0.00% 0'.00 0.00 0.00 0.39 48.05 18.60 19-Feb-08 14:00 19-Feb-OS 14:30 3 1.00 2.00 1.00 2.50 0.78 0.00% 0.00% 0.00 0.00 0,00 0.78 48.83 37.20 19-Feb-0B 14:30 19-Feb-08 15:00 1 1.00 2.50 1.00 5.50 4.85 0.00% 0.00% 0.00 0.00 0.00 4.65 53.48 223.22 19-Feb-08 15:00 19-Feb-08 15:30 3 1.00 • 2.50 1.00 3.50 1.55 0.00% 0.00% 0:00 0.00 0'.00 1.55 55.03 74.41 19-Feb-OS 15:30 19-Feb-08 16:00 1 1.00 5.50 1.00 5.50 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 55.03 0.00 19-Feb-08 16:00 19-Feb-08 16:30 3 1.00 3.50 1.00 4.25 1.16 0.00% 0.00% 0.00 0.00 0.00 1.16 56.19 55.80 19-Feb-OS 16:30 19-Feb-08 17:00 1 1.00 5.50 1.00 5.75 0.39 0.00% 0.00% 0.00 0.00 0:00 0.39 56.58 18.60 19-Feb-08 17:00 19-Feb-OS 17:30 3 1.00 4.25 1.00 4.50 0.39 0.00% 0.00% 0.00 0.00 0.00 0.39 56.97 18.80 19=Feb-08 17:30 19-Feb-08 18:00 1 1.00 5.75 1.00 5.75 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 56.97 0.00 19-Feb-0B 18:00 19-Feb-08 18:30 3 1.00 4.50 1.00 4.75 0.39 0.00% 0.00% 0.00 0.00 0.00 0.39 57.35 18.60 19-Feb-08 18:30 19-Feb-OS 19:00 1 1.00 5.75 1.00 6.00 0.39 0.00% 0.00% 0.00 0.00 0.00 0.39 57.74 18.60 19-Feb-08 19:00 19-Feb-08 19:30 3 1.00 4.75 1.00 4.75 0.00 0.00% 0.00% 0.00 0.00 0:00 0.00 57.74 0.00 19-Feb-08 19:30 19-Feb-08 20:00 1 1.00 6.00 1.00 6.00 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 57.74 0.00 19-Feb-08 20:00 19-Feb-08 20:25 3 1.00 4.75 1.00 4.75 0.00 0.00% 0.00% 0.00 0.00 0.00 0.00 57.74 0.00 20.Feb-OS 01:10 20.Feb-08 01:30 1 1.00 6.00 4.00 3.75 52.32 0.00% 0.00°k 0.00 0.00 0.00 52.32 110.06 3766.82 20-Feb-OS 01:30 20-Feb-08 02:00 3 1.00 11.25 3.00 2.75 24.03 0.00% 0.00% 0.00 ' 0:00 0.00 24.03 134.09 1153.30 20-Feb-08 02:00 20-Feb-08 02:30 1 4.00 3.75 4.00 5.25 2.33 0.00% 50.00% l.lfi 1.16 55.80 1.16 135,25 55.84 20-Feb-08 02:30 20-Feb-08 03:00 3 3.00 2.75 3.00 3.50 1.16 0.00% 45.00% 0.52 1.69 25.11 0.84 135.88 30.69 20-Feb-OS 03:00 20.Feb-08 03:30 1 4.00 5.25 5.00 4.50 18.02 0.50% 99.50% 17.93 19.61 860.50 0.00 135.89 0.00 20-Feb-08 03:30 20-Feb-08 04:00 3 3.00 3.50 6.00 2.25 55.70 0.00% 0.50% 0.28 19.89 13.37 55.42 191.31 2680.14 20-Feb-08 04:00 20-Feb-08 04:30 1 5.00 4.50 8.00 9.50 68.82 0.00% 20.00% 13.76 33.88 660.71 55.06 246.37 2642.83 20.Feb-OS 04:30 20-FBb08 05:00 3 6.00 2.25 8.00 9.50 52.46 0.00% 95.00% 49.83 83.49 2392.04 2.62 248.99 125.90 20.Feb-OS 05:00 20-Feb-08 05:30 1 8.00 9.50 10.00 2.00 27.70 0.50% 74.50% 20.63 104.12 890.46 6.92 255.91 332.37 20.Feb-08 05:30 20.Feb-08 06:00 3 8.00 9.50 8.00 11.00 2.52 10.00% 85.00% 2.14 106.27 102.?3 0.1? 256.04 8.04 20-Feb-08 06:00 20-Feb-08 06:30 1 10.00 2.00 11.00 5.00 25.18 10.00% 85.00% 21.40 127.67. 1027.32 1.26 257.30 50.43 20-Feb-O8 06:30 20-Feb-08 07:00 3 8.00 11.00 10.00 11.25 40.71 10.00% 90.00% 36.64 164.30 1758.53 O.OQ 257.30 0.00 20-Feir08 07:00 20-Feb-08 07:30 2 0.00 0.00 3.00 4.25 62.39 20.00% 80.00% 49,91 214:22 2395.88 0.00 257,30 0.00 20-Feb-0B 07:30 20.Feb-08 08:00 3 10.00 11.25 13.00 5.00 49.94 2.00% 40.00% 19.98 234.19 858.83 28 F~ 288.26 1390.30 20-Feb-08 0$:00 20-Feb-08 08:30 2 0.00 0.00 4.00 8.25 87.19 2.00% 40.00°k 34.88 268.07 1674.14 50.5? 336.84 2427.5? 20.Feb-08 08:30 20-Feb-08 09:00 4 0.00 0.00 1.00 7.25 29.84 '0.00% 100.00% 29.84 298.9Y 1432.32 0.00 336.44 0.00 20-Feb-OS 09:00 20-Feb-08 09:30 2 4.00 8.25 6.00 1.25 28A5 8.00% 82.00% 23.1)0 321.92 1104.24 2.8 i 339.94 134.66 20-Feb-OS 09:30 20-Feb-08 10:00 4 1.00 7.25 2.00 10.00 22.86 2.00% 90.00% 20.58 342.49. 987.74 1.83 341.47 87.80 20-Feb-08 10:00 20-Feb-08 10:30 2 6.00 1.25 7.00 8.25 31.89 0.00% 10.00% 3.19 345:68 153.09 28.70 370.1$ 1377.62 20-Feb-08 10:30 20-Feb-08 11:00 4 2.00 ~ 10.00 5.00 4.25 47.44 0.00% 10.00% 4.74 350.43 227.70 42.69 412.87 2048.30 20-Feb-08 11:00 20-Feb-08 11:30 2 7.00 8.25 9.00 3.25 31.89 0.00% 60.00% 19.14 369.56 818.54 12.76 425.63 612.36 20.Feb-08 11:30 20-Feb-O8 12:00 1 1.00 1.75 2.00 4.75 23.25 0.00°h 40.00% 9.30. 378.86 446.44 13.95 439.58 668.68 PRODUCTION TANK DATA SHEET Customer: ConocoPhlllips Well: Rendezvous 2 Start Date: 19-Feb-08 End Date: Flow Period: Clean-up Flow Period Total Fluid Production: 201.00 bbls Total Oil Production: 0.00 bbls Total Water Production: 0.00 bbls Total Volume From Sand Tank: 201 bbls ~+U11©CO~"YI~~1~35 (Volume was taken from the vac truck 251. 15:00 21-Feb-I On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips, Alaska Inc. submits the attached data for the Rendezvous #2 Well pursuant to the conditions of Sundry approval, number 308-011. We request that this data be held confidential as required under AS 31. nt mu~~ ~~,~ ~n nnr os sa~r.ri Start End Tank Previous Strap Current Strap Fluid Inc. BSB:W Hz0 Inc. Hz0 Cum Hz0 Rate OII Inc. Oil Cum Oil Rate Date 8 Time Date 8 Time No. feet In feet In bbl Solids Water bbl bbl bblld bbl bbl bblld 20.Feb-08 12:00 20-Feb-08 12:30 3 1.00 9.25 3.00 2.00 25.96 0.00% 40.00% 10.39 389.25 498.52 15,58 455.16 747.78 20-Feb-08 12:30 20-Feb-08 13:00 1 2.00 4.75 4.00 6.25 39.53 0.00% 90.00% 35.58 424.83 1707.63 3.95 459.11 189.74 20-Feb-O8 13:00 20-Feb-08 13:30 3 3.00 2.00 5.00 2.25 37.88 0.00% 90.00% 34.09 458.92 1636.41 3.79 462.90 181.82 20-Feb-O8 13:30 20-Feb-0B 14:00 1 4.00 6.25 6.00 3.50 34.93 0.00% 25.00% 8.73 467.65'' 419.18 26.20 469.10 1257.55 20-Feb-08 14:00 20-Feb-08 14:30 3 5.00 2.25 6.00 10.00 33.15 0.00% 25.00% 8.29 475.94 ' 397.83 24.86 513.96 1193.50 20-Feb-08 14:30 20-Feb-08 15:00 1 6.00 3.50 7.00 8.25 28.12 0.00% 40.00% 11.25 487.19 539.85 16.87 530.83 809.77 20.Fet>•08 15:00 20-Feb-08 15:30 3 6.00 10.00 8.00 3.25 28.96 0.00% 60.00% 17.37 504.56 833.94 11.58 542.41 555.96 20.Feb-08 15:30 20-Feb-08 16:00 1 7.00 8.25 9.00 1.00 28.1« 0.00% 17.00% 4.78 549.34 229.43 23.34 565.75 1120.16 20-Feb-OS 16:00 20-Feb-08 16:30 3 8.00 3.25 10.00 3.00 39.87 0.00% 30.00% 11.96 521.30 574.09 27.91 583.66 1339.54 20-Feb-08 16:30 20-Feb-08 17:00 1 9.00 1.00 10.00 6.75 29.80 0.00% 40.00°k 11.92 533:22 572.08 17.88 611.54 858.11 20-Fetr08 17:00 20-Feb-08 17:30 3 10.00 3.00 11.00 6.25 25.60 0.00% 12.00% 3.07 536.29 147.45 22.53 634.06 1081.30 20-Feb-OS 17:30 20-Feb-08 18:00 1 10.00 6.75 11.00 10.50 26.44 0.25% 47.50% 12.56 548.85 602.75 13.81 847.88 883.07 20.Feb-08 18:00 ' 20-Feb-0B 18:30 3 11.00 6.25 12.00 10.50 27.28 0.25% 19.75% 5.39 554.24 258.59 21,82 669.70 1047.48 20.Feb-08 18:30 20-Feb-08 19:00 1 11.00 10.50 13.00 5.25 31.47 0.00% 20.00% 6.29 560.53 302.15 25.18 694.88 1208.61 ZO-Feb-08 19:00 20-Feb-08 19:30 3 12.00 10.50 14.00 9.50 38.61 0.00% 22.00% 8.49 569.02 407.70 30.11 724.99 1445.50 20-Feb-0B 19:30 20-Feb-08 20:00 1 13.00 5.25 14.00 11.00 29.80 0.00% 25.00% 7.45 576.47 357.55 22.35 747.34 1072.64 20-Feb-08 20:00 20-Feb-08 20:30 2 1.00 11.00 3.00 6.25 29.84 0.00% 25.00% 7.46 583:93 358.08 22.38 769.72 1074.24 20-Feb-08 20:30 20-Feb-08 21:00 4 1.00 5.00 3.00 0.00 29.45 0.00% 14.00% 4.12 588.06 197.92 25.33 795.05 1215.80 20-Feb-0B 21:00 20-Feb-OS 21:30 2 3.00 6.25 4.00 10.00 24.41 0.25% 15.00% 3.86 591.72 175.78 20.69 815.74 993.19 20-Feb-08 21:30 20-Feb-08 22:00 4 3.00 0.00 3.00 4.00 6.20 0.25% 9.75% 0.60 592.32 29.02 5.58 821.32 267.86 20.Feb-08 22:00 20-Feb-08 22:30 2 4.00 10.00 6.00 8.00 36.67 0.00% 10.00% 3.67 595.99 176.03 33.01 854.33 1584.26 20-Feb-O8 22:30 20-Feb-08 23:00 4 3.00 4.00 4.00 10.50 28.68 0.50% 13.50% 3.87 598:86 185.83 24.66 878.99 1183.80 20-Feb-08 23:00 20-Feb-OS 23:30 2 6.00 8.00 8.00 0.25 27.28 0.50% 10.50% 2.86 602.73 137.48 24.28 903.27 1165.30 20-Feb-08 23:30 21-Feb-08 00:00 3 5.00 6.00 6.00 10.00 26.86 0.00% 15.00% 4.03. 606.75 193.38 22.83 925.10 1095.81 21-Feb-08 00:00 21-Feb-08 00:30 1 2.00 5.50 4.00 0.25 29.06 0.00% 10.00% 2.91' 609.66 139.51 26.'6 ~ 952.25 1255.61 21-Feb-OS 00:30 21-Feb-08 01:00 3 6.00 10.00 8.00 2.50 27.70 0.00% 9.00% 2.49 612.15 119.65 25.20 97?.46 1209.82 21-Feb-0B 01:00 21-Feb-08 01:30 1 4.00 0.25 5.00 8.25 32.06 0.00% 9.00% 2.89 615.04 138.51 29.18 '.706.64 '400.50 21-Feb-08 01:30 21-Feb-08 02:00 3 8.00 2.50 9.00 6.75 27.28 0.50% 19.50% 5.32 820.38 255.32 21.82 1028.46 1047.46 21-Feb-08 02:00 21-Feb-08 02:30 1 5.00 8.25 6.00 11.25 25.18 0.00% 13.00% 3.27 623.63 157.12 21.91 1050.36 1051.49 21-Feb-08 02:30 21-Feb-08 03:00 3 9.00 6.75 11.00 0.00 28.98 0.00% 11.00% 3.19 623.54 152.88 25.77 1076.13 1237.01 21-FBir08 03:00 21-Feb-08 03:30 1 6,00 11.25 8.00 3.00 26.44 0.00% 17.75% 4.69 628.32 225.25 21 J5 1097.88 1043.79 21-Feb-08 03:30 21-Feb-08 04:00 3 11.00 0.00 11.00 9.25 15.53 0.25% 7.00% 1.09 824.63 52.17 14.40 1112.28 691.27 21-Feb-08 04:00 21-Feb-08 04:30 1 8.00 3.00 9.00 4.75 23.08 0.00% 6.00% 1.38 826.02 66.47 21.70 1133.98 1041.42 21-Feb-08 04:30 21-Feb-08 05:00 3 11.00 9.25 12.00 .10:25 21.82 0.00% 5.00% 1.09 627.19 52.37 20.73 1154.71 995.09 21-Feb-OS 05:00 21-Feb-OS 05:30 1 9.00 4.75 10.00 7.75 25.18 0.00% 6.00% 1:51 628.62 72.52 23.67 1178.38 1136.09 21-Feb-08 05:30 21-Feb-OS 06:00 3 12.00 10.25 14.00 3.50 28.96 0.00% 24.00% 6.95 635.57 333.58 22.01 1200.38 1056.32 21-Feb-08 06:00 21-Feb-08 06:30 1 10.00 7.75 12.00 2.75 31.89 0.00% 12.00% 3.83 839.39 183.71 28.07 1228.45 1347.20 21-Feb-08 06:30 21-Feb-08 07:00 3 14.00 3.50 15.00 9.75 30.63 0.00% 8.00% 2.45 641.84 117.64 28.18 1256.64 1352.84 21-Feb-08 07:00 21-Feb-08 07:30 2 8.00 0.25 9.00 1.25 21.82 0.00% 8.00% 1:75 643.59 83:80 20.06 1276.71 863.66 21-Fe1N08 07:30 21-Feb-08 08:00 1 12.00 2.75 12.00 9.75 11.75 0.00% 4.00°l0 0.47 644.08 22.56 11.28 1287.99 541.46 i Customer: ConocoPhlllips Well: Rendezvous 2 Start Date: 19-Feb-08 End Date: Flow Period: Clean-up Flow Period PRODUCTION TANK DATA SHEET Total Fluid Production: 201.00 bbls Total OII Production: 0.00 bbls Total Water Production: 0.00 bbls Total Volume From Sand Tank: 201 bbls ~QI'1nCQ~'"II~NI~35 (Volume was taken from the vac truck 251. 15:00 21-Feb-t On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips, Alaska Inc, submits the attached data for the Rendezvous #2 Well pursuant to the conditions of Sundry approval, number 308-011. We request that this data be held confidential as required under AS 31. 05.035lc1 and 20 AAC 25 537(dl. ' Start End Tank Previous Strap Current Strap Fluid Inc. BSBrW H2O Inc. H2O Cum H2O Rate Oil tnc. Oil Cum Oil Rate Date & Time Date & Time No. feet in feet in bbl Solids Water bbl bbl bbUd bbl bbl bblld 21-Feb:08 08:00 21-Feb-08 08:30 2 9.00 1.25 10.00 2.25 21.82 0.00% 12.00% 2.62 646.68 125.70 19.20 1307.20 921.77 21-Feb-08 08:30 21-Feb-08 09:00 1 12.00 9.75 14.00 7.00 35.67 0.00% 10.00% 3.57 650.25 171:22 32.70 1339.30 1540.98 21-Feb-08 09:00 21-Feb-08 09:30 4 4,00 '. 10.50 6.00 5.75 32.12 0.00% 50.00% 16.06 666.31 .770.90 16.06 1355.36 770.90 21-Feb-0B 09:30 21-Feb-08 10:00 2 10.00 2.25 11.00 2.50 20.58 0.00% 3.50% 0.72 667.03 34.55 19.84 1375.20 952.49 21-Feb-OS 10:00 21-Feb-08 10:30 4 6.00 5.75 7.00 6.25 20.98 0.00% 3.50% 0.73 667.76 35.25 20.25 1395.45 971,92 21-Feb-08 10:30 21-Feb-08 11:00 2 11.00 2.50 13.00 0.00 36,09 0.00% 8.00% 2.89 670:65 138.59 33.20 1428.65 1593.75 21-Feb-OS 11:00 21-Feb-08 11:30 4 7.00 6.25 9.00 1.25 31.89 0.00% 12.00% 3.83 674.48 183.71 28.07 146672 1347.20 21-Feb-O8 11:30 21-Feb-08 12:00 3 0.00 6.25 1.00 1.25 10.85 0.00% 4.00% 0.43 674.91 20.83 10.42 1467.14 500.01 21-Feb-08 12:00 21-Feb-08 12:30 1 0.00 8.50 1.00 8.50 18.60 0.00% 30.00% 5.58 680.49 267.86 13.02 1480.16 625.01 21-Feb-08 12:30 21-Feb-08 13:00 3 1.00 1.25 2.00 8.00 29.06 0.00% 45.00% 13.08 693.57 627.$0 15.99 1496.14 767.3?. 21-Feb-08 13:00 21-Feb-08 13:30 1 1.00 8.50 3.00 1.50 26.35 0.00% 75.00% 19.76 713.33 948.68 6.58 1502.73 316.23 21-Feb-08 13:30 21-Feb-08 14:00 3 2.00 8.00 3.00 9.00 20.15 D.00% 10.00% 2.02 715.35 96.73 18.14 1520.87 870.55 21-Feb-08 14:00 21-Feb-08 14:30 1 3.00 1.50 4.00 2.50 20.15 0.00% 2.00% 0:40 715.75 19.35 19.75 1540.62 947.94 21-Feb-08 14:30 21-Feb-08 15:00 3 3.00 9.00 5.00 6.00 33.32 0.00% 1.00% 0.33 716.08 16.00 32.99 1573.81 1583.54 21-Feb-08 15:00 21-Feb-08 15:30 1 4.00 2.50 5.00 10.00 31.51 0.00% 2.50% 0.79 716.87 37.82 30.72 1604.33 1474.79 21-Feb-08 15:30 21-Feb-08 16:00 3 5.00 6.00 6.00 11.00 28..54 0.00% 2.50% 0.71 717.59 34.24 27.$2 1632.16 1335.51 21-Feb-08 16:00 21-Feb-OS 16:30 1 5.00 10.00 7.00 3.00 28.54 0.00% 5.00% 1.43 719.01 68.49 27.11 1858.27 1301.27 21-Feb-O8 16:30 21-Feb-08 17:00 3 6.00 11.00 8.00 4.50 29.38 0.00% 25.00% 7.34 726.36 352.51 22.03 1681.30 1057.53 21-Feb-08 17:00 21-Feb-08 17:30 1 7.00 3.00 8.00 6.25 25.60 0.00% 25.00% 6:40 732.76 307.19 19.20 1700.50 921.56 21-Fetr08 17:30 21-Feb-08 18:00 3 6.00 10.50 8.00 3.00 27.70 0.00% 55.00% 15.23 747.99 731.21 12.46 1712.96 598.26 21-Feb-OS 18:00 21-Feb-08 18:30 1 8.00 6.25 9.00 10.50 27.26 0.00% 7.00% 1.91. 749.90 91.65 25.37 1738.33 1217.67 21-Feb-OS 18:30 21-Feb-08 19:00 3 8.00 3.00 9.00 11.50 34.41 0.00% 5.00% 1.72 751.62. 82.58 32.69 1771.02 1568.18 21-Feb-08 19:00 21-Feb-08 19:30 1 9.00 10.50 11.00 1.00 24.34 0.00% 10.00% 2.43 754.05 116.83 21,91 1792.93 1051.49 21-Feb-08 19:30 21-Feb-08 20:00 3 9.00 11.50 11.00 2.00 24.34 0.00% 6.00% 1.46 755.51 70.10 22.88 1815.81 1098.22 21-Feb-O8 20:00 21-Feb-08 20:30 1 11.00 1.00 12.00 4.50 26.02 0.00% 5.00% 1.30 756.82 62.44 24.72 1840,52 1186.46 21-Feb-08 20:30 21-Feb-08 21:00 3 11.00 2.00 12.00 6.50 27.70 0.00% 12.00% 3.32 760.14 159.54 24.37 ?864.90 1169.93 21-Feb-OS 21:00 21-Feb-08 21:30 1 12.00 4.50 13.00 8.50 26.86 0.00% 10.00% 2.69 762.83 12$.92 24.17 1888.07 1160.27 21-Feb-08 21:30 21-Feb-08 22:00 3 12.00 6.50 13.00 11.00 27.70 0.00% 9.00% 2.49 765.32 119.65 25.20 1914.27 1209.82 21-Feb-08 22:00 21-Feb-08 22:30 1 13.00 8.50 15.00 1.50 28.54 0.00% 4.00% 1.14 766.46 54.79 27.40 1941.67 1314,97 21-Feb-08 22:30 21-Feb-08 23:00 3 13.00 11.00 15.00 4.00 28.54 0.00% 4.00% 1.14 767.60 54.79 27.40 1989.06 1314.87 21-Feb-08 23:00 21-Feb-08 23:30 2 0.00 3.00 1.00 8.00 26.35 0.00% 5.00% 1.32 76$:92 63.25 25.03 1994,10 1201,66 21-Feb-0B 23:30 22-Feb-08 00:00 4 1.00 4.50 2.00 10.00 27.13 0.00% 5.00% 1.36 770:27 65.11 25.77 X19.87 1237.01 22-Feb-08 00:00 22-Feb-08 00:30 2 1.00 8.00 3.00 2.00 27,90 0.00% 6.00% 1.67 771.85 80:36 26.23 2046.10 1258.96 22-Feb-O8 00:30 22-Feb-08 01:00 4 2.00 10.00 4.00 3.25 26.74 0.00% 5.00% 1:34 773.29'` 64.18 25.40 2071.50 1219.33 22-Feb-08 01:00 22-Feb-08 01:30 2 3.00 2.00 4.00 6.75 25.96 0.00% 7.00% 1.82 775.10 87.24 24.15 2095.65 1159,06 22-Fe1r08 01:30 22-Feb-08 02:00 4 4.00 3.25 5.00 7.50 26.15 0.00% 6.00% 1.57 776.67 75.32 24.52 2120,23 1190.04 22-Feb-08 02:00 22-Feb-OS 02:30 2 4.00 6.75 6.00 0.25 28.70 0.00°k 6.00% 1.72 778.39. 82.66 26.98 2147.21 1295.00 22-Feb-08 02:30 22-Feb-08 03:00 4 5.00 7.50 6.00 10.25 24.78 0.00% 6.00% 1.49 779:88 71.31 23.27 2170.49 1117,16 22-Feb-08 03:00 22-Feb-08 03:30 2 6.00 0.25 7.00 1.75 22.66 0.00% 2.00% 0.45 780.33. 21.75 22.21 2192.69 106599 - 22-Feb-O8 03:30 22-Feb-08 04:00 4 6.00 10.25 8.00 2.25 28.86 0.00% 9.00%' 2.42 782.75. ~ 16:03 24.44 2217,14 1173.16 • PRODUCTION TANK DATA SHEET Customer: ConocoPhllllps Well: Rendezvous 2 Start Date: 19-Feb-OS End Date: Flow Period: Clean-up Flow Period Total Fluid Production: 201.00 bbls Total Oil Production: 0.00 bbls Total Water Production: 0.00 bbls Total Volume From Sand Tank: 201 bbls ~~C4~"11~~1~5 (Volume was taken from the vac truck 251. 15:00 21-Feb-t On behalf of itself and Anadarko Petroleum Corporation, ConocoPhillips, Alaska Inc, submits the attached data for the Rendezvous #2 Well pursuant to the conditions of Sundry approval, number 308-011. We request that this data be held confidential as required under AS 31. Start End Tank Previous Strap Current Strap Fluid Inc. BSiiW H2O Inc. H2O Cum H2O Rate Oil Inc. OII Cum Oil Rate Date 8 Time Date & Time No. feet in feet in bbl Solids Water bbl bbl bblld bbl bbl bbUd 22-Feb-O8 04:00 22-Feb-08 04:30 2 7.00 1.75 8.00 4.75 25.18 0.00% 4.00% 1.01 783.76 48.34 24.17 2241.31 1160.27 22-Feb-08 04:30 22-Feb-08 05:00 4 8.00 2.25 9.00 7.25 28..54 0.00% 6.00% 1.71 785.47 82.19 26.A,2 2268.13 1287.57 22-Feb-OS 05:00 22-Feb-OS 05:30 2 8.00 4.75 9.00 10.25 29.3$ 0.00% 7.00% 2.06 787.53 98.70. 27.32 2295.45 1311.34 22-Feb-OS 05:30 00-Jan-00 Q0:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 Q0:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 OO:OC 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 00-Jan-00 00:00 • • • EXPFZQ SEQUENCE OF OPERATIONS CUSTOMF%: CwocoPhllips o. ~ Flow bl -Clem-up WELL : Rev4rnoas 3 RIGNAME DATE TIME OPERATIONS 9-Feb-08 06:00 S afety mce[ing 9-Feb-OB 09:00 Get with Handi bean and start consNraion oftank farm berm 9-Feb-O8 11:00 Get with ASTC loader apemlm to unload pipe trailer 9-Feb-OS 13:30 Unload sceorid trailer 9-Feb-OS 15:00 Lay oa plywood ro tiNr berm 9-Feb-08 18:00 Nigh[ ship arrived to spot 500 bbl tanks in berm 9-Feb-OB 23:00 Standing by as trucks deliver 500 bbls taN:s 10-Feb-OS 00:00 Continue to spa 500 bbls tanks 10-Feb-OS 05:30 Safety m«ting 10-Feb08 05:45 Day crew departs for Rendezvous _ 14Feb-08 0]:15 Day crew arrives Rendervous 10-Feb-OS 0]:30 Position Tioga heater onto flare stack 10-Feb-OS 08:30 ASRC ]oadtt operator arrives on bcation 10-Feb-O8 11:00 Positron first 400 bbl tank into tank farm 10-Feb-OB 11:30 Offload tmik circulation system t0-Feb-0B 12:00 Stage electrical box and gorse[ at base ofboom wiN heater trunks on Nem 10-Feb-OS 14:00 Position next 400 bbl tank into tank farm I O-Fcb-OS 15:00 Spa tmk diverter manifold into berm 10-Feb-OS 16:00 Position next 400 bbl tank into tmik Grm 10-Feb-OB 1]:30 ASRC WCk hooked onto FBU On CD4 10-Feb-08 18:00 Safety Meeting Position last 400 bbl tank info tank farm 10-Feb-OS 18:15 FBU depart CD4 for Rendezvous 10-Feb-OS 19:50 FBU artived alRrndrnous 10-Feb-OS 20:45 Spot FBU into positron 10-Feb-OB 21:00 ASRC WCk departed Rendezvous for Alpine 10-Feb-08 22:00 Position plywood inm relief and solids tankberm 10-Feb-OS 23:00 Layed out plywood around FBU 11-Feb-08 00:00 Coainue to wload rocks ofequipmen[ I I-Feb-OB 01:00 Standing by as rocks deliver equipment 1 l-Feb-OB 01:30 Night dsifl departs for Alpine 11-Feb-0B 06:00 Safety meeting 11-Feb-OS 0]:30 Day crew arrives ReMervous 11-Feb-O8 08:00 Start [o work on Flare t t-Feb-OS 10:00 Instill bola into flare legs and trgMor 11-Feb-OS I I:45 Install bonem section of Bare and lighten with ASRC crane 11-Feb-0B 13:00 Insmll tank stairs onto uprights 11-Feb-08 15:00 Install mid sectron of flare and tighten 11-Feb-OS 1]:00 installfwlsectron onto flare 11-Feb-OB 18:30 Spot heato into FBU berm 11-Feb-O8 I9:30 Ni [arrives Saf I l-Feb-OS 20:00 Spo[ vertical scrubber m FBU berm 11-Feb-OS 21:00 Unload and cut dunage I I-Feb-OB 23:00 Remove brass drain valves an 400 bbls ranks and instill stainless valves 12-Feb-08 00:00 Finished instilling Bare tip 72-Feb-OS 03:00 Instill3" 150 flanges on 400 bbls finks 12-Feb-OS 04:00 Spot heaters onto line heater and gas scrubber 12-Feb-OS 05:30 Softy m«ting 12-Feb-OB 05:45 Install flare igniter 12-Feb-0B 06:00 Lorate well head xover and heater xavers 12-Feb-OS 0]:00 Stirt m ran flow line from heater to FBU 12-Feb-OH 08:00 Lay out cfioke and arod busto bom 12-Feb-OB 09:00 Spot rig man for snarl busttt and chokemanifold i2-Feb-08 09:15 Remove lmse craddle and remove diverttt manifolds 12-Feb-OS 09:30 Spa sand buster onto rig man 12-Feb-OS 10:00 Start tc run relief line m relief ti~ 12-Feb-OB 10:30 Instill manifold valves on ram Farm l2-Feb-OB 12:00 Install info omo 500 bbls tanks 12-Feb-OS 13:00 Start m run gas to scrubber 12-Feb-OS 14:00 Unload choke manifold building 12-Feb-OS 15:00 5 [fuel for heater 12-Feb-OB 16:00 Spot choke manifold 12-Feb-08 I]:00 Finisfi rig up gas Ihse 12-Feb-OS 1]:45 Safety m«ting Ib-Feb-OS 01:00 Prepared for 3000 psi pressure test of Bowlines. 16-Feb-OB 03:30 Riggedti Hot Oiler forpressure test. 16-Feb-OS 04:25 Opened fo Tank #4. Sorted Flushing lines using the Ha Oiler Truck I6Feb-OS 04:30 Returns at Tank N4-shut down Hot Oiler Truck Pressured up to 3000 psi. Ib-Feb-OS 04:40 Stopped pumping. Leak naked. 16-Feb-OS 05:30 StartN pressuring up-leak fixed. 16-Feb-OB 05:50 Opened to tank k4 to Bush lines 16-Feb-OS 05:54 Pressured up to 1000 psi. 16-Feb-OS 05:59 Good pressure test Bleed pressure back m Hot Oiler. Ib-Feb-08 06:00 Held rooming safley m«ting. 16-Feb-OB 08:00 Pla«d plywood under Ne genemmrs. 16-Feb-08 08:30 Stirred heat exchanger bring. 16Feb-08 09:00 Changed camloc o-rings in [he fink f Ib-Feb-OS 10:15 Rigged m chemical pump m PowerChokes pump and tied into the choke manifold. 16-Feb-OH 11:45 Completed tieing m the bw gas flare line. 16-Feb08 13:00 Ran SSV tine to valve. 16-Feb-OS 14:00 Bu ed the transftt um amch«k rotation. 16-Feb-OS 14:15 Rigged ro spargmg line 6om Bowback unit m blow doom tank. Ib-Feb-08 14:50 Chained down the relief line. 16-Feb-OB 16:30 Hooked up check paint to Bowback unit with methanol. i6-Fe608 18:00 Completed shift fiarM over with day crew. 16-Peb-08 18:30 Compleed evening safley meeting. Ib-Feb-08 19:00 Started rurming heat trace on pipe. 16-Feb-OS 22:30 Instilled isolation vaWe on back pressure control box &liquid control box. I]-Feb-08 00:00 Finished installing heat trace on pipe. 1]-Feb-0B 02:30 Insmlled kam on flow line. 1]-Feb-08 03:00 Checked operation of all oil dump controllers and valves. 1]-Feb-OB 03:30 Worked Baron valves on separator, gas arM oil scmbbers. 1]-Feb-OB 03:45 Filled diesel taNC for heater. 1]-Feb-08 04:00 Blew out High gas line to drain a1 stick and preasme tested line from FBU to flarestick b 100 psi an pressure. • • EXPRO SEQUENCE OF OPERATIONS CUSTOMER: CwacoPbill~ps -Clewup g1G AME : Itm4avws Z DATE TIME OPERATIONS 17-Feb-OB 05:00 F ire tested indirect fire heater. 17-Feb-O8 05:45 Compleed ahifl hand over with day ttew. l7-Feb-08 09:00 P ulled adjustable choke to make sure we have spares. 17-Feb-OS 09:10 S tartedinsulation oflhe rest ofpipe. 17-Feb-08 10:00 P repared loads for back load to oNttjob and allied pipe. 17-Feb-OH 10:45 Finished tank farm changing of omloc malea. 17-Feb-OB 11:45 Fnished sortin r 17-Feb-08 12:30 Loaded carlik truck with pipe basket. 17-Feb-08 13:00 Cleaned all areas arM disposed of garbage in dumpsters. 17-Feb-08 13:15 Continued with insulation. 17-Feb-OS 14:00 Staged equipment for next bad ofback load 17-Feb-OB 14:30 I nstalled plug onto oil side Boat chamber on FBU. 17-Feb-OB 15:00 Loaded vp and gU second load of gear for carlile. l7-Peh08 16:00 Ran bavding wire. 17-Feb-08 16:45 Swapped gensets. 17-Feb-OS 17:00 Continued insulation. Mount saftey equipromt on FBU. 17-Feb-08 17:45 Shia hand over with night crew. 17-Feb-OH 16:30 Finished everting safety meeng. 17-Feb-OB 19:00 Strarting wrapping flow Imes invisquene. l7-Feb-O8 20:00 Fill sight glsses with orange sot. l7-Feb-OS 21:30 Blew down kelly hose on raN: tv make sure it was empty. 17-Feb-O8 22:00 Removed kelly hose from tank and replaced it wiN another. 17-Feb-08 23:00 Continued wrapping pipe with visquene. 18-Feb-OH 02:00 Finished wrapping and securing visqurne to pipe. 1 B-F<b-OB 03:00 Poroped me0mno] though sand line. l8-Feb08 05:30 Finished tiding up scan cables and poly Bow lines. 18-Feb-OS 06:00 Held mornin safl m 18-Feb-OS 07:00 Completed bonding in Ne tmik farm. IS-Feb-OS 08:00 Cleaned separator site glasses. 18-Feb-OS 14:00 ComP1U<d av test and fluid test on tardC farm hoses and pipework. 1 B-Feb-08 16:00 Placed 1.54incfi orifice plate in serive on the separator. l8-Feb-OB 16:30 Placed hydrocarbon signs and NPFA diamonds on all mN: f mNCS and fuel tanks. 18-Feb-08 17:00 Filled releef line with methanol. 18-Feb-08 17:15 Check Ranarex -all good IS-Feb-OH 16:00 Shtlt haMover wiN night crew. 1 B-Feb-OB 18:30 Evening softy meeting. l8-Feb-08 19:00 Continue preparing mrd f IB-Feb-OS 20:30 Aigged in ormolus sensor on well head. IS-Feb-OS 21:30 Bolted up flange on well head 18-Feb-OS 22:30 Started pumping methanol tlvvugh relief line. 19-Feb-OB 01:30 Finished pumping mehanol though relief line. 19-Feb-OB 02:00 Started rigging m Bow line to well head. 19-Feb08 04:30 Finished rigging inflow line. 19-Feb-OS 05:30 Finished rigging in WHP & W HT sensors. 19-Feb-08 06:00 Finished handover wiN rtigh[ crew and held safety meeting. 19-Feb-OB 06:15 Prepared m pressure test flow Ime from welt head to upstream of choke manifold. 19-Feb-OB 10:00 Found leak on flow line. Problem with a -not um m fluid Bterefore there was no r l9-Feb-08 10:20 Leakffixed-continuedm pump up flow line forpressmetes[. 19-Feb-OS 10:48 Oovd pressure [eat of the Bowline from wellhead m choke manifold. Prepare fo open Ne well fm cleao-up Bow. 19-Feb-OS 11:15 Held toolbox talk prior m opening Ne well. 19-Feb-OS 11:47 Lit gasflare ingi[tt-all good 19-Feb-OB 11:49 Opetred the wing valve on Ose we0head -pressure son at surfce. l9-Feb-08 11:51 Opened choke on a 24/64th adrysmble m TaNr #l. 19-Feb-OS 11:52 Schlumberger nitrogen pumper online at 350 cfiv. Irmer Armulus (IA) -400 psig 1?Feb-08 11:59 Increased choke to 32/64ths adjusmble. 19-Feb-OS 12:00 Divined from Tk #1 m Tk #3. BSffiW = 100°/a diesel 19-Feb08 12:20 Shut dawn gas flare ignittt-wait for gu at surface. 19-Feb08 12:30 Divined fmro Tk #3 m Tk #1. BS&W = 100% diesel 19-feb-OS 13:00 Diverted from Tk #1 m Tk #3. BSffiW = 100% diesel 19-Feb-OS 13:02 Smrted mehanol injection a[ Ne choke manifold 19-Feb-OS 13:03 Schmmbttgtt nitrogrn pampa remains online at 350 cfiv. Imitt Arroulus (IA) = 1000 psig 19-Feb-OB 13:30 Diverted from Tk #3mTk#1. BSffiW=I00%diesel l9-Feb08 13:36 IA sensor blacked in at the wellhead -doing work ov Ne wellltead. 19-Feb-OS 13:40 Schlmvberges nitrogen pumper increased mtem500 cfm. N=1100 psig 19-Feb-09 13:44 IA sensor oprned on Ose wellhead. 19-Feb-08 13:45 BS&.W = 100% diesel 19-Feb-OS 13:49 Ncreased choke fo 48/64ths ad~usmble. 19-Feb-OB 14:00 Divested from Tk#IbTk #3. BSffiW=100%diesel 19-Feb-OS 14:30 Diverted from Tk #3 m Tk #1. BSffiW = 100°o diesel 19-Feb-OS 15:00 Diverted from Tk #1 b Tk #3. BS&W = 100%diesel 19-Feb-OS 13:30 Diverted from T7: #3 m Tk #I. 8SffiW = 100% diesel 19-Feb-OB 15:44 Schlumberger nitrogen pumper with 1060 gallons of nitrogen pumped. 19-F<b-OB 16:00 Diverted from Tk #I to Tk #3. No Fluid gain. 19-Feh08 16:22 Filled meBmnol pump at choke manifold. 19-Feb-08 16:30 Diverted from Tk #3 m Tk #1. BSffiW = 100% diesel 19-Feb-OS 16:34 Pumped methanol into the bosom of ttte sand trap. 19-Feb-OS 16:39 Shut down mehanol injection into Ne bottom of Ne sand trap. l9-Feb-OB 17:00 Divested Tk #1 to Tk #3. BSffiW = 100% diesel 19-Feb-OB 17:30 Diverted Tk #3 to Tk #1. BHffiW = 100°/ diesel 19-Feb-0B 18:00 Diverted Tk #1 to Tk #3. BSffiW = 100% diesel 19-Feb-OS 18:25 Schlmvbtt increased N2 rate tv 750 scam. 19-Feb-08 18:30 Diverted from Tk #3mTk#l. BSffiW=1W%diesel 19-Feb-OB 19:00 Diverted from Tk #! to Tk # 3. BSffiW = 50°/ Brute 50%diesel. 19-Feb-OB 19:30 Diverted from Tk #3mTk#1. BS&W =20%brine, 80%Diesel. l9-Feb-0B 19:45 Triplex meMavol injection started 19-Feb-OS 19:50 Finish pumping methanol with triplex. 19-Feb-OS 20:00 Diverted From Tk #I m Tk #3. BSffiW = 12 % brine, 88%diesel. 19-Feb-OH 20:00 Schmmbttga @ min. rate, holding 3000 psi on W. 350 acf/m. l9-Feb08 20:21 Schlumberger stopped pumping N2. 19-Feb-OS 20:25 Shutting choke, manimr pressure. 19-Feb-08 20:27 SurGce mehanol injection @ choke shutdown. 19-Feb-08 20:28 Pumping methanol @ tree cap. 19-Feb-OS 20:43 Changed overlo pumping diesel @ tree wp. Page 2 EXPRO SEQUENCE OF OPERATIONS C 3TOME8 : CmmoPhillips ST No.: Flow pl -Clem~up wELL : Rmdmous 2 RIG NAME DATE TIME OPERATIONS 19-Feb-08 21:35 L ined up m g<[ Fluid m FBU for BS&W testing. 19-Feb-OB 23:20 P ressure up Bow line from choke to well head wiN hot oil. I9-Feb-08 23:50 F lushed 10 bbl of diesel from hot oilier m Tk#3 to prove good rommunication from wellhead to mNc f 19-Feb-OS 23:55 S topped pumping hot oil downbole. Tk#3=1 P, 11.25". 20-Feb-OS 01:10 Open m wellhead on a 26/64ths adjustable choke. 20-Feb-OS 01:2] Schlumberges N2 online @ 500 scf/m, 2600 psi. 20.Feb-OS 01:30 Diverted from 7k #1 tc 7k #3. 20-Feb-08 02:00 Diverted from Tk #3 to Tk #1. BS&W= I S%wattt, 85% diesel. 20-Feb-OB 02:00 Schlumberger N2 changed pump rate m 300 scf/m. 20.Feb-OB 02:30 Diverted from Tk #ImTk#3. BS&.W=0.5%water, 99.5%diesel. 20-Feb-OH 02:51 i ncreased choke to a 30/64ms adjusmble. 20-Feb-08 03:00 Diverted from Tk #3 m Tk #i. BS&.W= 45 water, 55 %diesel. Trace of sediment. 20-Feb-OS 03:15 Rocked choke. 20.Feb-OS 03:20 Sand detector ickin a sand. 20-Feb-OS 03'30 Diverted Fmm Tk #1 to Tk #3. BS&W =99.5% water, 0.6% sediment.. 20-Feb-OB 03:32 Decreased choke to a 26/64ms adjusmble. 20-Feb.08 03:48 Shm in well. 24Feb.08 03:5] WeB re-oprned at the choke manifrld. 20-Feb-OS 04:00 Diverted tram Tk#3 to ik #1. BSffiW=.S% wales, 99.5°o diesel N2 shuWOwn. 20-Feb-OB 04:30 Divested from Tk#I m Tk #3. BS&W= 20 water, 80% diesel. 20-Fe408 05:00 Diverted from Tk #3 to Tk 31. BSffiW= 96%water, 5 % diesel. 24Feb-OS 05:30 Diverted from Tk #1 to 7k #3. BSffiW = 74.5%wattt, 0.5% Sac sand, 25 %diesel 20-Feb-08 06:00 Diverted from Tk #3 to Tk #1. BS&W = 83% water, 10% fiat sand 5%diesel 20-Feb-OB 06:10 50 bbls m sand tank from the 19-Feb-08 to 06:00 on Bse 20-Feb-08. Added m tool volume back. 20-Feb-08 06:30 Diverted fiom Tk #1 to Tk #3. 20-Feb-OS 06:30 Sucked out mtM tank-toml of 30 bbls. 20-Feb-OH 07:00 Divested from Tk #3 to Tk #2. BS&W = 90% water, 10% sand 20-Feb08 0]:2] 1.5--inch plate om of service on the separator. Schlumbergtt nitrogen pumptt continues m pump a[ 325 scflm. 20-Feb-08 0]'30 Diverted Tk #2 to Tk#3. BSffiW=80%wates, 20%sand 20-Feb-08 0]:36 SarM trap-out of service-removed mline choke. 20-Feb-OB 0]:51 Commrnced transfer af7k #1 to Truck#116. 20.Feb-08 08:00 Diverted Tk #3 fo Tk p2. BS&W=58%water, 2%sand, 40%diesel 20-Feb-OS 08:15 Sand Trap in service-intine choke out. 20-Feb-OS 08:18 Dum sand from the sand tra to the sand tank. 20.Feb-OB 08:22 Sucked fluid from the sand tank to the vac truck Approx. 10 bbls. 20-Feb-O8 08:30 Diverted Tk #2 m Tk t14. HS&W = no fluid at sample point all gas. 20-Feb-OS 08:4] Blew down kelly lwse on rank m make sine it was empty. 20-Feb08 08:49 Finished blow down of sand trap. 20-Feb-0B 08:53 GasGmviry=0.848 20-Feb-08 08:55 Finished transfes of lk #1 to Track #116. 20-Feb-OB 08:59 Finished blow down of sand trap. 20-FebAB 09:00 Diverted Tk SF41o Tk #2. BS&W =11Npo water 20-Feb-08 09:00 Oil leg on the separator closed-diveMdthmugh the wattt leg. 20-Feb-OS 09:26 Commenced transftt afTk #3 to Track #115. 20-Feb-O8 09:30 Diverted Iic #2 to Tk #4. BS&W = 82% water, 6% sand 20-Feb-OS 09:40 Dumped the sand trap. 20-Feb-OS 10:00 Divested Tk#4toTk #2. BSffiW=90%wmtt, 8%diesel,2%sand 20-Feb-OB 10:16 SarM monitor om ofservice-movedm downstream of saM trap. 20.Feb-08 10:21 Sand mordtm in sttvice. 20-Feb-OS 10:30 Diverted Tk #2 tc Tk #4. BS&W = 10%wakr, 90%diesel, hate sand 20-Feb-OS 10:38 Gas Gmviry=0.773 20-Feb-08 10'48 l.6-inch orif a plate out of service on the separator. 20-Feb-OS 10:58 2 incb orifice plate in service on the separator. 20-Feb-OH 11:00 Diveted Tk #4 to Tk #2. BS&W=90%diesel, l0%wa 20-Feb-08 11:00 Divested Tk#4fo Tk #2. BSffiW=90°/diesel, l0%water 20-Feb-OS 11:04 Completed hansfer of Tk #3mTruck llb. 20-Feb-OS 11:2] Flushed m sand hap. 20-Feb-OS 11:30 Divined ik #21o Tk#I. BSffiW=60°o water, 40%diesel 20-Feb-OS 12:00 Divested Tk #1 m Tk #3. HSffiW = 40°/ water, 60% diesel 20.Feb-OS 12:30 Diverted Tk #3 to Tk pl. BS&W=40%wates, 60%diesel 20-Feb-OB 12:58 Increased chokem a20/64ths adjusmble. 20-Feb-OB 13:00 Diverted Tk #1 to Tk #3. 20.Feb-OS 13:01 Increased choke fo a 22/64ths adjustable. 20-Peb-OS 13:04 Increased chokem 24/64ths adjustable. 20-Feb08 13:09 Increased choke to 26/6401s adusmble. 20-Feb-OS 13:14 GasGmviry=0.861 20-Peb-OS 13:15 Ineseased choke fo 28/64ths adjusmble 20-Feb-OB 13:28 Increaze choke to 30/641hs adjusmble. 20-Feb-08 13:30 Diverted Tk #3 m Tk #1. 20.Feb-OS 13:34 Inceased chokem 32/64ths adjusmble. 20-Feb-OB 13:38 Commenced trensfes ofTk #4 to Truck#250. 20-Feb-OB 13:40 Increazed choke toa 34/64ths adjusmble. 20.Feb-OS 13:45 OiI API=41@BSE=39@60F 20-Feb-08 14:00 Divested Tk #1 to Tk#3. B5&W=25%wa[tt w/trace sediment 20-Feb-OB 14:12 Commenced hansEer Tk #2 m Truck #250. 20-Peb-08 14:30 Diverted Tk #3 to Tk kl. 20.Feb-OS 14:39 Completed transftt ofTk #2 m Track #250. 20-Feb-OS 11:51 Increased chokem 36/64ths adjusmble. 20-Feb-08 14:52 Continued to suck BUid from sand mNr Peak Truck 20.Feb-08 15:00 Diverted Tk #1 to Tk #3. BSffiW ° 40°/ water w/hate sediment 20-Feb-OS 15:27 Increazed choke tc 38/64ths adjusmble. 20-Feb-08 15:30 Diverted Tk #3 to Tk #1. 20.Feb-OS 15:39 Increased choke to a 40/64ths adjusmble. 20.Feb-OS 15:5] Increased choke m a 46/64ms adjustable. 20-Feb08 16:00 Diverted Tk#l to Tk #3. BS&W=17%water,0-25%emlosio0.l%corldensate 20-Feb-08 16:03 GasGmviry=0.861 20.Feb-OS 16:15 OiI API=42@92 F=?9.4@60F 20-F<b-OB 16:19 Increased separator pressmeto 160 prig. 20-Feb-0B 16:29 Hlew down sand hap. 20.Feb-OS 16:30 Diverted Tk #3 to Tk #1. 20-Feb-OB 16:31 Increased choke to 56/64ths adjusmble. 20-Feb-0B 16:43 Blew down sand hap. 20.Feb-OS 16:45 HSffiW =30%wata w/trace sediment Page 3 EXPRO SEQUENCE OF OPERATIONS «°Fnxups TESL No : F p WP.LL. &mdccv°as 2 v o DAl'E TIME OPERATIONS 20-Feb-OS 1]:00 Diverted Tk #1 to Tk#3. B8&W=40%wMtt w/trace sedwrnt 20-Feb-OS 1]:09 Decreased separator pmssure. 20-Feb-OS 1]:30 Diverted Tk #3 to Tk #1. 20-Feb-OH 18:00 Diverted Tk #1 to TkJ{3. BS&.W =41.5%watn, 0.25%sedimrnt 20-Feb-OB 18:30 Divested Tk #3 m Tk#I. BSffiW = 19.]5%wattt, 0.25% sediment Blew down sand trap. 20-Feb-O8 19'00 Diverted from Tk#1 w Tk #3. BSffiW= 20 water, 80% condensate. Trace sedirornt. Sand trep blow down. 20-Feb-08 19:30 Diverted lk #3 m 11: #l. BS&W = 22% warn, ]8%condensate. Blew down sand trap. 20-Feb-08 19:30 Changed orifice plate to 2.5". 20-Feb-OS 20:00 Dumped sand trap. 20-Feb-OB 20:00 Divested from Tk #l to Tk #2. BSffiW = 25% wafer, ]5 % condensate. 20-Feb-OS 20:10 Separator dump. 20-Feb-OS 20:20 Tk #2 Starting strap - 7 ft, 11" M. Tk q4 smrtMg strap - 1' E15" vr. 20-Feb-O8 20:30 Diverted from Tk #2 fo Tk #4. 20-Feb-08 20:30 Sand trap dump. 20-Feb-OS 20:35 Separator damp. 20-Feb-OB 20:38 Oil API 38.9 @ 85 F. 20-Feb-O8 20:45 Started Fluid transferfrom Tk #3wtruck. 20-Feb-08 21:00 DivMed from Tk #4 to Tk#2. BSffiW = 14% water, trace of sediment. 24Feb-OS 21:00 Sand map dump. 20-Feb-08 21:20 Gas GraviTy = 0.911. 20-Feb-OS 2127 Sand tra dum . 20-Feb-OB 21:30 DivMed Tk il2 to Tk # 4. BSffiW =15%, trace of sediment. 20-Feb08 21:36 Changed choke size to 52 /64ths M IDEA m corispond to actual choke size. 24Feb-OS 22:00 Diverted 11c 7btoTk#2. 85ffiW=9.]5%water, 0.25%sediment. 24Feb-OB 22:00 Sand bap droop. 24Feb-OS 22:15 Stmt fluid bansf from Tk#1 ro track. Start strop - 14'fr 11" m. 20-Feb-OH 22:30 Sand trap dmnp. 20-Feb-OB 22:30 DivMed TktF2 fo Tk p4. B8&W =10% wa1tt. 20-Feb-O8 22:43 Changed adjusable choke a 56/64Ns. 20-Feb-0B 22:50 Sand mcrease4 sand detecror alarms darted going off. 24Feb-OS 22:55 Changed adjustable choke back m 52/64Ns. 24Feb-OS 22:58 Sand trap dmvp. 20-Feb-OS 23:00 DivMed Tk #4 m Tk #2. 8SffiW = 13.5%water, 0.5 sed 20-Feb-O8 23:10 Stopped fluid transfer m buck from T1c #I. Tk #1 f 1 strap is 2'Q 5.5"M. Track #250. 20-Feb-0B 23:18 Separator dump. 20-Feb-OS 23:30 Diverted Tk #2 fo Tk #3. BSffiW = 10.5 watt, 0.5%sed. 24Feb-OS 23:37 Sandtrap dump. 21-Feb-OB 00:00 DivMed ftom Tk #3 to Tk #I. BS&W = I S% warn, trace sed. 21-Feb-OB 00:01 Sand trap dump. 2I-Feb-0B 00:30 Diverted Tk#t to Tk #3. BSffiW-IO%wattt. 21-Feb-OS 00:52 OA=50 si 21-Feb-OS 00:55 Sand trap dmnp. 21-Feb-OS 01:00 DivMed Tk #3 to Tk #1. BS&W = 9% warn. 21-Feb-OB 01:29 Sand trap dump. 21-Feb-0B 01:30 Divined from Tk #1mTk #3. BS&W=9%. 21-Feb-OS 01:36 Oprn adjustable choke to 54/661ha. 21-Feb-08 02:00 Diverted Tk #3 m Tk #1. BSffiW - 19.5%waltt, 0.5%sed 21-Feb-OS 02:01 Sand trep dump. 21-Feb-OB 02:05 Sepaamr dump. 21-Feb-OB 02:28 Band trap dump. 21-Feb-0B 02:30 Diverted Tk#l too#3. BS&W=l3%water. 21-Feb-OS 02:30 Oil API40 @ 95 F. 21-Feb-OH 02:32 Open choke to 56/640u adjustable. 21-Feb-OB 03:00 DivMed Tk #3 to Tk #I. BS&W=t!°o wattt. 21-Feb-08 03:01 Sand trap dump. 21-Feb-OS 03:1] Band trap dump. 2l-Feb-OS 03:29 Choke @ 48/64NS. 21-Feb-OS 03:30 DivMed Tk #1 to Tk #3. BS&W=1].]5% water. 21-Feb-OB 03:41 Choke@40/64tha 21-Feb-OB 03:52 Sand trap droop. 2l-Feb-08 06:00 Divined Tk #3 fo Ik #1.85&W-7% wMn. Trace of sed. 21-Feb-OS 04:30 Diverted ik#I to Tk #3. B8ffiW=6%wattt. 21-Feb-OS 04:30 Sand trap dmnp. 21-Feb-OB 05:00 DivMed Tk#3 to Tk #I. BSffiW=5°owater, trace sed. 21-Feb-08 05:01 Sand trap droop. 21-Feb-08 05:11 Separolordump. 21-Feb-OS 05:23 Choke open to 42/64the adj. 21-Feb-08 05:30 DivMed il:#1 m Tk #3. BSffiW= 6°o water, bate of sed. 21-Feb-OB 05:30 Sand trop dump. 21-Feb-08 06:00 Diverted from Tk #3 b Tk #1. BSffiW = 24% water 21-Feb-OS 06:30 Diverted from Tk #I to Tk#3. Gas Gravity=0-633 BSffiW=12%water '. 2l-Feb-OS 07:00 Diverted Tk #3 to Ik #2. 21-Feb-08 0]:00 Dumped the sand trap. 21-Feb-OS 0]:08 OiI API=42@84F=40@60F 21-Feb-08 07:15 85ffiW=8%wattt 21-Feb-OS 0]:30 DivMed Tk #2 to Tk #1. 2l-Feb-OS 07:63 Commenced transfer froru Tk #3 to Tk #5. 21-Feb-OS 07:45 Transferred fluid from sarM tank to back. 21-Feb-OS 08:00 DivMed 17: #1 to Tk #2. 85ffiW = 4 % water 21-Feb-OS 08:08 Decreased separator pressum. Pressure=40 prig 21-Feb-08 08:12 Decreased se are ure. Pressme=IS s 21-Feb-OS 08:15 Increased sepnMm pressure [0 45 Psig. WHP started to Mcrease. 21-Feb-OS 08:30 Diverted l7: #2mTk#I. BS&W=12%water 21-Feb-OS 09:00 DivMed Tk #1 to Tk #4. BS&W =10%water 21-Feb-OS 09:00 FMished transfn of "fk #3mTk#5. 21-Feb08 09:30 Diverted 17c 714 to Tk #3. B8ffiW = 50°/ warn 21-Feb-0B 09:31 Started tansfes of Tk #I mTk #6. 21-Feb-OS 10:00 DivMed lk #2 b lk i14. BSffi W = 3.5%wattt (used emulsion breaker) 21-Feb-OB 10:00 Decreased separator pressure ro 30 psig. 21-Feb-08 10:30 DivMed Tk N4 to Tk W2. 21-Feb-08 10:60 Dumped sand bap. 2l-Feb-OS 10:45 Completed transferred of Tk #1 to Tk #ti. 21-Feb-OS 10:47 Salted transf of Tk #S to Tk#7. ~ ! EXPAO SEQUENCE OF OPERATIONS g: cw~aennnp, o. Flw xl -Clem-np g®aa~ou: z IIIGNAME : DATH TIMB OPHRATIONB 2I-Feb-0B 11:00 D ivested Tk #2 to Tk #4. BSffiW = 8 % water 21-Peb-OS 11:00 O il AP1=41 @86 F=38.9 @60F 21-Feb-OS 11:04 C ompleted transfer Tk #5 [c Tk #]. 21-Feb-OB 11:2] Gas Gravity=0.80] 2l-Feb-O8 11:30 Divert Tk #4 to ik #3. BSffiW = 12 % water 21-Feb-OS 11:49 T ransferred Tk #2 to Tk #]. 21-Feb-OS 11:59 Divested Tk #3 [o Tk #4. BSffiW=4%wattt 21-Feb-OS 12:30 Divested Tk#1 to Tk#3. BSffiW=30%wattt 2l-Feb-OB 12:48 Transferred Tk #5 tc Tuck 116. 21-Feb-OB 13:00 Divered Tk #3 to Tk#1. BS&W=45%wamr 21-Feb-08 13:28 Finished transfer of Tk #5 to Tuck 116. 21-Feb-OS 13:30 Divined Tk#1 to Tk #3. B5&W=75%wates 21-Feb-OB 14:00 Diverted Tk #3mTk#1. BSffiW=10°/water 21-Feb-O8 14:32 Finished transfer of Tk il6 to Truck 251. 21-Feb-0B 14:3] Started transfer of Tk #]to Tuck 251. 21-Feb-OS 14:43 Finished transfer of Tk #] to Truck 251. 21-Feb-OH 15:00 Divined Tk #3 to Ik #1. BSffiW = 1°o water 21-Feb-OB 15:00 OiI API=40@80f=38.4@60F 21-Feb-OB IS:IB TrensferreATk #6 to Tuck 115. 21-Feb-08 15:30 Divested Tk #1 m Tk #3. BSffiW = 2.5 % water w/trace sediment 21-Feb-OS 15:44 Dumped sand trap. 21-Feb-OS 16:00 Diverted Tk #3 to Tk#1. Compleced transfes of l1c #61o Tmck 115 2l-Feb08 16:30 Diverted Tk #I to 1]s #3. B8&W = 5 % water 21-Feb-08 17:00 Diverted Tk #3 to Tk#I. BS&W=25%wa[tt 21-Feb-OS 1]:09 Transf ed Tk #3 to Tk #]. 21-Feb-08 1]:1] Blew down sepaator sparge Ime. 21-Feb-OB 17:21 Completed transf fiom Tk #3 to Tk #]. 21-Feb-OS 17J0 Diverted Tk #1 to 13c #3. 21-Peb-OS 1]:30 Started transfes of Tk #] to Truck 250. 21-Feb-OS 18:00 Divested Tk #3 to Tk #1. BS&W = 55 % water. 21-Feb-OS 18:0] Clanged choke to 44/64tbs adj. 21-Feb-OB 18:30 Diverted Tk #t to Tk #3. BSffiW=]%wattt. 21-Feb-0B 18:45 Changed choke to 46/64ths adj. 21-Feb-OS 18'57 Finish transftt from Tltlt7 to truck 250. Tk#]=0'fl, 7"m. 21-Feb-OS 19:00 OiI API: 38.5@84 Gas S.G.=0.860 BS&W=5%water. 21-Feb-OB 19:00 Divested Tk #3m"fk#I. 2l-Feb-O8 19:08 OA=10 psi. 21-Feb-OS 19:29 Increased choke to 48/64ths adj. 21-Feb-08 19:30 Divested Tk #1 to Tk #3. BS&W - 10%wattt. 21-Feb-OB 19:50 Salted Tank transfer from Tkp4 [o Tk#5. 21-Feb-08 19:58 Sand trap dmvp. 21-FebAB 19:59 Snipped fluid transfer between Tk #4 W 11c #5. 21-Feb-08 20:00 Diverted Tk #3 to Tk #1. BS&W = 6% water. 21-Feb-OB 20:02 Barred fluid transfer from Tk 7W to Tk #6. 2l-Feb-08 20:30 Diverted Tk #I to Tk #3. HS&W - 5%. 21-febAB 21:00 Diverted Tk #3 to T1c#i. BS&W-12%wates. 21-Feb-OS 21:30 Divested Tk #1 m Tk #3. BS&W -10% water. 21-Feb-OB 21:30 Increased choke to 50/64ths. 21-Feb08 22:00 Diverted Tk#3m Tk#I. BS&W-9%water. 21-FebAB 22:30 Diverted Tk #1 to Tk#3. BSffiW-4%water. 21-Feb-OS 22:46 Started transfering Tk #I to Tk #5. 21-Feb-OS 22:53 Sand trap droop. 21-Feb-OB 23:00 Divested Tk #3 to Tk #2. BSffiW - 4 % water. 21-Feb-OS 23:02 Started transfering fluid from Tk #I to Tk #6. 21-Feb-OS 23:30 Divested Tk #2 m Tk all. BS&W - 5 % water. 22-Feb-OS 00:00 Diverted Tk #4o Tk#2. 22-Feb-OS 00:30 Gas S.G=0.853 22-Feb-08 00:30 Divined Tk #2 to Tk fi4. BSffiW - 6% wMer. 22-Feb-OS 01:00 DivatW Tk #4 to Tkp2. BSffiW-5%wa~es. 22-Feb-OH 01:26 increased choke m 60/64Ms adj. 22-Feb-OB OI:30 Diverted Tk #2 to Tk #4. BS&W-7%water. 22-Feb-OB 01:30 Oil API: 39.5 @ 88 F. 22-Feb-OS 01:51 Separator dump. 22-Feb-OS 02:00 DivMW Tk #4 to Tk #2. BS&W - 6% water. 22-Feb-OB 02:15 Started pumping from Tk #6 to truck 116. 22-Feb-OB 02:26 Sandbap dmnp. 22-Feb-08 02:30 Divested Tk #2 W Tk # 4. BS&.W = 5%. 22-Feb-OS 03:00 Diverted Tk 7k tc Tk #2. BS&W- 5% water. 22-Feb-06 03:00 Increased choke to ]0/64ths adj. 22-Feb-OB 03:09 Decr®sed choke to 60/64ths. 22-Feb-OS 03:15 Decreased choke to 50/64fis. 22-Feb-OS 03:25 Finish pumping Tk #6mwck 116. 22-Feb-OH 03:30 Diverted 11c #2 m Tk # 4. BSffiW-2 % wattt. 22-Feb-OB 03:32 Transfer fluid Eom Tk #3 to lk 5. 22-Feb-0B 03:58 Sand trap dump. 22-Feb-OS 04:00 Divested lac #4 to Tk #2. B5ffiW-9%wates. 22-Feb-OS 04:00 Increased choke to 42/64ths adj. 22-Feb08 04:10 Swt fluid transfer from 13:716 to Tmck I IS 22-Feb-08 04:12 Decreased choke b 40/641hs adj. 22-Feb-OS 04:30 Divested Tk #2 [c Tk #4.BS&W-4%water. 22-Feb-OS 05:00 Divested 11r #4 to 7k #2. BSBeW- 6 % water. 22-Feb-OB 05:16 StarlM fluid transferfrom lk q3 to Truck. 22-Feb-08 05:30 Diverted Tk #2 to 17: 7N. BSffiW-]%wates. 22-Feb-OS 05:3] Sand trop dump. 22-Feb-OS 05:43 Sepammr dump. 22-Feb-OB 05:45 Fluid vansfer from Tk 3 b truck 250. 22-Peb-08 06:00 Divested 3kg4 to Tk#2. 22-Feb-OS 06:00 Shmin weH. Papa E acs ` - oc~~ CUSTOMER : ConocoPhillips PERFORATION INTERVAL :0000.0 - 0000.0 m mar,/ "~p~" ,,,,,, WELL TEST DATA SHEET WELL NAME : Rendezvous 2 TEST No. :Flow #1 - Clean-up J~~/~ ~~"/~''/~~~ • +t~ ~ ~ ~' u "` ~~~ , n~u+ DATE : 19-Feb-08 12:00 to 22-Feb-08 05:3G CUSTOMER REP.: Jack Kralick y~/~ n/ ~I~ 1 1 ,a8 ~, 1 ' r - BASE: AnChOfa98, Alaska RIG : EXPRO SUPERVISOR : Denis Henrion DATE 8 DOWNHOLE CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME BHP BHT SIZE BSBW WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BSBW GAS OIL WATER OIL GAS REMARKS (dd-mmm hh:mm) (psia) (°F) (64ths) (%) (psig) (°F) (psig) (MMacfd) (stb/d) (slb/d) (scf/stb) (psig) (°F) (%) (MMscf) (stb) (stb) (API@60°f) (Air=1) Diverted from Tk #1 to Tk #3. BSBW = 19-Feb 12:00 24 28 38 526 3658 2 35 100% diesel Diverted from Tk #3 to Tk #1. BS&W = 19-Feb 12:30 32 52 786 967 1 36 20 100% diesel Diverted from Tk #1 to Tk #3. BS&W = 19-Feb 13:00 32 43 961 149 1 36 23 100% diesel Diverted from Tk #3 to Tk #1. BS&W = 19-Feb 13:30 32 37 1114 74 2 36 25 100% diesel 19-Feb 14:00 48 38 1290 19 2 35 25 Diverted from Tk #3 to Tk #1. BSBW = 19-Feb 14:30 48 38 1485 37 2 34 26 100% diesel Diverted from Tk #1 to Tk #3. BS&W = 19-Feb 15:00 48 38 1636 223 1 34 31 100% diesel Diverted from Tk #3 to Tk #1. BS&W = 19-Feb 15:30 48 37 1766 74 1 34 32 100% diesel Diverted from Tk #1 to Tk #3. No fluid 19-Feb 16:00 48 33 1881 ain. Diverted from Tk #3 to Tk #1. BS&W = 19-Feb 16:30 48 38 2004 56 2 34 33 100% diesel Diverted Tk #1 to Tk #3. BS&W = 100% 19-Feb 17:00 48 36 2114 19 1 34 34 diesel Diverted Tk #3 to Tk #1. BS&W = 100% 19-Feb 17:30 48 30 2220 19 2 34 34 diesel Diverted Tk #1 to Tk #3. BS&W = 100% 19-Feb 18:00 48 19 2310 diesel Diverted from Tk #3 to Tk #1. BS&W = 19-Feb 18:30 48 8 2402 19 1 35 34 100% diesel Diverted from Tk #1 to Tk # 3. BS&W = 19-Feb 19:00 48 0 3 2557 19 1 35 35 50% Brine 50% diesel. Diverted from Tk #3 to Tk #1. BS&W = 19-Feb 19:30 48 0 2710 20% brine 80% Diesel. Schlumberger @ min. rate, holding 3000 19-Feb 20:00 48 2 2929 si on IA. 350 scf/m. 19-Feb 20:30 48 2817 19-Feb 21:00 48 2676 19-Feb 21:30 48 2 2650 19-Feb 22:00 48 15 0 2626 19-Feb 22:30 48 2 2626 CONFIDENTIAL INFORMATION CONOCOPHILLIPS REQUESTS THE INFORMATION BELOW AND ATTACHED BE KEPT CONFIDENTIAL AS REQUIRED UNDER AS 31. 05.035(c) and 20 AAC 25.537(d). • Page 1 of 7 n^ - ~ WELL TEST DATA SHEET CUSTOMER : ConocoPhillips WELL NAME : Rendezvous 2 DATE : 19-Feb-0B 12:00 to 22-Feb-0B 05:30 PERFORATION INTERVAL :0000.0 - 0000.0 m TEST No. :Flow #1 -Clean-up ~~""'~~ ~~[~•i •~ CUSTOMER REP.: Jack Kralick Wt10~'tl~~i BASE: Anchorage, Aleske RIG : EXPRO SUPERVISOR : Denis Henrion DATE 8 DOWNHOLE CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME BHP BHT SIZE BSBW WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BS&W GAS OIL WATER OIL GAS REMARKS (dd-mmmhh:mm) (psia) (°F) (64ths) (%) (psig) (°F) (psig) (MMSCfd) (stb/d) (stb/d) (scf/stb) (psig) (°F) (%) (MMSCf) (sib) (sib) (API@60°f) (Air=1) 19-Feb 23:00 48 13 2617 19-Feb 23:30 48 16 2751 20-Feb 00:00 48 46 2711 20-Feb 00:30 48 8 69 2664 20-Feb 01:00 48 115 79 2639 Diverted from Tk #1 to Tk #3. 20-Feb 01:30 48 13 48 2579 3767 1 38 113 Schlumberger N2 changed pump rate to 20-Feb 02:00 48 152 52 2711 1153 1 40 137 300 scf/m. Diverted from Tk #1 to Tk#3. BS&W= 20-Feb 02:30 48 0.5 239 58 2784 56 56 1 40 139 1.2 0.5% water 99.5% diesel. Diverted from Tk #3 to Tk #1. BS&W= 45 20-Feb 03:00 48 0.5 293 45 2652 31 25 1 41 139 1.7 water 55% diesel. Trace of sediment. Diverted From Tk #1 to Tk #3. BSBW = 20-Feb 03:30 48 1.0 383 53 2809 861 19.6 99.5% water 0.5% sediment.. Diverted from Tk#3 to Tk #1. BS&W= .5% 20-Feb 04:00 48 0.0 846 63 2686 2660 13 76 87 195 19.9 water 99.5% diesel. N2 shutdown. Diverted from Tk#1 to Tk #3. BS&W= 20 20-Feb 04:30 48 0.2 574 95 2297 2643 661 223 105 250 33.7 water 80% diesel. Diverted from Tk #3 to Tk 31. BSBW= 20-Feb 05:00 48 1.0 363 94 2130 126 2392 218 111 252 83.5 95%water 5% diesel. Diverted from Tk #1 to Tk #3. BS&W = 20-Feb 05:30 48 0.8 227 83 2169 332 990 209 106 259 104.1 74.5% water 0.5%frac sand 25% diesel Diverted from Tk #3 to Tk #1. BS&W = 20-Feb 06:00 18 1.0 207 80 2230 6 103 175 109 259 106.3 85% water 10%frac sand 5% diesel Sucked ouY sand tank -total of 30 bbls. 20-Feb 06:30 18 1.0 235 88 2211 60 1027 126 112 261 127,7 Diverted from Tk #3 to Tk #2. BS&W = 20-Feb 07:00 18 1.0 310 93 2179 1759 164.3 90% water 10% sand Diverted Tk #2 to Tk #3. BS&W = 80% 20-Feb 07:30 18 1.0 577 105 2017 2396 214.2 water 20% sand Diverted Tk #3 to Tk #2. BS&W = 58% 20-Feb 08:00 18 0.4 464 103 1835 1390 959 206 132. 290 234.2 water 2% sand 40% diesel Diverted Tk #2 to Tk #4. 138AW-= r~ . 20-Feb 08:30 18 0.4 412 110 1702 2428 1674 205 138 340 269.1 '8, a~ Oil leg on the separator closed -diverted 20-Feb 09:00 18 1.0 254 100 1655 1.12 1432 202 135 0.02 298.9 0.848 throu h the water le . Diverted Tk #2 to Tk #4. BS&W = 82% 20-Feb 09:30 18 0.9 231 91 1729 0.74 135 1104 5500 193 135 0.04 343 321.9 0.848 water 8% sand CONFIDENTIAL INFORMATION CONOCOPHILLIPS REQUESTS THE INFORMATION BELOW AND ATTACHED BE KEPT CONFIDENTIAL AS REQUIRED UNDER AS 31. 05.035(c) and 20 AAC 25.537(d). • • Page 2 of 7 CUSTOMER : ConocoPhillips PERFORATION INTERVAL :0000.0 - 0000.0 m ,~ WELL TEST DATA SHEET WELL NAME : Rendezvous 2 TEST No. :Flow #i -Clean-up /wr _ ~~~~I~~ ( / ~ DATE : 19-Feb-08 12:00 to 22-Feb-08 05:30 CUSTOMER REP.: Jack Kralick ~ \, / BASE: AnChOrage, Alaska RIG : EXPRO SUPERVISOR :Denis Henrion DATE & DOWNHOLE CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME BHP BHT SIZE BS&W WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BS&W GAS OIL WATER OIL GAS REMARKS (dd-mmm hh:mm) (psia) (°F) (64ths) (%) (psig) (°F) (psig) (MMSCfd) (stb/d) (stb/d) (scf/stb) (psig) (°F) (%) (MMSCf) (stb) (stb) (API@60°f) (Air=1) Diverted Tk #4 to Tk #2. BSBW = 90% 20-Feb 10:00 18 0.9 282 93 1788 0.60 88 988 6865 192 137 0.05 345 342.5 0.848 water 8% diesel 2% sand Diverted Tk #2 to Tk #4. BS&W = 10% 20-Feb 10:30 18 0.1 369 99 1780 0.80 1378 153 584 195 130 0.07 373 345.7 0.848 water 90% diesel trace sand Diverted Tk #4 to Tk #2. BS&W = 90% 20-Feb 11:00 18 0.1 530 102 1616 2.54 2049 228 1239 220 139 0.12 416 350.4 0.773 diesel 10% water Diverted Tk #2 to Tk #1. BS&W = 60% 20-Feb 11:30 18 0.6 390 100 1476 2.17 612 919 3537 242 145 0.17 429 369.6 0.773 water 40% diesel Diverted Tk #1 to Tk #3. BSBW = 40% 20-Feb 12:00 18 0.4 322 97 1469 1.41 670 446 2102 238 138 0.20 443 378.9 0.773 water 60% diesel Diverted Tk #3 to Tk #1. BSBW = 40% 20-Feb 12:30 18 0.4 259 95 1534 1.06 748 499 1424 188 135 0.22 458 389.3 0.773 water 60% diesel 20-Feb 13:00 20 0.9 371 99 1522 1.19 190 1708 6264 169 141 0.24 462 424.8 0.773 Diverted Tk #1 to Tk #3. 20-Feb 13:30 30 0.9 376 100 1419 1.79 182 1636 9839 172 147 0.28 466 458.9 =8~{ 4 0.861 Diverted Tk #3 to Tk #1. Diverted Tk #1 to Tk #3. BS&W = 25% 20-Feb 14:00 32 0.3 345 99 1344 1.77 1258 419 1409 170 139 0.32 492 467.7 39.0 0.861 water w/trace sediment Diverted Tk #3 to Tk #1. 20-Feb 14:30 34 0.3 312 98 1303 1.61 1194 398 1352 171 139 0.35 517 475.9 39.0 0.861 Diverted Tk #1 to Tk #3. BS&W = 40% 20-Feb 15:00 36 0.4 258 96 1324 1.37 810 540 1686 151 145 0.38 534 487.2 39.0 0.861 water w/trace sediment Diverted Tk #3 to Tk #1. 20-Feb 15:30 38 0.6 257 95 1352 1.23 556 834 2207 115 138 0.40 546 504.6 39.0 0.861 Diverted Tk #1 to Tk #3. BS&W = 17% 20-Feb 16:00 40 0.2 312 98 1324 1.49 1120 229 1330 117 140 0.44 569 509.3 39.0 0.861 water 0.25% emlusion 1 20-Feb 16:30 56 0.3 346 100 1230 2.00 1340 574 1493 139 144 0.48 597 521.3 39.4 0.861 Diverted Tk #3 to Tk #1. Diverted Tk #1 to Tk #3. BS&W = 40% 20-Feb 17:00 56 0.4 305 100 1142 2.08 858 572 2421 158 138 0.52 615 533.2 39.4 0.861 water w/trace sediment Diverted Tk #3 to Tk #1. 20-Feb 17:30 56 0.1 179 96 1119 1.79 1081 147 1651 110 140 0.56 637 536.3 39.4 0.861 Diverted Tk #1 to Tk#3. BS&W = 47.5% 20-Feb 18:00 56 0.5 171 94 1150 1.41 663 603 2126 86 148 0.59 651 548.8 39.4 0.861 water 0.25% sediment. Diverted Tk #3 to Tk#1. BSBW = 19.75% 20-Feb 18:30 56 0.2 139 93 1197 1.30 1047 259 1238 72 135 0.61 673 554.2 39.4 0.861 water, 0.25% sediment. Blew down sand Diverted from Tk#1 to Tk #3. BS&W= 20 20-Feb 19:00 56 0.2 222 97 1193 1.54 1209 302 1274 68 136 0.65 698 560.5 39.4 0.861 water Bf~iE_ , . TraDe 20-Feb 19:30 56 0.2 252 99 1077 1.99 1445 408 1373 76 138 0.69 728 569.0 39.4 0.861 Changed orifice plate to 2.5". Diverted from Tk #1 to Tk #2. BSBW = 20-Feb 20:00 56 0.3 239 99 989 2.20 1073 358 2052 74 143 0.73 751 576.5 39.4 0.861 25% water 746 Sand trap dump. 20-Feb 20:30 56 0.3 247 102 954 1.96 1074 358 1822 72 129 0.77 773 583.9 39.4 0.861 CONFIDENTIAL INFORMATION CONOCOPHILLIPS REQUESTS THE INFORMATION BELOW AND ATTACHED BE KEPT CONFIDENTIAL AS REQUIRED UNDER AS 31. 05.035(c) and 20 AAC 25.537(d). • C~ J Page 3 of 7 CUSTOMER : ConocoPhillips PERFORATION INTERVAL :0000.0 - 0000.0 m WELL TEST DATA SHEET WELL NAME : Rendezvous 2 TEST No.: Flow #1 -Clean-up . „_ ~ `~,p~~ tt /`~ =3:~,~t!~'~Y.~. ~;,'~~i _ DATE : 19-Feb-0B 12:00 to 22-Feb-0B 05:30 CUSTOMER REP.: Jack Kralick ~~~~I~1~~ BASE: AnChOr8Qi3, A188ke RIG : EXPRO SUPERVISOR :Denis Henrion DATE & DOWNHOLE CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME BHP BHT SIZE BSBW WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BSBW GAS OIL WATER OIL GAS REMARKS (dd-mmm hh:mm) (psis) (°F) (64ths) (%) (psig) (°F) (psig) (MMscfd) (slb/d) (stb/d) (scf/stb) (psig) (°F) (%) (MMSCf) (stb) (stb) (API~60°f) (Air=1) 20-Feb 21:00 56 0.1 108 96 948 1.77 1216 198 1460 71 134 0.81 798 588.1 37.0 0.861 Sand trap dump. Diverted Tk #2 to Tk # 4. BS&W = 15%, 20-Feb 21:30 56 0.2 268 100 929 1.79 993 176 1807 63 140 0.85 819 591.7 37.0 0.911 trace of sediment. Sand trap dump. 20-Feb 22:00 52 0.1 231 100 928 1.80 268 29 6707 63 132 0.89 825 592.3 37.0 0.911 Diverted Tk#2 to Tk #4. BS&W = 10% 20-Feb 22:30 52 0.1 191 98 920 1.81 1584 176 1143 63 133 0.92 858 596.0 37.0 0.911 water. Diverted Tk #4 to Tk #2. BS&W = 13.5% 20-Feb 23:00 52 0.1 251 100 930 1.73 1184 186 1458 62 138 0.96 882 599.9 37.0 0.911 water 0.5 sed. Diverted Tk #2 to Tk #3. BS&W = 10.5 20-Feb 23:30 52 0.1 254 99 912 1.86 1165 137 1593 63 131 1.00 907 602.7 37.0 0.911 water 0.5% sed. Diverted from Tk #3 to Tk #1. BS&W = 21-Feb 00:00 52 0.2 193 97 894 1.83 1096 193 1670 62 133 1.04 929 606.8 37.0 0.911 15% water trace sed. Diverted Tk #1 to Tk #3. BS&W - 10% 21-Feb 00:30 52 0.1 206 96 888 1.84 1256 140 1468 62 141 1.07 956 609.7 37.0 0.911 water. Diverted Tk #3 to Tk #1. BSBW = 9% 21-Feb 01:00 52 0.1 232 96 891 1.77 1210 120 1462 61 139 1.11 981 612.2 37.0 0.911 water. Diverted From Tk #1 to Tk #3. BS8~W=9%. 21-Feb 01:30 52 0.1 130 93 887 1.82 1400 139 1296 62 132 1.15 1010 615.0 37.0 0.911 Diverted Tk #3 to Tk #1. BS&W - 19.5% 21-Feb 02:00 54 0.2 154 95 891 1.77 1047 255 1688 62 138 1.19 1032 620.4 37.0 0.911 water, 0.5% sed. ~' ~ ~ ~ F' 21-Feb 02:30 54 0.1 139 95 884 1:91 1051 157 1813 63 138 1.23 1054 623.6 37.0 0.911 Diverted Tk #3 to Tk #1. BS&W = 11 21-Feb 03:00 56 0.1 191 95 892 1.77 1237 153 1433 61 133 1.26 1079 626.8 37.3 0.911 water. Diverted Tk #1 to Tk #3. BS&W= 17.75% 21-Feb 03:30 48 0.2 188 96 813 1.69 1044 225 1620 59 139 1.30 1101 -631.5 37.3 0.911 water. Diverted Tk #3 to Tk #1. BS&W-7% water. 21-Feb 04:00 40 0.1 95 89 856 1.12 691 52 1619 34 134 1.32 1116 632.6 37.3 0.911 Trace of sed. 21-Feb 04:30 40 0.1 91 89 889 1.12 1041 66 1076 30 130 1.34 1137 634.0 37.3 0.911 Sand trap dump. Diverted Tk#3 to Tk #1. BS&W= 5%water, 21-Feb 05:00 40 0.1 177 91 906 1.06 995 52 1068 50 142 1.37 1158 635.1 37.3 0.911 trace sed. Sand trap dump. 21-Feb 05:30 42 0.1 145 94 908 1.25 1136 73 1101 52 127 1.39 1182 636.6 37.3 0.911 Diverted from Tk #3 to Tk #1. BS&W = 21-Feb 06:00 42 0.2 229 97 900 1.18 1056 334 1116 71 135 1.42 1204 643.5 37.3 0.911 24% water Diverted from Tk #1 to Tk #3. 21-Feb 06:30 42 0.1 192 96 894 1.30 1347 184 969 73 144 1.44 1232 647.4 37.3 0.911 U 3~S&W = 12% water 21-Feb 07:00 42 0.1 176 96 881 1.36 1353 118 1007 74 133 1.47 1260 649.8 37.3 0.833 Dumped the sand trap. Diverted Tk #2 to Tk #1. 21-Feb 07:30 42 0.1 105 89 863 1.41 964 84 1468 74 143 1.50 1280 651.6 40.0 0.833 CONFIDENTIAL INFORMATION CONOCOPHILLIPS REQUESTS THE INFORMATION BELOW AND ATTACHED BE KEPT CONFIDENTIAL AS REQUIRED UNDER AS 31. 05.035(c) and 20 AAC 25.537(d). Page 4 of 7 WELL TEST DATA SHEET CUSTOMER : ConocoPhillips WELL NAME : Rendezvous 2 PERFORATION INTERVAL :0000.0 - 0000.0 m ~#,/ TEST No. :Flow #9 -Clean-up /-~ t ~ ~'II~~~ DATE : 19-Feb-0B 12:00 to 22-Feb-08 05:30 CUSTOMER REP.: Jack Kralick WI lV IsnsE: Anchorage, A188ke RIG : EXPRO SUPERVISOR :Denis Henrion DATE & DOWNHOLE CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME BHP BHT SIZE BSB,W WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BSSW GAS OIL WATER OIL GAS REMARKS (dd-mmm hh:mm) (psia) (°F) (64ths) (%) (psig) (°F) (psig) (MMSdd) (stb/d) (stb/d) (scf/stb) (psig) (°F) (%) (MMSCf) (stb) (stb) (APIQ60°f) (Air=1) Diverted Tk #1 to Tk #2. BS&W = 4% 21-Feb 08:00 42 0.0 91 82 925 0.75 541 23 1385 68 147 1.52 1291 652.0 40.0 0.833 water ' Diverted Tk #2 to Tk #1. BS&W = 12% 21-Feb 08:30 42 0.1 150 87 975 0.98 922 126 1068 52 133 1.54 1310 654.6 40.0 0.833 water Finished transfer of Tk #3 to Tk #5. 21-Feb 09:00 42 0.1 205 97 952 1.46 1541 " 171 946 52 137 1.57 1343 658.2 40.0 0.833 Diverted Tk ;# to Tk #3. BSSW = 50% 21-Feb 09:30 42 0.5 170 95 922 1.55 771 771 2009 54 143 1.60 1359 674.3 40.0 0.833 water ~ ~ ~ ~' 21-Feb 10:00 42 0.0 104 88 899 1.53 952 35 1610 53 136 1.63 1378 675.0 40.0 0.833 21-Feb 10:30 42 0.0 311 96 927 1.03 972 35 1062 35 139 1.65 1399 675.7 40.0 0.833 Diverted Tk #4 to Tk #2. Oil API = 41 @ 86 F = 38.9 @ 60 F 21-Feb 11:00 42 0.1 191 97 903 1.56 1594 139 978 41 140 1.69 1432 678.6 40.0 0.833 BSB,W = 12% water Divert Tk #4 to Tk #3 21-Feb 11:30 42 0.1 163 95 806 1.98 1347 184 1470 46 126 1.73 1460 682.4 38.9 0.807 . 21-Feb 12:00 42 0.0 41 86 819 1.41 500 21 2822 37 129 1.76 1470 682.9 38.9 0.807 Diverted Tk #1 to Tk #3. BS&W = 30% 21-Feb 12:30 42 0.3 186 96 840 1.33 625 268 2130 37 133 1.79 1483 688.5 38.9 0.$07 water Diverted Tk #3 to Tk #1. BS&W = 45% 21-Feb 13:00 42 0.5 224 99 823 1.49 767 628 1938 40 130 1.82 1499 701.5 38.9 0.807 water Diverted Tk #1 to Tk #3. BS&W = 75% 21-Feb 13:30 42 0.8 201 94 791 1.65 316 949 5210 42 138 1.85 1506 721.3 38.9 0.807 water Diverted Tk #3 to Tk #1. BS&W = 10% 21-Feb 14:00 42 0.1 84 88 -828 1:37 871 97 1570 38 131 1.88 1524 723.3 38.9 0.807 water 21-Feb 14:30 42 0.0 135 89 868 0.91 948 19 964 33 127 1.90 1544 723.7 38.9 0.807 Oil API = 40 @ 80 F = 38.4 @ 60 F 21-Feb 15:00 42 0.0 214 97 857 1.55 1584 16 978 42 140 1.93 1577 724.1 38.9 0.807 Diverted Tk #1 to Tk #3. BS&W = 2.5% 21-Feb 15:30. 42 0.0 164 93 841 1.54 1475 38 1042 42 134 1.96 1608 724.8 38.4 0.876 water w/trace sediment Diverted Tk #3 to Tk #1. Cernpleted 21-Feb 16:00 42 0.0 166 96 797 1.69 1336 34 1265 44 126 2.00 1635 725.6 38.4 0.876 otTktM6toTn~ck 115 Diverted Tk #1 to Tk #3. BSSW = 5% 21-Feb 16:30 42 0.1 111 91 771 1.51 1301 68 1160 42 135 2.03 1663 727.0 38.4 0.876 water Diverted Tk #3 to Tk #1. BS&W = 25% 21-Feb 17:00 42 0.3 181 97 773 1.47 1058 353 1391 42 138 2.06 1685 734.3 38.4 0.876 water Started transfer of Tk #7 to Truck 250. 21-Feb 17:30 42 0.3 201 98 754 1.51 922 307 1643 42 130 2.09 1704 740.7 38.4 0.876 Diverted Tk #3 to Tk #1. BS&W = 55% 21-Feb 18:00 42 176 97 743 1.52 598 731 2536 43 140 2.12 1713 748.0 38.4 0.876 water. Diverted Tk #1 to Tk #3. BS&W = 7% 21-Feb 18:30 44 178 97 747 -1.46 1218 92 1196 42 142 2.15 1738 749.9 38.4 0.876 water. CONFIDENTIAL INFORMATION CONOCOPHILLIPS REQUESTS THE INFORMATION BELOW AND ATTACHED BE KEPT CONFIDENTIAL AS REQUIRED UNDER AS 31. 05.035(c) and 20 AAC 25.537(d). • J Page 5 of 7 CUSTOMER : ConocoPhillips PERFORATION INTERVAL :0000.0 - 0000.0 m WELL TEST DATA SHEET WELL NAME : Rendezvous 2 TEST No.: Flow #1 -Clean-up ~~~II~ ~ DATE : 19-Feb-0B 12:00 to 22-Feb-08 05:30 CUSTOMER REP.: Jack Kraiick BASE: Anchorage, AleSke RIG : EXPRO SUPERVISOR :Denis Henrion DATE & DOWNHOLE CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME BHP BHT SIZE BSSW WHP WHT CSG GAS Oll WATER GOR PRES. TEMP. B38~W GAS OIL WATER OIL GAS REMARKS (dd-mmmhh:mm) (psia) (°F) (64ths) (%) (psig) (°F) (psig) (MMSCfd) (stb/d) (stb/d) (scf/stb) (psig) (°F) (%) (MMscf) (sib) (stb) (API@60°f) (Air=1) Diverted Tk #3 to Tk #1. 21-Feb 19:00 46 172 97 748 1.44 1569 83 916 41 129 2.18 1771 751.6 38.4 0.876 Diverted Tk #1 to Tk #3. BS&W - 10% 21-Feb 19:30 48 170 97 737 1.47 1051 117 1401 43 137 2.21 1793 754.1 36.7 0.860 water. Diverted Tk #3 to Tk #1. BS&W = 6% 21-Feb 20:00 48 178 98 729 1.58 1098 70 1434 44 143 2.25 1816 755.5 36.7 0.860 water. Diverted Tk #1 to Tk #3. BS&W - 5%. 21-Feb 20:30 48 164 97 725 1.52 1186 62 1283 42 132 2.28 1841 756.8 36.7 0.860 Diverted Tk #3 to Tk #1. BS&W-12% 21-Feb 21:00 48 171 98 722 1.44- 1170 160 1228 42 137 2.31 1865 760.1 36.7 0.860 water. Increased choke to 50/64ths. 21-Feb 21:30 48 169 97 725 1.48 1160 129 1278 43 143 2.34 1889 762.8 36.7 0.860 Diverted Tk# 3 to Tk #1. BS&W - 9% 21-Feb 22:00 50 169 97 723 1.45 1210 120 1196 48 132 2.37 1914 765.3 36.7 0.860 water. Diverted Tk #1 to Tk # 3. BS&W - 4% 21-Feb 22:30 50 168 97 720 1.42 1315 55 1082 52 141 2.40 1942 766.5 36.7 0.860 water. Diverted Tk #3 to Tk #2. BS&W - 4% 21-Feb 23:00 50 165 97 723 1.46 1315 55 1107 55 146 2.43 1969 767.6 36.7 0.860 water. Diverted Tk #2 to Tk #4. BS&W - 5% 21-Feb 23:30 50 162 97 728 1.43 1202 63 1190 54 132 2.46 1994 768.9 36.7 0.860 water. Diverted Tk #4 o Tk #2. 22-Feb 00:00 50 173 98 725 1.42 1237 65 1145 55 140 2.49 2020 770.3 36.7 0.860 Diverted Tk #2 to Tk #4. BS&W - 6% 22-Feb 00:30 50 174 97 726 1.45 1259 80 1153 56 148 2.52 2046 771.9 36.7 0.860 water. Diverted Tk #4 to Tk#2. BS&W-5% water. 22-Feb 01:00 50 175 96 731 1.40 1219 64 1152 55 133 2.55 2072 773.3 36.7 0.860 Oil API: 39.5 @ 88 F. 22-Feb 01:30 60 166 97 .730 1.41 1159 87 1218 56 140 2.58 2096 775.1 36.7 0.853 Diverted Tk #4 to Tk #2. BS&W - 6% 22-Feb 02:00 60 173 97 720 1.49 1180 75 1266 57 147 2.61 2120 776.7 36.7 0.853 water. Diverted Tk #2 to Tk # 4. BS&W = 5%. 22-Feb 02:30 60 169 97 708 1.54 1295 83 1189 57 136 2.64 2147 778.4 36.7 0.853 Increased choke to 70l64ths adj. 22-Feb 03:00 60 159 97 704 1.46 1117 71 1311 57 143 2.67 2170 779.9 36.7 0.853 Diverted Tk #2 to Tk # 4. BS&W-2% water. 22-Feb 03:30 40 214 97 720 1.32 1066 22 1242 63 144 2.70 2193 780.3 36.7 0.853 Increased choke to 42/64ths adj. 22-Feb 04:00 40 188 96 733 1.39 1173 116 1183 60 138 2.73 2217 782.8 36.7 0.853 BS&W-4%water. Diverted Tk #2 to Tk #4 22-Feb 04:30 40 190 96 743 1.37 1160 48 1183 59 146 2.76 2241 783.8 36.7 0.853 . Diverted Tk #4 to Tk #2. BS&W- 6% water. 22-Feb 05:00 40 197 95 741 1.44 1288 82 1117 61 143 2.79 2268 785.5 36.7 0.853 Diverted Tk #2 to Tk #4. BS&W-7% water. 22-Feb 05:30 40 191 95 742 1.41 1311 99 1077 61 142 2.82 2295 787.5 36.7 0.853 CONFIDENTIAL INFORMATION CONOCOPHILLIPS REQUESTS THE INFORMATION BELOW AND ATTACHED BE KEPT CONFIDENTIAL AS REQUIRED UNDER AS 31. 05.035(c) and 20 AAC 25.537(d). i Page 6 of 7 - CUSTOMER : ConocoPhillips PERFORATION INTERVAL :0000.0 - 0000.0 m ~~INguuN~~" i WELL TEST DATA SHEET WELL NAME :Rendezvous 2 TEST No. :Flow #1 -Clean-up r ` ~~ ~ ~ Wl ~V1r DATE : 19-Feb-08 12:00 l0 22-Feb-0B 05:30 CUSTOMER REP.: Jack Kralick l l i BASE; Ar1ChOfag@, Alaska RIG : EXPRO SUPERVISOR : Denis Henrion DATE 8 DOWNHOLE CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME BHP BHT SIZE BS&W WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BSBW GAS OIL WATER OIL GAS REMARKS (dd-mmmhh:mm) (psis) (°F) (64ths) (%) (psig) (°F) (psig) (MMSCfd) (stb/d) (stb/d) (scf/stb) (psig) (°F) (%) (MMscf) (stb) (stb) (APIQ60°f) (Air=1) CONFIDENTIAL INFORMATION CONOCOPHILLIPS REQUESTS THE INFORMATION BELOW AND ATTACHED BE KEPT CONFIDENTIAL PURSUANT TO 5 USC 552(8)(9). CONFIDENTIAL INFORMATION CONOCOPHILLIPS REQUESTS THE INFORMATION BELOW AND ATTACHED BE KEPT CONFIDENTIAL AS REQUIRED UNDER AS 31. 05.035(c) and 20 AAC 25.537(d). ~~ ~J Page 7 of 7 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E {DOA) Sent: Sunday, February 24, 2008 10:45 AM To: 'Morgan, Mike R' Cc: Kralick, Jack T; Cawvey, Von Subject: RE: Rendezvous #2 Weekly Status Report Mike, et al, Thanks for the report of the ongoing operations. Tom Maunder, PE AOGCC ~~~-~~~ From: Morgan, Mike R [mailto:Mike.R.Morgan@conocophillips.com] Sent: Friday, February 22, 2008 7:06 PM To: Maunder, Thomas E (DOA) Cc: Kralick, Jack T; Cawvey, Von Subject: Rendezvous #2 Weekly Status Report Tom, I've faxed over a copy of the attached Rendezvous #2 status report. A hardcopy will be delivered next week. We will continue to file weekly reports until completion of operations. Best regards, Mike Morgan ConocoPhillips Alaska, inc. Exploration Engineer 907-263-4332 We request that the attached information be held confidential as required under AS 31.05.035 (c) and 20 AAC 25.537(d). 2/24/2008 FW: NE-NPRA 2007-2008 Exploration Project Update Maunder, Thomas E (DOA) From: Morgan, Mike R [Mike.R.Morgan@conocophillips.comj Sent: Friday, January 25, 2008 12:09 PM To: Maunder, Thomas E {DOA) Cc: Kralick, Jack T; Crumrine, Tim William; Barreda, Brian B Subject: FW: NE-NPRA 2007-2008 Exploration Project Update Attachments: Project Tracker 01.25.08.pdf Tom, Page 1 of 2 ao~-oo1 I understand you met with Jack Kralick regarding our plans Rendezvous 2 this season. Thanks for the quick turn around on the Sundry Approval. Before Jack headed north he asked that I keep you posted on our progress. Below, and attached, you'll find an update on our schedule (updates occur every Tuesday and Friday until the rig and testing work starts). I hope all is well, and please don't hesitate to call with any questions. Best regards, Mike Morgan ConocoPhillips Alaska, Inc. Exploration Engineer 907-263-4332 From: Ramirez, Thaimar R Sent: Friday, January 25, 2008 10:29 AM To: Alvord, Chip; Barman, David B; Barreda, Brian B; 'Bowen, Kim ; Brasfield, Tom J; Campaign, Wayne; Cawvey, Von; Chambers, Mark A; Crumrine, Tim William; Darnall, Jim; Doherty, Patrick D; Eiben, Thorsten; 'Fleming, Tim'; Hannon, Renee; 'Hansen, Patti ; 'Home, Jerry ; Hughes, John D.E.; Isaacson, Erec S; Knodc, Douglas G; Kralick, Jadc T; Kunemund, Robert J.; 'Martin, Joe'; Morgan, Mike R; 'Murphy, Russ'; Roadifer, R D; Snyder, Frank C; Soria, Dora I; St.Pierre, Bruce; Sykes, Gary R.; Tracy, Martin'; Way. Patrick E(Frorrtiine Group of Texas); 4viison, Chris; 'Wilson, Doug'; Wilson, Gregory C Subject: NE-NPRA 2007-2008 Exploration Project Update Friday January 25, 2008 Highlights Ice Road Progress: Colville River bridge is 100% complete, ramps are 100% complete (Opening Today, Jan.. 25 at noon; call ice road hotline, 659-1779, for updates prior to traveling) Char#1: Char cut-off to Char location is 47% complete, estimated completion date Jan. 29th. Char Drilling Pad (500'x500'x3') is 0% complete, estimated completion date Feb. 6th. Spark DD-9 and Rendezvous 2: Char Cut-off to Ublutuoch is 57% complete, estimated completion date Jan. 26th. Ublutuoch to Spark DD-9 is 94% complete, estimated completion date Jan. 26th. Spark DD-9 ice pad (500'x500') is 0°I° complete, estimated completion date Feb. 10th. 2124/2008 FW: NE NPRA 2007-2{}08 Exploration Project Update Page 2 of 2 Spark DD-9 to Rendezvous 2 is 0°k complete, estimated completion date Jan. 31st. Rendezvous ice pad {500'x500') is 0% complete, estimated completion date Feb. 5th. Rendezvous 2 tiltmeter installation is 69% complete (25/36 holes drilled as of Thursday, Jan. 24th) Estimated Mobilization Anticipated rig move Doyon 141 to Char #1 is Feb. 6th with spud date Feb. 9th. Anticipated test and wellwork rrrobi#ization to Rendezvous 2 is Feb. 5th; an early well integrity assessment is planned. Activities at Risk: Spark DD test and abandonment operations {21 day minimum for test rig up, test, shut in, well P&A}. Plans are in-place to suspend ongoing KRU 3C-14A we{I operations to accommodate ice road opening/rig move-out. Comments: This report shows Peak's updated schedule. Please, find enclosed a summary report for further details. «Project Tracker 01.25.08.pdf» Thanks, Thaimar Ramirez Associate Pedopny~ist Exploration, Evaluation, and Operations Co n o c o P h i /Jip s A /a s, Fa office: +1-907-265-6524 a 2/24/2008 • RIG: 3C!14A (KRU) a ~ ~V~~ 11 1/23 2/3 Well to be suspended RIG1: Set Conductor at Char 2 213 2/5 Install while finishing pad RIG1: Move D141 to Char 3 2I6 2/9 RIG1: Drill Char #1 22 2/9 3/2 TEST2: Char #1 Frac & Tests 30 3/3 4/2 RIG2: Move to Spark DD 4 3/2 3/6 RIG2: Drill Spark DD Pilot Hole 20 3/6 3/26 RIG2: ST Spark DD to tioriz, Complete 13 3/26 4l8 TEST3: Spark DD Test 8 P8A 27 4/8 Sly RIG3: CD4 Operations (Max Days) 23 4/8 5/1 Includes rig move Comments: Plans are in-place to suspend ongoing 3C-14A well operations to accomodated ice road opening/rig move-out. /loos zo/-oc7~ Daily Operations Summary Report RENDEZVOUS 2 ; ,_ ~ ~ ~ 2oU~ ,~ Y ~ /~ V'~ JSct~'n,.. Job: RECOMPLETION RALPH WILBURN :ASSIST FMC W/CRANE TO PULL BPV. DHD PERFORM, PACKOFF TEST. MIT TBG TO 4000 PSI, PASS. MIT IA TO 3500 PSI, PASS. MIT OA TO 1500 PSI, FAIL. PULL XXN PLUG @ 8325' MD. RUN LIB ON 2.73" X 10' DUMBELL DMY DRIFT, CLEAN PIC OF SUPPOSED FIRINIG BEAD @ 8345' MD. IN Well shut in at 0600 yesterday -build-up in progress for 72 hours from then -emptied tanks to recycle and injection well ,. ~ GonFl~e,T`~ 259 I~ ~ b ` It ~~ ~ ~ ~ ~~ ~^ r ~ ~ I pt U aE t10~e~eCOIYl1 t ~,~~' ..,, , , „r r ,hw. ,,,;~ EXPRO ~~.: - ~ ~ , ,.. ~~.~ y_ Completed build-up at 0600 hrs -started slickline rig up -cold ambient temperatures caused a slight delay waiting until above -40 degrees Page 1/2 Report Printed: 5/8/2008 Daily Operations Summary Report RENDEZVOUS2 Job: RECOMPLETION *** SLU214 "*: RALPH WILBURN BRUSHED TBG TO 8350' SLM & TAG FISH. APPEARS FISH MOVED -5' DEEPER FROM LAST TAG. SET CATCHER @ 8325' RKB. PULL PETRADAT SPG @ 8302' RKB. REPLACED WITH HES-SPG (SER# 4032). PULLED 1/4" ORIFICE VLV @ 8302' RKB (NO SIGNIFICANT WEAR). REPLACED WITH SAME. SET HES QUARTZ GAUGES ON XXN LOCK @ 8325' RKB (OAL= 10'). SET & PULLED 2.75" X-PLUG @ 7906'. PERFORMED DRAW DWN TEST ON PLUG. GOOD TEST. RAN TEST RUN OF CATS GAUGES. MADE STOPS @ 2000',3000',4000',5000',5500',6000',6500',7000',7500',7935',7960',7994',8220' RKB'S. GOOD DATA. ***NO DATA @ 8324' RKB. SET CATS GAUGES (OAL= 29.63") w/ 2.75" DHSIT (OAL= 8.91 ") ON 2.75" X-LOCK (2.813" KEYS) @ 7906' RKB. SET 2.75" XX PLUG @ 7910' RKB JOB COMPLETE (2008. 6/2008.. RALPH WILBURN PULLED DHSIT & GAUGES @ 7906' RKB. PULLED 1" HES-SPG @ 8302' RKB. PULLED 1/4" OV @ 7854' RKB. ***LEFT POCKETS OPEN***. PULLED 2.75" XN-LOCK ASSY w/QUARTZ GAUGES @ 18325' RKB. SET 2.75" PXX PLUG & PRONG @ 7906' RKB. JOB COMPLETE.JOB DONE BY RALPH WILBURN «~ SLU770 "": j RALPH WILBURN SET 1'' OV @ 7854' RKB, PULL 2.79" PXX PLUG @ 7899"RKB, BULLHEAD FLUIDS, PULL'. ',1" OV @'7854' RKB TBG FLUID LEVEL AFTERsC~V 5ET = 1400' SLM i " SLU770 " RALPH WILBURN TAGGED CEMENT PLUG @ 7135' SLM + (CORR. _ -7) = 7128' RKB, PULL 1" DMY VLV @ 2494' RKB. Page 2/2 Report Printed: 5/8/20081 ~ ~ COIIOCO~11111PS TRANSMITTAL C(JNF/DENT/AL DATA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Rendezvous 2 AOGCC Permit: 201-007 DATE: 04/29/2008 North Slope, Alaska Rendezvous 2 501032036300 1 CD and 1 hardcopy report TO: Christine Mehnken State of Alaska AOGCC 333 W. 7"' Avenue, Suite 100 Anchorage, Alaska 99501 Rendezvous 2 Well Test Report by EXPRO; Jurassic perfs 8350'-8390'md; test dates 2119 to 3/3/2008 Restricted Confidential-proprietary geotechnical data ~~t~ #n h~ hAlri r~n~~i~ic~nti~l /~r~~~rst ~n Z1~; /1'~ ~#T^~ {l~?~1~1 +''?~ ~/1 s,_-. a}L- #:-....='. 4~ ~.s a.f Yia 4L-s 53, 4.~f ~~i # v` .4..a: i _~.r Z -a.., =m. } ~{ f d.,_,..~ CC: Fran Sn e CPAI Onshor c~5foration Manager a "~.0~ ~P~'°~~ ?`'s3 Receipt: Date: ..,:._ . ,... _.__ „'?t~li~Ss(~ ,~,:'.r'3q'' ~~~ GfS-Technica~r Data Management ~ ConocoPhi/lips ~ Anchorage, Alaska (Ph: 907.265.6,947 Sandra.D.Lemke~Conocophil/ips com ~~~N~~3 APR 2 9 2008 CONFIDENTIGL ~o~ - ov ~- STATE OF ALASKA .ALASKA OIL AND GAS CONSERVATION COMMISSION Surtace Abandonment /Location Clearance /Suspended Well ( Title 20 AAC 25.170 ) FILE INFORMATION: Operator: ConocoPhillips Alaska, Inc, Well Name: Rendezvous #2 Address: P.O. Box 100360 PTD No.: 201-007 Anchorage, Alaska 99510 API No. 50- 103-20363-00 Surface Location (From Sec. Line): Unit or Lease Name: N/A NorthlSouth 1707 FNL East/V1/est 2632 FEL Field and Pool: NPRA Ex !oration Section: 6 Township: 9N Range: 2E Meridian: U Downhole P&A Date: 20 AAC 25.120 -ABANDONMENT MARKER: Insp. Date: Surface Monument Approval Date: Post OD: (4" min) _" Length: _ft. Set on (Wellhead, Csg , In Cmt) Height above final grade (4' min.): _ft. Casing stub_ft. below final grade Top of Marker Post Closed ? _ All openings closed ? Inspector: Insp. Date:4/5/08 Subsurface Monument Approval Date: Marker Plate Diameter: 16" " Distance below final grade Level: 4' Thickness: 3/4 " Side Outlets removed or closed: N/A Marker Plate Attached To Conductor Y (Y!N) Cement to surface (all strings)? Yes Ins ector: Lou Grimaldi Exact Information Beadwelded Directly to Marker Post or Blind Marker Plate: Insp. Date: 4/5/08 Approval Date: CONOCO PHILLIPS-AK RENDEZVOUS #2 API#50-103-20363-00 PTD #201-007 c~~`~~~@6CEa~8s~ APR ~ ~ 2008 Ins ectar: Lou Grimaldi Insp. Date: 20 AAC 25.170 -LOCATION CLEANUP: Approval Date: Pit's filled in? Liners Removed or Buried? Debris Removed: Notes: General condition of padllocation: (Rough, Smooth, Contoured, Flat, Natural ) Notes: Type of area surrounding location: {Wooded,Tundra,Grass,Brush,Dirt,Gravel,Sand) Debris on surrounding area: Notes: Access road present? Type road: (Dirt, Gravel, Ice, Other) Condition: Condition of road: Notes: Cellar filled in? Type of fill: Height above grade: Notes: Type work needed at this location: Ins ector: RECOMMENDED FOR APPROVAL OF ABANDONMEI Yes gNo~~ (If "No" See Reason ) Distribution: Reason: ~i1C~Or\ C-~C?~t;YL;~'~_ !`~, ~.(..t'~! orig -Well file c -Operator Final inspection performed? Yes No c -Database c -Inspector Final Approval By: Title: DATE: J rJ+~" Sheet by L.G. 8/5/00 2008-0405_Surf_Abandon_Rendezvous-2_Ig.xls 4/17!2008 • • Rendezvous #2 (ConocoPhillips) Surface Abandonment Photos by AOGCC Inspector Lou Grimaldi April 5, 2008 r.. ~~~~~ ~I- ~f ~+~~ _, .~y1( .. _, fh~S ~+F ~ J sy_ a 1~' ~ _ Excavation, casing stub; cement to surface Marker plate • • d~~ 1.:....~ ~.:; ....d u .._~ .~ ~~.~~,8 ~ ~ ~~ ~ ~ ~ ) ~ ~)- r- ~~ SARAH PAL/N, GOVERNOR ~S~A OIIt ~ ~" 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA7'IO1~T COl-IIuII55IO1~T ANCHORAGE, ALASKA 99507-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Von Cawvey Wells Supervisor Conoco Phillips Alaska Inc. ~~~)~ JAN ~ ~ 20~~ PO Box 100360 Anchorage, AK 99510 Re: Exploration Wildcat, Rendezvous #2 ~ ` ~ ~~ ~ Sundry Number: 308-0 l 1 _.._ ..__.....__...... ~....., :.. Dear Mr. Cawvey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. It is stated that following the planned activities that the well will be plugged and abandoned. A separate Form 1-403 should be submitted with the specific details of the plugging. A weekly status report is required from the time well operations are resumed until the well is plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this,~bday of January, 2008 Sincerely, ~~ (~,{~~ • "' ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 C~~~ Jai ~ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Pertorate ~, Wai er Other ^/ ~rl~~ti 13 Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^~ Time Extension TEST Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory 0' 201-007 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20363-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS NO Q Rendezvous #2 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): AA-81781, ALK 5126 RKB 35', GL 115' Exploratory 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8650' 8649' '" 8325' 8324' 8325' Casing Length Size MD ND Burst Collapse Conductor g5' 16" 115' 115' Surface 2638' 9.625" 2673' 2672' Production 8567' 7" 8602' 8601' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8344'-8390' 8343'-8389' 3.5" L-80 8394' Packers and SSSV Type: Packers and SSSV MD (ft) pkr ~ 7952' no SSSV 13. Attachments: Description Summary of Proposal ~ 14. WeII Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^~ ~ Development ^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat February 1, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Suspended ^' 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Kralick @ 240-5553 Printed Name VOrI CawVe Title: Wells Supervisor i ~~' ~d8 D t ~ a e Signature Phone 265-6305 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so therepresentative may witness ~~'- o echanical Integrity Test ^ Locat ion Clearance ^ Plug Integrity ^ BOP Test ^ M \ e l ~j-~-cam ~ \~ ISS 'W l~c~ \`Cl0 ~ ~ Q ~ 'l~S~vt1\'~`~~ ~ ~~ t- ~"~" Other: h~~` ~4``7 Q i ~ ` \ /~ i ,C < Subsequent Form Required: ~0~,,,,\ uh ~ h ~ ~~~ i ~C~~~ `,~C ~~~, ~e~ ~~ c tttJJJ J r APPROVED BY ~/D / Approved by: ( COM ISSIONER 1 I N Date: f Form 10-403 Revised 06/2006 ~, ,i~tEti ~~ ~ ~~~~ Submit in Duplicate ~! ~!/08' • • Rendezvous 2 Well Work Procedures Summary • ~ Re-enter well, build scaffold and tent -heat up wellhead. Pull VR Plugs and BPV, XN Plug • •r MIT on annulus -Test tree to 5000 psi to ensure integrity • Slickline Beat Guns Off Tubing Tail o E-line on location with chem cutter o CT rigged upon location with BOPs tested to beat guns downhole if necessary • > Rig up sickline for StimTube shot • Frac • ~> CT FCO -N2-on location if necessary • Pull/Replace DV with OV • -Run Cars system with DHSIT • • Rig Up PWS for flowback • Flowback X days • ~ Surface Samples • =Wait for build-up Part1: E're~Vlfell',fbr: Frac and Flowback EEI V E~ JAN ~ 2008 Alaska Oil ,~ Oa~~ Cans, Commission pnchora~e In ordentm minimize• downtime due to mobilization and rig up tiime itwili:be necessary to have. SL,- E~iine, and C~ rigged up and ready to move to the well if needed:. GT should test BUPs~prior to I~au.ing= Alpine to #ravel to Rendezvous 2, During this ime 2 LRS units are needed., one I~~_unit ~arill be used to support ongoing well work and another to warm tanks fon the firac jpb. Install #IoNv:cross to top of ree. Notes: Call FMC to pull BPV and VR plugs Slickline 1. Pull BPV, VR plug 2. R/U LRS to test tubing to 5000#, monitor IA ~ 3. Test IA to 3500 psi, monitor tubing ~-~ `~~~~0`~~~~~c~~ ` 4. Drift wellhead through tubing hanger with 2.89" or greater gauge ring or swage w ~~~SS Q~SSvcfc 5. Drift and tag X plug at 8325' RKB (min. I.D. 2.79") ~5~ a, ~ t ~ 6. Equalize and pull X plug. Allow WHP to stabilize and record pressure. ~ 7. M/U toolstring with 2-1/8" 13 stem with blind box 8. Spend no more than 6 hours beating on auto release -unless progress is being made. a. If successful, follow fish down and tag top of fish, continue to step 9. b. If unsuccessful, have LRS on standby to ensure a fluid pack, note any fluid losses. E-line 1. Prep for Chemical Cut with E-line. (note: RA PIP Tag at 7893' RKB and 2.75" XN nipple at 8325' RKB) 2. Run string shot 3. Chemical cut above auto release firing head Slickline • ~ 1. Tag top offish. 2. If fish is below perforation midpoint at 8370' RKB, run HES StimTube to open up perforations. If guns are not below midpoint, move CT to well to attempt to beat guns downhole. Coiled Tubing 1. Move onto well with CT with BHA made to jar down with HIPP-TRIPPER or similar to jar auto-release firing head. 2. If successful follow guns down for tag 3. If unsuccessful POOH and c!o BHA for FCO Part 2: Frac Well Frac Crew and Equipment 1. Install 3-1/2" tree saver 2. Pump Step Down Test to obtain near wellbore friction. If over 1000 psi wellbore friction is observed. Pump scour stage, and repeat step down. 3. Pump Minifrac to Perfs / SD let frac heal. Displace minifrac into formation 4. Pump Main Frac Treatment / SD when pad reaches perforations to allow frac to heal 5. Flush Coiled Tubing Perform post frac FCO Part 3: Prep for Flowback Slickline 1. R/U and test lubricator 2. Brush XN nipple, and all GLMs and nipple profiles above XN. Brush tree on way out of hole 3. Set catcher sub in 2.813" XN nipple 4. Pull DV from STA#4 @ 8302' RKB and set side pocket gauge in same 5. Pull/Replace DV in STA#2 with %4' OV 6. Pull catcher 7. Run Cars system on X lock. Set in X nipple at 7899' RKB Part 4: Flowback and Data Gathering PWS 1. RU Flowback Unit with Sand Buster as per PWS schematic 2. Flowback well for 1 week to tank farm Disposal of fluids Fluid disposal will be at CD4 recycle tanks. via crude oil transport trucks -tanks to be set at CD4 in Alpine to offload and a pump truck will pump into the CD4 crude oil line that will take the fluids to the Alpine plant for processing. SLB DilPhase On location for surface sampling and possible downhole samples r: Nitrogen N2 on location for well kickoff (Specify volume of annulus) Instrumentation Shack on location for computer equipment Part 5: Plug and Abandon -Drilling to Conduct P&A Slickline to pull Ca Ts tool E-line Perforating Cement Van Excavating GBR • - ~-1O~ c~~EC) . Page 1 of 1 Rendezvous #~2 Completion Schematic Revision 1112!07 ee~trisare ttaxad wt Boyon141 QR[46 -LW i6" 65X (i~40 +115 MD Surface wg. 9-S~" 40.0# LED: @TCM (2873' PAD k 2673 T'tE31 Ar[aee rasing cemented as fatlo+ns- 2Dbbts CW-10D Wash 40: bbls of t0.5 ppg MudPUSti?C Spacer 332 bbts RSilt Ltta ~ 1.0.7 ppg, 4.44. cer. Hlak 72 bbls of- t2 PP9 LiEeCtata (~ 2:36 au tfsk FuHceLnrs, Evmped.plug. Aoets hekt Fhida: Bie.~l m 2494' ND;- 9.i ppg Brineto Bohan 3-1l2" FMIC Gen V Tubing Hanger, 4-112" LEO EUEBRD p(n cbvui 3-112" 9.3# L-BO E UEBRD Speceott Pups as Requ'ued 3-112" 9.3# L-80 EUESRD Tubing to Surtace 3-1 R" Cemco 95' nipple v~d 2.679' profile sd at 892' MD 3-1 R" 9.3# L-80 ELE8RD tubng to landng ripple 3-12"x1"Cameo%BNM~2'mandrel+rdi"G~^L4'~<.dBKl:xtdi,6' LEOhandfmg pups installed dove and belov. Mandrel @2494' MD 3-12" x 1" Carteo %BMNF2' mandrel vwBK-5latch and dummy, 8 LEO hantlmg pupsinstalleddloveandbeiow. Mandrel(~7854`MD ~., ~-~~ - . -~ :~.~~ baL? 3-1l2"Cartco'X'nipplevil2E13"profJa.NdelD is smatterthen spedfietl BakerPBR (1 OtjvoModet K 22 tbg seal ripple. PBR shear cGri 39K #) r Packerkrailoioe A~ernblY Baker 7" x 4"'SPB-3' P adcer pin fM 500 psi shear Top to bottom: 4" x 3.5" XO sub, 5 pup, 9 ~a 3.S' 9.3ppf LEO tubing, 8' pup, Cameo 3.5" x 1" KBMM-2 GLM vvt3l{S latch and dumm y (~-6252' Cameo 3.5" x 1" KBMM--2 GLM~+raHK-5 latch end dummy (~ 8302' 7"'easiru3 ae,narAed asfot 2D!bbis G4`41t30: Wac_n SD bbis M~cP USHXL 60 bbls 12.0 ppgL@eCrete ~ 2.4 cfft.fsk 41': bb1515.$.ppg,Gasbk~ X12 cu.ftlsk Disf4: vr326 bbts 9&ppg brine. Lost 50 - 9D~. rdurrn afia 29D bbls pumped. Bumped?pk~„floats belt{ Produdlrxt rasing, 7` 26:Dt=LED BTCM ('88ttT-t.K?-f 86D7 T,4~D2 3.S' x 2.75' XN nipple (2.813" X 2.75" X74+1 Plug Ground Down to 2.79" W! 2' Debris Catcher OD installed and tested) {~ 6325 MD 8' Ported Sub C~ 6336' MD e~~,r ~ es~~ raa `, i~ G'.-C25~,an~~ar FSirg t€~saei Stitlf k~zcts~d-ts:~?s CheF;ac~a CuF! Perforations 8350' • 6390' ~ 5 spf Passible 49.T of fired & dropped TCP gums (8515' -646591~ft in hole Float Collar @ 6516' file://S:\NSK\LongTerm\Groups\Wells Group\Well Testing (EXP130)\2008 Well Testing\... 1/16/2008 • PHILLIPS Alaska, Inc. FIN~~. TUBING Single Completion Assembly • Revised 23 Apr 2001 WELL: RENDEZVOUS 2 DATE: 4/22/01 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS " DOYON 141 RT to LDS = 23.10' 23.10 FMC GEN V tubing hanger w/pup 2.70 23.10 Jt 261 3.5", 9.3#, 8rd EUE Mod tubin (1 ~t) 31.34 25.80 Space out pups 3.5" 9.3# L-80 Act. pups={8.15 TOP+9.96+10.05} 23.53 57.14 Jts 235-26 3.5", 9.3#, 8rd EUE Mod tubing (26jts) 811.79 80.67 Nipple 2.875" CAMCO DSN3.5" EUE Mod 8rd Box X Pub 1.60 892.46 Jts184-234 3.5", 9.3#, 8rd EUE Mod tubing (51 jts) 1594.42 894.06 pup 3.5" 9.3#, 8rd EUE Mod Box & Pin Pu 5.56 2488.48 GLM #4 Camco 3.5" X 1", KBMM-2, w/1" shear vlv set @ 2900# 6.87 2494.04 pup 3.5" 9.3#, 8rd EUE Mod Box & Pin Pup 6.19 2500.91 Jts13-183 3.5", 9.3#, 8rd EUE Mod tubing (171jts) 5341.64 2507.10 u 3.5" 9.3#, Srd EUE Mod Box & Pin Pup 5.61 7848.74 GLM #3 Camco 3.5" X 1", KBMM-2, w/BK-5 latch & dummy 6.80 7854.35 pup 3.5" 9.3#, Srd EUE Mod Box & Pin Pup 6.10 7861.15 1 Jt 3.5", 9.3#, Srd EUE Mod tubing (1jt) 31.36 7867.25 Ni ple X nipple w/2.813" id 'X' profile 1.42 7898.61 1~t 3.5", 9.3#, Srd EUE Mod tubing (1jt) 31.44 7900.03 up 3.5" 9.3#, Srd EUE Mod Box & Pin Pup 6.37 7931.47 PBR Baker PBR w/seal stem, 10' seal travel, pin to shear @ 39K overpull 13.33 7937.84 u 3.5" 9.3#, Srd EUE Mod Box & Pin Pup OUT ??? 7951.17 tb anchor Tubing anchor, Model k-22, w/tbg seal nipple .92 7951.17 Packer Baker SAB-3 Packer, pin f/1500 psi shear 4.92 7952.09 XO XO sub, 4" LTC Box x 3-1/2" EUE Srd Pin .87 7957.01 u 3.5" 9.3#, Srd EUE Mod Box & Pin Pup 6.12 7957.88 9 Jts 3.5", 9.3#, Srd EUE Mod tubin (9't) 282.39 7964.00 pu 3.5" 9.3#, Srd EUE Mod Box & Pin Pup 5.66 8246.39 GLM #2 Camco 3.5" X 1", KBMM-2, w/BK-5 latch & dummy 6.77 8252.05 pu 3.5" 9.3#, Srd EUE Mod Box & Pin Pup 6.16 8258.82 1 Jt 3.5", 9.3#, Srd EUE Mod tubing (1jt) 31.41 8264.98 u 3.5" 9.3#, Srd EUE Mod Box & Pin Pup 5.44 .8296.39 GLM #1 Camco 3.5" X 1", KBMM-2, w/BK-5 latch & dumm 6.87 8301.83 pup 3.5" 9.3#, Srd EUE Mod Box & Pin Pup 6.15 8308.70 up 3.5" 9.3#, Srd EUE Mod Box & Pin Pup 9.98 8314.85 Nipple XN' Nipple w.2.750" id, polished w/RHC seat latched in place 1.36 8324.83 pup 3.5" 9.3#, Srd EUE Mod Box & Pin Pup 10.04 8326.19 Ported Sub Ported sub (balanced isolation tool) 8.05 8336.23 Firing Head 1.~7 8344.28 Tubing. auto release firing head (7.34') & blank gun (3.72') 4.65 8345.35 loaded PERF gun (40.00' 40.00 8350.00 Bottom shot to TDF & 3-3/8" TDF (firing head) 3.93 8390.00 Botfc:,°~ of t€,.'€~[~~ cOS~ve~`ed ~erforatir~g s,~ste~t~ --> 8,393.93 NOTE: RA PIP TAG IN 7" CSG 7892.89' Revised 24 Apr 0001 Firs Seal ass lac 1' alsave PBR Ran 261 jts DOYON 141 Drilling Supervisor. R.W. SPRINGER/R.W. BOWIE r: CASING /TUBING /LINER DETAIL Single Completion Assembly PHILLIPS Alaska, Inc. Remarks: WELL: RENDEZVOUS 2 DATE: 4/22/01 2 OF 2 PAGES DOYON 141 Drilling Supervisor.' R.W. SPRINGER/R. W. BOWIE ;~ PHILLIPS ALASKA INC. • TUBING TALLY PAGE: 1 of 3 WELL : RENDEZVOUS 2 NPRA RIG: DOYON 141 TUBING DESCRIPTION: 3-1/2", 9.3#, L-80, ABM-EUE, Non-Coated -Range 2 -Class A DATE: ####### Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 31.41 26 31.32 51 31.29 76 30.26 101 31.29 126 31.38 151 31.33 176 31.31 2 31.31 27 31.36 52 31.27 77 31.28 102 31.41 127 30.27 152 31.31 177 31.34 3 31.45 28 31.29 53 31.31 78 31.32 103 31.40 128 31.37 153 30.30 178 31.51 4 31.44 29 31.26 54 31.40 79 31.40 104 31.28 129 31.31 154 31.26 179 31.38 5 31.30 30 31.33 55 31.36 80 31.38 105 31.26 130 31.02 155 31.32 180 31.43 6 31.31 31 31.36 56 31.32 81 31.30 106 31.42 131 30.27 156 31.33 181 31.36 7 31.33 32 31.37 57 31.31 82 30.30 107 31.38 132 30.23 157 31.36 182 31.37 8 31.34 33 31.36 58 31.37 83 31.45 108 30.22 133 31.37 158 31.37 183 31.42 9 31.42 34 31.34 59 31.22 84 31.39 109 31.28 134 31.35 159 31.39 184 31.34 10 31.49 35 31.31 60 31.30 85 31.29 110 31.29 135 31.25 160 31.31 185 31.37 11 31.44 36 31.22 61 31.32 86 31.38 111 31.28 136 31.31 161 31.37 186 31.08 12 .31.36 37 31.31 62 31.34 87 31.28 112 31.41 137 31.29 162 31.77 187 31.36 13 30.10 38 30.10 63 31.28 88 31.31 113 31.40 138 31.30 163 31.33 188 31.28 14 31.31 39 30.98 64 31.35 89 31.29 114 31.24 139 31.33 164 31.22 189 31.35 15 31.37 40 31.35 65 31.40 90 31.28 115 31.27 140 31.34 165 31.30 190 31.39 16 31.40 41 31.46 66 30.57 91 31.36 116 31.35 141 31.30 166 31.35 191 31.36 17 30.30 42 31.26 67 31.44 92 31.37 117 30.26 142 31.28 167 31.34 192 31.29 18 31.38 43 31.28 68 31.31 93 31.32 118 31.40 143 30.17 168 31.33 193 31.35 19 31.33 44 31.37 69 31.42 94 31.37 119 31.28 144 31.44 169 31.27 194 31.37 20 31.37 45 31.32 70 31.38 95 31.35 120 31.34 145 31.23 170 31.25 195 31.41 21 31.38 46 31.30 71 31.32 96 31.36 121 31.41 146 30.28 171 31.35 196 31.32 22 31.34 47 31.31 72 31.34 97 31.33 122 31.36 147 31.32 172 31.36 197 31.39 23 31.38 48 31.35 73 31.32 98 31.43 123 31.27 148 30.33 173 31.43 198 31.35 24 31.34 49 30.31 74 31.42 99 31.36 124 31.30 149 31.32 174 31.35 199 31.32 25 31.31 50 31.40 75 31.34 100 31.42 125 31.37 150 31.31 175 31.47 200 31.37 Tot 781.91 Tot 780.62 Tot 782.70 Tot 781.58 Tot 781.17 Tot 776.37 Tot 782.77 Tot 783.82 TOTAL LENGTH THIS PAGE = 6250.94 DIRECTIONS: TOTAL JOINTS THIS PAGE _ 200 • ARCO ALASKA INC. TUBING TALLY PAGE: 2 of 3 WELL NUMBER: RENDEZVOUS 2 NPRA RIG: DOYON 141 TUBING DESCRIPTION: 3-1/2", 9.3#, L-80, ABM-EUE, Non-Coated -Range 2 -Class A DATE: 4/22/2001 Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 31.41 226 31.27 251 31.30 276 31.33 301 326 351 376 202 31.35 227 31.36 252 31.26 277 31.42 302 327 352 377 203 31.38 228 30.19 253 31.32 278 31.35 303 328 353 378 204 31.30 229 31.40 254 31.46 279 31.37 304 329 354 379 205 31.33 230 31.41 255 29.08 280 31.35 305 330 355 380 206 30.33 231 31.31 256 31.34 281 306 331 356 381 207 30.08 232 31.32 257 31.36 282 307 332 357 382 208 31.35 233 31.33 258 31.24 283 308 333 358 383 209 31.30 234 31.32. 259 31.28 284 309 334 359 384 210 31.36 235 31.35 260 31.33 285 310 335 360 385 211 31.37 236 31.39 261 31.34 286 311 336 361 386 212 31.31 237 31.37 262 31.32 287 312 337 362 387 213 31.33 238 31.29 263 30.26 288 313 338 363 388 214 31.40- 239 31.44 264 30.35 289 314 339 364 389 215 31.50 240 30.66 265 31.36 290 315 340 365 390 216 31.37 241 31.39 266 31.30 291 316 341 366 391 217 30.33 242 31.37 267 31.51 292 317 342 367 392 218 31.45 243 31.28 268 31.23 293 318 343 368 393 219 31.43 244 31.34 269 31.36 294 319 344 369 394 220 31.32 245 31.39 270 31.37 295 320 345 370 395 221 31.34 246 31.35 271 31.29 296 321 346 371 396 222 31.35 247 31.26 272 31.22 297 322 347 372 397 223 31.38 248 31.28 273 30.23 298 323 348 373 398 224 31.34 249 31.37 274 31.34 299 324 349 374 399 225 31.40 250 31.29 275 31.46 300 325 350 375 400 Tot 780.81 Tot 781.73 TOTAL LENGTH THIS PAGE = TOTAL LENGTH = 8748.21 TOTAL JOINTS THIS PAGE = TOTAL JOINTS = 280 Average Jt = 31.24 Tot 777.91 2497.27 80 Tot 156.82 Tot DIRECTIONS: Tot Tot Tot L3-5/d' BORE - SK 3.CMM DIESEL-FIRED HEATER 3 PHASE SEPARATOR 92MMSCF/D VERTICAL GAS SCRUBBER--tOSMMSCF/D $AND REMOVAL CYCTEM E16NC- UPSTREAM [pIL PRESSURE 5N CUNTRGL SYSTEM- PNEUMATIC VCSSCL OESI6N PRESSURE I41p PS] VESSEL OCSIGN PRESSURE 1A9p PSI Ri !00'F '.BVNSTREAM--2N, 4' 1NLCi, puiLEi, OYPATS Spun SERVICE ASME SEti. Vlll SPUR SCRV]CC. ASNC SECT. YIII ',9 UPSTREAM Cp]LS / 12 -pVNSTAEAM LLILS 12%IS 16A00 BBL/-AY 36% ]p 8000 BHLS/MY ~ I I, " rvUMINAt CHLKE--P~PYLExC GLrLLL HATH r w: is - ~~ ~ x - ~ - ~- ~~ ~ 3' HI RELIEF GAS i • tp Mt, _ t_ P Ww FAd IgBI Rtp Y ~ -.. ... ~ It1xaM. p A[I ? Y 4X gw ~~~ '~ ~~~ HS)D SCfM rs ', 1 U~V.tt SSV MTA sN 160 v~H 1m1~01v.1 [S~'~ J ~ ~ ._~ ~~ STAAIGx H Mr fLAV rte:. rv Av[ P[V ro ev rv K 3' HI s w '~"~ • x[LYIOx ~ ~ nlx0 ~ Lv[ P ~ L .1.~ w 3 ~, ~ n ,Pe L ` 3L PxmxAnt ~ ~ H e < GAS $w : A ~ _. wLAw RA [x r .: ,. +. PI . ,, : v: K H r A ss ATSV/n ,. / 000 ~--loa, T,~T-~~- ryiUT ..._._._.r, _ _ ~ , ' a -v _ _ - , 11,0 nl • 3' SM IOx RCCCOVCR ~ SUPn~ 3/2' NV By < ,. 4-1/16' SK SURFA..E TREE s ils•~wros~A "~II LANK m„ vP ^'~% ~ ~ p x.Ar[[ ~ ~ ~ '1 /IV S[ ~~vld~ ~ v MAInvsPARGINC NE Lv g z• zK ~ n PI PLe eP r 1 i ~ ~ 5x ~ 10H0/SO I'„ , LL HV k:) " - ,.w P Ilfo PSI j 1 4sn;Xp¢ X 1 ISM m q. CC SM, ~0. r Lv % ~dpa E CA451M MASIMUM PRESSURE E%PECTE- ~ r I 10H w91i1K ~-~ ~ M~ 1 As 1 xrv OO A 1 FRNVLL ~.uF[Al[ U9r4 1. VCLL „Ilx ~5 C0.1Mt HH00 Pdl ~ pV LV T ~ f Rv« Ix L ~X- ~ 1 [se " MAKIMUM ExPCCTEB RATES I rrcC ~rox Noo rae n4[ Nx a n x s~ V LV E cnoA[ 2 4,5 AO xASf[N vKVE--ME TI[ { i 4v 4v I ~ nEAtER HA,. Ch 4 - YE 65 BHLS ~ 2 PI IFDA `RVN~ .g__0i.? P n u y Td!. v aAlx LCm ayG ` I (L ~ 4 uvL~itw. m ~ :'r n 1 - _ ~ AOBC v 1 mm G R' V ~~ A,re1SPgM ®,o w~M'~'°' S1 Kd ~ R mvx g~ v n xpmc [ r.w sn i ~ r rLwpa ~ r riv~ '. vµYLl I v HRAIx l w x _ V ''...._. w ,r ~ pi[S[t ~*~. nY ~ u R HuAx3 CwSipx XeDg9 '' O '~, Hi 0 Ew SExIllls I]Op HPO i,L -_ ~ ~, ~ 10a SW VO 'BH !~ N # a L_~ D~7I tCRHy~~~F-y~[O'i' V . .-may -.._. ~_ I '/ M --.%- ~ ivx I , Y \~ ^'~m~ lyd I t.x, a '. u ~ ~~ ~l '4N _ ,1, v[XI 10 "H T H HON 13A00 NC rz h A nIxLS=x[R[ VERTICAL GIL SCRUBBER--SDMMSCF/D i d$HMr--rLwh ~~'~ L ' SAND uxE oRAlx '~ l "~ VCSSEL DESIGx PRESSURC t410 PS] R1 100'f Tp TAM( Lv ~'~ "~ j m _V_-~ Ziq SDUR SERVICE RSMC SCCi. Vlil (( " o ]6H{0 8000 BBLS/DAY 3' HI GAS r rv H J H ~""V ttuuce 2' % ]~ 3' 8gy Hv~rL ~, NIL/WATER ova OIL/WATER PRIMARY STORAGE TANK FARM LO RELIEF q nwaL STORAGE TANKS (•U TN TANK PH M rA x ATMOSPHERIC 400 HARRCLS MAIIYLM CAPACITY 400 BBL STCPAGE TANK RATED AT Ifi OZ. (21 pZ. [MERGENCY pNLY1 PRESSURE sreAl~r[plw r /rv ipTAl MR%IMUTI LRPAGITY- 1600 BARRELS MAKIMUN VENT CAPACITY pF 6', 6 pi. HAILM - 3.2 MMSti/0 (173.96 SCf/xJ nH 3' HI GA$ IpiAL ACTUAL CAPAITY- 1280 BARRELS H' H1 GA$ uPMnr ' ~ ~ 3' LO 6AS 3' LO GAS H.sHX srsrx' r[ 'v s[( Ar } 1• x H• ruv vst ~_-_..;,_._....;~, e, A d, ^ C] uu PIPIw Is xtu [4AL[e „ ', x•-a ox s-e M .w rxvAAr[n w l.r« rwru _' (o ~rbsvxia CAPACITY lpp can w Am aeL T[i AT 9p PnL xU Cp°KI[Y MAH m.«m N (1 r Isn ~ ~ ~f ~ ~ ~ oc+Ix iL4~ Lei dwx f°° rxl 1 I ArvIGQp 0.'S ~PLp5tt0 [IDD' FLARE STACK W1TH MARDAIR TIP ADNMSCF/DAY CAPACITY CACH7 N I N [V~ ~ ev - N N N S[CVgA-Y rM[ fMN I mL II PI Lp ManlfpL- sx I I r ~ ~ ~ ArE rs .o .NN >, I gN ALAI rRPxs[ER PYP .M ~>,~,p[ ~ Pta xlw,[ ,„~„~ ~Ar[I ~ILwrAOL^slwnr _ I 'CJ p ~~ L __uApp HPH 1 ev~e~v '.~,. Lmo !r:o I vwi (p 'T - ~ Alxovx[R[ v eV I ev ~ o~wue HX ~ rev ~ a[vrzu[e _... _._. i Ix a, I ":fix q '. evil o,`r... B'~,p r repo[ ux 3' LN GAS .V ~.] T t L~ x E 4 P 1504 p C} [Le i L/WATER ip,xX v[Nt Aw v[xtEOw CRPACITY 400 6PMSv "m sM« s[t At 9p Ps]c [NNTE~ NIL/WATER r 1 L% UNITS TG 8' MANNED 24 HDURS/DAY DPEN TOP • 602 zN Lp AEUEf Z36 HHl RELIEF TAW( xa [MwIIY x,X [MACitt L ' HY E%PRN QUALIFIED PERSONNEL] e'-e ~ ^ ^ NOTE' [THIS VALVE WILL BE LOCKED I NUT ~ O R C ~ N S T I~ U C T I U N UNLESS ERPNRTING NIL7 HArwfs vaL BE pPEx ~ YwLE icsnxc i SECONDARY TANK FARM IS FOR STORAGE PURPOSES ONLY I~ COMMODITY ABBREVIAT]~NS LEGEND I ev aRV.H, e't a~ ~1~-fiCev7, --~i~ Cy4Lla~ HB BLw -ovx Ao AIP pneArze x nuts[ AIP ra' ~ 1 I ~lm ~ I~1~-~-IEw~e ev X HFV HmL[A fEE- vAr[R Aolo Iq~lrmp rILO[ ,v r[~r vas ~N ~N ~HV ~rv ~N ~N ~BV Hv~ BV ~ev 4R- CLLSC- AMINE BRAIN [ApO SCRLVOP[X :e ~iTev N T rv cv T CB ttps[- -AAIN aCa vKV[ cns WI pl1 wrT Ox MI _ CH LOELC%IP NGSE -I[[ R[f G[x OIL -- I LSL GAR SCRL CLUiC- [spa CIfAGC1CY SNISOWN HVIr[x VATER 0 ~ ~ () rA FLAxE Aaw91[A r [xl[T OP[gw ]' IxIU OPENp6 )' [qU W[xp6 r rqU W[xAp :r LqU pPFNiw r [qti pPExlw ~ CSp CM SEAL OPEN xL[ x101 L[V[L LIMP SNn Ix AIR 'P"."""""'--- CSV- CLp$C- SUUR V4:ER pRAIN ABBVC LRBUNB w5p xIW L[v[l SWi OWx _ _ _ ^ ^ r ^ ^ ^ ^ - DRRIN xo51 NION PB[SSLNE SWI Ix Ilw Pfl RELIEF V ~-A~ .V EMS ENTRA NIGH PRESSUAC STEAM (OVCR 300 CBS) " xIW TGIF Cpx1A¢LCA '~ qW 1[IPCAANAC 9rU1 pOYN METHAN[L w<xrH LO ,L~ra'A[ IgSR( xOSACA[ xl[O ES-S EMERGCNCY TXUippVN $VITCH IMAVUAI) "[5p l1RJl- LOx[A0.[B ESOV EMERGENCY SHIITWVN VRLYE L[v LIMIO mireu vMVE ~ 1[wAPKa[ ~ rO irz[MAS ~ ~Id 9h PnEe[ li MAI I[r i x,e CwdLlix MY I.r '~ WJ [xNtl~r wx IwALIIY x+d weM1IY I CG NEL GAS IIRJIp sILM GLASS Cu G]AE VATER LM L[vp LIMO SM p I ^ ^ ^ ^ ^ ^ G LLYWL a L¢a-Nt rAA-pln LOV Pa[ssuc sun Ix lw P[I 6DR STYLE HAw.ER UNIpN 2N YP HL HIGH PRCSSUAE STEAx L:N~CN;ArE LN rz,P Lpgwu[A L ~. NIGN PRESAIAE SIERx LN mxOLf vAiv[ 1502 STYLE HRMMER llN]pN ION VP HS i 'A INSTRIIMENi ^Y H ~~ ~ I AIR Pw suH[iLa Pr TPR ' _ , yr F' _ x CxEM]CAL ----.1 L _.._____. __ r ___ _._. _,. ,.. ~U PACHOBAE [o.'rR0. AF9AA[pH r vixr uA ~ rc.~uK ~ nw. urr, , .i., wL > nv vK x LC LUY PRESSUAE S1EAM LIINp[Nin'E PAFS9JHt LpxixpL vALV[ pWS UILY VATER GRAIN BELUV LRA.E Pa[SSOA[ INHILAIW LS EGV PRCSSURE SIEAX PRS9ltlft'A[[Oette NS MC-IUM PRESSURE SCAM PItSSLRC YMW PHSSIH S[xSpR xl4x/LW P PRGCCSS Piv PR[SSUA[ sw[iY v,LV[ T 1A6(i- O[ Mtx [dwOSl SECON-ARY STORAGE TANK FARM sA nARnw AIR o1 o~LBr w,[x UA UIILiTY nIR Rd R[6pLArw SipRAGE TANKS (6) rl rzW Ix01[ArW RTNpSPKRiC- 512 BARRCL MAKIMLM CAPACITY rmAL HAxtxuM rtw- cAPALIrr- 31]z eARRELT TpTRL ACTUAL FLUID CRPACITY- ],088 BARR(LS H~cWR ` ce CONOCOPHiLLIPS ALASKA IE'C. HL51~xPRN RENDEZVOUS 2 CHAR pAl[I za 2007 SPARK DD PPRpvAt vT~auo~u o[aE~:,^5~^'I [ REVISWx O[F[RlPrlpn R[vISIOx ¢s.PIPr IBx E NGNE ~ RIG PAD LIM17S r soz~-LO ras io rLavs l• 5o2--xl LPS i0 fLU4[ CANII/RGI IGf TANK 6x x PO' x 30'x rHniof xHZOlxiio xrRN GENSEi f~f Nfli FRRN 50' i 24' x 20'x SAN- Rt~SiFR Fi RM 20'z20'x.Or CAMP ~ HCAiER ~ IO iE$i E~UIPMENi BERN PRIMARY TANK EARN I~~' Y 6D' x 2px 7RRNSPOR7 AREA BERM 60'x 20'x 20'x 35' ICE RDAD ,~~ ~. e e r~ I;,,· ""~', ., \:'~.. ~""" '¡~ MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: \LascrFiche\CvrPgs _ Inserts\Microfilm -,Marker. doc Re: Trailblazer A-I & H-I reviews Subject: Re:Trailblazer A-I & H-l reviews From:. John Nonnan <john_norman@admin.state.ak.us> Date: Tue~ 24Aug 200416:39:18..0800 To: jim- cowan@dnr.state.ak.us CC: JeffLandry<jefLlandry@law.state.ak.us>, Julie Houle <julie_houle@dnr.state.ak.us>, Don Krouskop <donJcrouskop@dnr.state.ak.us>~ Don Brizzolara <don_brizzolara@dnr.state.ak.us>, Howard D Okland <howard_okland@admin.state.ak.us> Jim, In addition to data on the two Trailblazer wells, any additional well data you would like to review will be made available to you provided it is no longer confidential. Does this adequately answer your question? John Jim Cowan wrote: John, I've just received the fax of Conoco's 8/23/04 letter to you requesting, among other things, that Division of Oil and Gas staff not have access to confidential information from other wells in the NPR-A. This comports with our understanding of appeal protocol. However, during our review of well information prior to the initial showing and denial we also reviewed information from the Spark #1, the Moose's Tooth C and the Rendezvous #2 & #A wells and might ask to do so again if our division files for these wells are lacking. I We will not seek access to information acquired subsequent to our initial I review and decision to deny extended confidentiality for the two Trailblazer wells. Jim Cowan )ùl -007 John K. Norman <John Norman~admin.state.us> Commissioner Alaska Oil & Gas Cæservation Commission I of I 8/25/2004 8:35 AM FW: Disclosure of 6 CPAI wells approved Subject: FW: Disclosure of 6 CPAI wells approved Date: Thu, 26 Jun 2003 10:16:06 -0800 From: "Jim Cowan" <jc@dnr.state.ak.us> Reply-To: <Jim_Cowan~dnr. state.ak.us> To: <sarah_palin~admin.state.ak.us> CC: <Steve_Davies@admin.state.ak.us>, <Howard_Okland~admin.state.ak.us>, "Mark D. Myers" <mdm~dnr.state.ak.us>, "Bonnie Robson" <br~dnr. state.ak.us> Sarah, Steve and Howard, As follow-up to the message below, CPAI's land manager confirmed today that the only wells subject to appeal are the two Trailblazer wells. The Nigliq 1 & IA, Spark IA, Moose's Tooth C, Rendezvous A & 2 may be disclosed immediately. Thanks Jim Cowan Manager, Resource Evaluation Division of Oil and Gas 269-8765 ..... Original Message ..... From: Jim Cowan [~_~.~.i.~...~_~_~_~_~.~.~.~.~.~..~.~_~..:~.~] Sent: Wednesday, June 25, 2003 4:05 PM To: sarah_palin@admin.state.ak.us Cc: Steve Davies@admin.state.ak.us; Howard Okland@admin.state.ak.us Subject: Disclosure of CPAI Trailblazer A-1 & H-1 wells appealed Sarah, Steve and Howard, The DNR received the anticipated appeal from ConocoPhillips regarding the Division of Oil & Gas' denial of extended confidentiality for data from the Trailblazer A1 & Hi wells (NPR-A). That denial was issued on June 5, but release was delayed until tomorrow, June 26, so CPAI could utilize the 20-day notice-of-appeal period to formulate its position. The AOGCC is copied on the appeal letter and may have already have reached you. Consequently, we ask that you do not disclose confidential information and data from these two wells until we notify you that the appeal process is complete. Appeals of the similar denials for the other six wells are also due today, but have not yet been received. If we hear nothing more from CPAI I'll notify you in the morning that you may proceed with their release effective tomorrow, June 26. Thanks Jim Cowan Manager, Resource Evaluation Division of Oil and Gas 269-8765 FRANK H. MURKOWSKI GO VERNOR DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS 550 WEST 7TM AVENUE, SUITE 800 ANCHORAGE, ALASKA gg501-3560 PHONE: (907) 269-8800 FAX: (907) 269-8938 CERTIFIED MAIL #7002 0860 0003 3538 7846 RETURN RECEIPT REQUESTED June 5, 2003 Richard P. Mott ConocoPhillips Alaska, Inc. Vice President, Exploration and Land P.O. Box 100360 Anchorage, AK 99501-0360 DECISION OF THE DIRECTOR R'e: Request for extended confidentiality Spark 1 A, Rendezvous A & 2, Moose's Tooth C Dear Mr. Mott: JUN O 9 2003 Alaska Oil & Gas Cons. Commission Anchorage I am responding to your April 10, 2003, letter to Commissioner Irwin in which you requested, on behalf of ConocoPhillips Alaska, Inc. (CPAI) and the working interest owners, extended confidentiality under 11 AAC 83.153 for the Spark lA, Rendezvous A, Rendezvous 2 and Moose's Tooth C well data, reports, and information filed with the Alaska Oil and Gas Conservation Commission (AOGCC). Originally scheduled for release during May 2003, the Division of Oil and Gas (Division) temporarily extended the confidentiality of this well information until June 6, 2003, to allow CPAI to make a showing that the information is significant for the valuation of unleased land more than three miles from the wells. CPAI presented the information to the Division on May 29, 2OO3. CPAI requested that the Division authorize extended confidentiality for information derived from these wells until 90 days after the next federal NPR-A oil and gas lease sale (tentatively scheduled for mid-2004) or until the Bureau of Land Management rules that disclosure is appropriate (upon lease expiration or with earlier consent of the lessee), whichever first occurs. As you know, 11 AAC 83.153(a) provides that the commissioner may extend confidentiality for well information if the well is located more that three miles from unleased lands. 11 AAC 83.153(a) states, in part, "The commissioner will, in his or her discretion, extend confidentiality to reports or information required under AS 31.05.035from a well located more 'than three miles from any unleased land if the owner of the well from which these reports or information are derived makes a sufficient showing that the reports or information contain significan, t information relating to the valuation ofunleased land beyond the three-mile radius." All wells subject to this request are more than three miles from unleased lands. "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." Having considered the information provided by CPAI, the request for extended confidentiality of reports and information derived from the referenced wells is denied. The reasons for this denial include, but are not limited to: · While information from the wells is significant for evaluation of surrounding leased lands it is not significant for evaluation of unleased lands eight and more miles away and for which the applicant failed to submit bids in the June 2003 NPR-A lease sale. · Information from the Spark 1 well, the "mother" borehole for the Spark 1A sidetrack, has been released to the public. · CPAI disclosed in a press release dated May 21, 2001, that the Spark 1 and lA, Moose's Tooth C and Rendezvous A and 2 wells all targeted the Alpine producing interval and that all encountered oil or gas or condensate in what was believed to be three separate accumulations. · The same press release disclosed test information germane to the Spark 1A and Rendezvous A wells. · Long available to the public are the data and information from exploration wells drilled by the federal government during the U.S. Navy and U.S. Geological Survey NPR-A exploration programs. A number of these wells are located in the unleased areas used by the applicant to justify the requested extension of well confidentiality. Hence substantial information regarding the petroleum potential of these unleased areas already exists in the public record. By copy of this letter I am advising the AOGCC to release reports and information from the Spark lA, Rendezvous A & 2, and Moose's Tooth C wells on Friday, June 6, 2003, upon expiration of the previously granted temporary 45-day extension. A person affected by this decision may appeal it in accordance with 11 AAC 02. Any appeal must be received within 20 calendar days after the date of"issuance" of this decision, as defined in 11 AAC 02.040(d) and (d) and may be mailed or delivered to Mr. Tom Irwin, Commissioner, Department of Natural Resources, 550 W. 7th Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1-907-269- 8918, or sent by electronic mail to dnr_appeals~dnr, state.ak.us. This decision takes effect immediately. If no appeal is filed by the appeal deadline, this decision becomes a final administrative order and decision of the department on the 31 st day after issuance. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court. A copy of 11 AAC 02 may be obtained from any regional information office of the Department of Natural Resources. Sincerely, Mark D. Myers Director Cc~ Sarah Palin, Commission Chair, AOGCC Jeff Landry, Department of Law Mike Kotowski Jim Cowan ~KA 0IL AND GAS CONSERVATION C0~SSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 16, 2003 Mr. Richard P. Mott Vice President, Exploration and Land ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Requested notice before disclosure to DNR Dear Mr. Mott: When ConocoPhillips Alaska, Inc. ("ConocoPhillips") submitted to the Commission the data required under 20 AAC 25.071 for wells Spark lA, Moose's Tooth C, Rendezvous A, and Rendezvous 2, you asked the Commission to notify you before the' data are disclosed to the Department of Natural Resources ("DNR") or the public. We understand that ConocoPhillips has applied to DNR for extended confidentiality for these wells under AS 31.05.035(c) and 20 AAC 25.537(d). DNR has informed us that it would like to review these well data at the Commission's offices on the afternoon of May 19, 2003, for the purpose of determining whether to grant the application for extended confidentiality. It is our understanding that DNR has the authority to review such confidential well data for that purpose. See 1984 Inf. Op: Att'y Gen. (661-84-0523; July 3); State, Dep't of Natural Resources v. Arctic Slope Regional Corp., 834 P.2d 134 (Alaska 1991). In light of your request that the Commission provide you advance notice in these circumstances, we are providing you this notice as a courtesy. Randy Ru~edrich, Commissioner Alaska Oil and Gas Conservation Commission CC: Jim Rudd, ConocoPhillips (mailed and faxed) Barbara Fullmer, ConocoPhillips (mailed and faxed) Paul mazzolini, ConocoPhillips (mailed and faxed) Richard P. Mott, ConocoPhillips (mailed and faxed) John Bridges, Anadarko (mailed and faxed) SD \RR/jjc Re: [Fwd: Request to inspect NPR-A well data] Subject: Re: [Fwd: Request tdmspectN:PR-A welldata] From: "Rob Mintz'" <Robert Mintz@law.ståte.ak.l1s> Date: TIm, 15 May 2003 16:52:50 -0800 ro:,c;;:steve_davies@admin.stat~.~,~s>:," ,:'i,<;~:'f:.:~:: .. , ': '::~" , "", :'~:.. ,,:.., ' ; ..~;.' ',0:,..; Steve, is this the same thing you e-mailed about yesterday? Subject: Re: [Fwd: Requesttoin$peêtNPR-A weU~ta] From: "Dan T. Seamount" <Dal1_Seamollnt@admin.strite.nk.us> Hate: Tim, 15 May 2003 15:09:54 -0800 To: Sarah Palin <sarahjJali~1@adl~in:~,ate,ak.\Js>, RobMil1tz <Robert..:.MintZ@law,~tate.ak.us>',' CC:Ran4o1ph A Ruedrich ~$~gy~rue4d,C9@Q.ðmtg;~t~t,~.~1<.,~~>, '. ',>,¡¡':J;/.!:;iy\ ~ ~, . :"" " ok by me. Sarah Palin wrote: ------------------------------------------------------------------------ Subject: Request to inspect NPR-A well data Date: Wed, 14 May 2003 15:56:52 -0800 From: "Jim Cowan" .:::.1~<íJ!9!~E..:.~~-9:,!=.,~:_¡;¡_J<:_:.:l.:l..~,~ Reply-To: .:::..g-~~çSJ_wan@d~_~tate. ~J<:_~-~s> To: .~.~~E~h-pal :h~.<íJ!.¡;¡_cì.!!1iE.:_5'ta!=..~_~,~"':_ll~~. CC: "Mark D. Myers" .:':!1.1.<:l.!!\.<íJ!gnr...:_~,!=_i'i..!=.!':..:..~~:_\.:ls>, Good afternoon Sarah. ConocoPhillips Alaska has applied to the Division of Oil and Gas for extensions of the normal 24-month confidentiality period for eight wells, six of which are within the NPR-A. At Mark's request (and as is the Division's normal procedure), ConocoPhillips will be presenting their case to the Division next Wednesday. Inasmuch as the well data are archived only at the AOGCC and in order to prepare for CPAI's showing we would like to review the well data on your premises on the afternoon of Monday, May 19. This is to avoid having only the applicant's "spin" on the significance of the well data and information when arriving at our determination. This represents a rather recent and advantageous change in protocol between our two agencies and is the result of consultations between our respective attorneys, Mintz and Landry. I believe it's the first opportunity we've had to take advantage of it. With your approval I'll work out the details with Steve Davies. The wells of interest, but for which we have no information, are: Trailblazers A-1 & H-1 Spark 1A Moose's Tooth C Rendezvous A Rendezvous 2 Nigliq 1 & 1A are also on CPAI's list, but we have all appropriate data for those and need not review AOGCC files. Thanks for your help. Jim Cowan Manager, Resource Evaluation State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Ave., Suite 800 Anchorage, AK 99501-3510 ) of2 o/] \,O )Ð ". '¡ . ..' , 8/11/20044:59 PM Re: [Fwd: NPRA wells in question are. . .J Subject: Re: [Fwd: NPRA wells in question are.. .J' From: "Rob Mintz" <Robert_Mintz@law.state.ak.us> Date: Wed, 14 May 2003 15:44:28 -0800 To: <steve,:" davíes@adn~in.statè.ák:ùs::>,',. :; ," , "'" : ," What's the deal with CPAI "showing" to Mark? I am guessing that means CPAI has requested that DNR grant extended confidentiality for these wells and that they are approaching the end of their two-year confidentiality period. If that is the case, and the purpose of the review requested by Jim Cowan is to assist Mark in making the determination whether to grant CPAI's request, then I don't see a problem. Otherwise we should talk about it. . Steve Davies <s~,~,Y~_s!9:Y-,!_~..ê,@a_Sl.!T!~-=_st:.~,!:_~~-~~_:_:t:I,~,::: 05/14/03 03:15PM »> Rob: Jim Cowan wells as described their staff to requests to view all files related to conhfidential below. Do we have an agreement with DNR that allows view confiedntial data? Thanks, Steve Davies 793-1224 ] of] A 1\ w ~ t: 1.Q:1 """,;': :. 8/] ]/2004 4:58 PM Re: NPRA wells in question are. . . Sltbject:Re: NRRAwells in questìòífáte;;... FröriÙ Steve DãYie$<steve- davies@admin.state.ak.us> Date:,Wed,14 May 2003 1?;17:31 ~080Q~u. :.."'..:.,.... )~~ ::. ,....':' ¿;'ot.?-;PCJ7 ,:.:.. To: ~imlÇo\V~n@dnr.state.~k.1Ìs':.~¡;~~~:!:;: ':::~!)~:i\,¡:. ::',f::'I'~i~~¡~~~~i'r~';p;;,:,~¡: :,;, ::.:;¡;¡~~~:; ,,':'1<:< 'i¿::.;:\:~::L;:::.~:i'~~1'~:>:;';~:'::::"\, Jim: A formal request though Sarah Palin is the proper procedure. I have a call in to Rob Mintz about this. I have booked the small conference room for next Monday afternoon for your use if the request is approved. I'll let you know what Rob says. Steve D. Jim Cowan wrote: Trailblazers A-I Spark lA Mooses's Tooth C Rendezvous A Rendezvous 2 & H-l I'd like to bring Krouskop, Brizzolara and Houle over about 1:30 Monday afternoon, 5/19, for a quick cruise though the well files. We don't want to take anything away except our notes so would just like a room to work in that afternoon. CPAI is making their "showing" to Mark about 11:30 Wednesday morning. What's the proper protocol? Handle it through you, Jack and Tom or submit a more formal request through the Ms. Palin? Jim Cowan 269-8765 1 of 1 8/11/2004 4:58 PM [Fwd: NPRA wells in question are. 0 oj SubjeCt: fr\vct: NPRA. wellsin From: Sieve Davies <sleve_davies@admin.state.ak.us> nl1tc: Wed, 14 May 2003 15:15:18 -0800 ~o: Rob l\1intz <Rob~rt-,Mi~tz@la~;~~~J~~~~.;P$>i:~;<:. ';;;C/-:--¿' 07 '\:"::,Ù/;::,',:'~i::;Y~~:!;!",::.:,:\Yu',' ,', " .' , ' ".,<~~:,;,~ '"~I Rob: Jim Cowan requests to view all files related to conhfidential wells as described below. Do we have an agreement with DNR that allows their staff to view confiedntial data? Thanks, Steve Davies 793-1224 Subject: NPRAw~llsjnqu~stionare.., Frolll: "JiniCowan" <jc@drir.S(¡jteoak.tis> Date: Wed, 14 May 2003 13:56:30 -0800 T():<stcve_davies@admin,..~tate.akll~?r.:'y,:t;~é(ik;:~;~Ù~~~,~,;,'f~~\';":,::;.,',,, '::.:,:' .,' , ~: : ::; :'::'-':',:, ',i:-,""', "" Trailblazers A-I Spark lA Mooses's Tooth C Rendezvous A Rendezvous 2 & H-1 I'd like to bring Krouskop, Brizzolara and Houle over about 1:30 Monday afternoon, 5/19, for a quick cruise though the well files. We don't want to take anything away except our notes so would just like a room to work in that afternoon. CPAI is making their "showing" to Mark about 11:30 Wednesday morning. What's the proper protocol? Handle it through you, Jack and Tom or submit a more formal request through the Ms. Palin? Jim Cowan 269-8765 Content-Type: message/rfc822 . NPRA wells in question are. . ..eml Content-Encoding: 7bit toft 8/1 1/2004 4:57 PM NPRA wells in question are. . . StlbjeêhNPRA wells inquestionare.. . Fróm:."JímCowan" <jc@dnr.state.akus> Date: Wed, t 4 May 2003 13:56:30 -0800 . 'i>b>ð);'î:J'f:77 ' , , T ......t -'ft' @'dm"""t"'t'i'ak';"";:"";:" "'~"~i"!IIi."'>""""""""""':'::"¡:"':"""i"""";"::,\,:,,.:;,;,~,,,,~.:--,.. :"" .,!,t""".',,';.""'; ,o:.-..!i:t;,V"e~V1el;", "a""""",J,nisae. .u""",,""";¡:,"!",,,"'>'~""!'1:,,;.;i;t".':'!"\"~"','",l"';'r.I"",';'~"t;f~,'("~,"",',-,ì',"',',i:'.,',;'~:>{",":"o':!,':;,¡'~"::'~":1¡,1,i',":~'¡':"i!,,'i~,.I"'!";',"'::t'~'\';,'.¡JI!.":¡"":"'"',, ,..",1'1"""'""""'" ",.',"'".. ";""0,:,.",.,'"""".."','1""',.,';',,.,',,,,,",,,,,."":",':..'.'..;~':"':",'è~",,,',':,':"'1".'\,:"',,,:,",' :K, Trailblazers A-1 Spark 1A Mooses's Tooth C Rendezvous A Rendezvous 2 & H-1 I'd like to bring Krouskop, Brizzolara and Houle over about 1:30 Monday afternoon, 5/19, for a quick cruise though the well files. We don't want to take anything away except our notes so would just like a room to work in that afternoon. CPAI is making their "showing" to Mark about 11:30 Wednesday morning. What's the proper protocol? Handle it through you, Jack and Tom or submit a more formal request through the Ms. Palin? Jim Cowan 269-8765 10f1 RIJ 1/2004 4:'i7 PM FRANK H. MURKO Vr'SKI GO VERNOR DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS CERTIFIED MAIL #7002 0860 0003 3538 7778 RETURN RECEIPT REQUESTED 550 WEST 7TM A VENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE:(907) 269-8800 FAX: (907) 269-8938 April 21, 2003 Richard P. Mott ConocoPhillips Alaska, Inc. Vice President, Exploration and Land P.O. Box 100360 Anchorage, AK 99501-0360 DECISION OF THE DIRECTOR Re' Requests for Extension of Confidentiality under 11 AAC 83.153 Nigliq 1 Nigliq lA Trailblazer A-1 Trailblazer H-1 Spark lA Moose's Tooth C Rendezvous A Rendezvous 2 50103203700000 50103203700100 501032036400 501032036900 501032031301 501032031500 501032031600 501032036300 I am responding to your letters of April 9 and 10, 2003, requesting extended confidentiality under 11 AAC 83.153 for well data, reports and information generated from the eight referenced wells and filed with the Alaska Oil and Gas Conservation Division (AOGCC) under AS 31.05.035. For wells more than three miles from unleased land, as is the case here, 11 AAC 83.153(a) grants the commissioner discretionary authority. 11 AAC 83.153(a) states, in part, "The commissioner will, in his or her discretion, extend confidentiality to reports or information required under AS 31.05. 035 from a well located more than three miles from any unleased land if the owner of the well from which these reports or information are derived makes a sufficient showing that the reports or information contain significant information relating to the valuation of unleased land beyond the three-mile radius." Inasmuch as all wells are more than three miles from unleased lands, confidentiality for the eight referenced wells is extended for only 45 days from this date (through June 5, 2003) during which time the Division of Oil and Gas will require a showing to establish the significance of well data from the referenced wells to unleased OCS and NPR-A lands and to state lease ADL 390348 which is due to "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." expire September 30, 2003. The showing should be scheduled prior to May 30, 2003, to allow the Division to make a decision by June 5, 2003, regarding further extension of the confidentiality period. Extended confidentiality for the remaining four wells for which you requested extended confidentiality (Hunter A, 501032040500; Lookout 1, 501032035900; Lookout 2, 501032041000; and Mitre 1, 501032040900) will be reviewed prior to their 2004 disclosure dates. Please submit that request on or about March 26, 2004, so that the significance of the well information can be evaluated in the context of activities up to that time. By copy of this letter I am notifying the AOGCC of the 30-day extension of confidentiality for the eight referenced wells. A person affected by this decision may appeal it in accordance with 11 AAC 02. Any appeal must be received within 20 calendar days after the date of"issuance" of this decision, as defined in 11 AAC 02.040(d) and (d) and may be mailed or delivered to Mr. Tom Irwin, Commissioner, Department of Natural Resources, 550 W. 7th Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1-907-269- 8918, or sent by electronic mail to dnr_appeals~dnr, state.ak.us. This decision takes effect immediately. If no appeal is filed by the appeal deadline, this decision becomes a final administrative order and decision of the department on the 31st day after issuance. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court. A copy of 11 AAC 02 may be obtained fi.om any regional information office of the Department of Natural Resources. Mark D. Myers Director Cc.' Sarah H Palin, Commission Chair, AOGCC JeffLandry, Department of Law J. R. Cowan, Division of Oil and Gas DATA SUBMITTAL COMPLIANCE REPORT 411612003 Permit to Drill 20t0070 Well Name/No. RENDEZVOUS 2 Operator CONOCOPHILLIPS ALASKA INC MD 8650 'rVD -864ra~ Completion Dat 4/28/2001 J Completion Statu SUSP Current Status SUSP APl No. 50-103-20363-00-00 UIC N REQUIRED INFORMATION Mud Log __-Ik~-o~- V'JJ'¢..` Sample Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type ~ Fmt (data taken from Logs Portion of Master Well Data Maint) Name Log Log Scale Media Run No Interval Start Stop OH I Dataset CH Received Number Comments ~nal Well Report Ultrasonic Imager ---F-efmation Log 10231 10230 Core analysis Core Results ~ ~/~,) ~OP/D Gamma /j~O 2/5 Ray/Re.s 'DGrR/Acoustic Tool 2/5 '-[~'~'R/Ne u/Den 2/5 8309 8368 Open 108 8650 Open FINAL ch FINAL 6000 8410 CH FINAL 200 8650 CH FINAL 108 8650 ch FINAL 8309 8650 oh FINAL oh FINAL oh FINAL 108 8650 oh Fl NAL 108 8650 Fl NAL 108 8650 oh oh 8/8/2001 q-0230 8/8/2001 ~31 5/25/2001 6/11/2001 6/11/2001 8/8/2001 ~1231 8/8/2001 1923~ 8/8/2001 8/8/2001 8/8/2001 8/8/2001 8/8/2001 8309-8368 108-8650 Final Well Report 6000-8410 Color log, Sepia 200-8650 Formation Log 108-8650 Digital Data (} 8309-8650 Digital Data Core Analysis Report Core Results Report 108-865O BL 108-8650 BL 108-8650 BL Well Cores/Samples Information: Name ~ Start Interval Stop Sent Received Dataset Number Comments /Core Chips ADDITIONAL INFORMATION Well Cored? ~ N Chips Received? ~ N Analysis ~ N R P.r~.iv~.d 9 8309 8368 Daily History Received? Formation Tops Permit to Drill 2010070 MD 8650 Comments: TVD DATA SUBMITTAL COMPLIANCE REPORT 4116~2003 Well Name/No. RENDEZVOUS 2 Operator CONOCOPHILLIPS ALASKA INC 8645 Completion Dar 4/28/2001 Completion Statu SUSP Current Status SUSP APl No. 50-103-20363-00-00 UIC N Compliance Reviewed By: Date: ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 17, 2002 James R. Winegamer District Landman Exploration and Land ConocoPhillips PO Box 100360 Anchorage AK 99510 Dear Mr. Winegamer: The Alaska Oil and Gas Conservation Commission ("Commission") has completed an audit of the NPRA wells drilled by Phillips Alaska, Inc. ("Phillips") to v. erify the well status and projected release dates. In letters accompanying data submittals for these NPRA wells, Phillips requested that the Commission provide notice prior to any public disclosure of confidential information so that Phillips might be heard on the issue. Pursuant to AS 31.05.035(c), the data Phillips provided as required by AS 31.05.035(a) will be kept confidential for 24 months following the 30-day filing period unless the °wner of the well gives written permission · to release the reports and information at an earlier date. The Commissioner of Natural Resources may extend the 24-month period of data confidentiality under certain circumstances. In the case of the Spark IA, Permit to Drill # 200-056, the Department of Natural Resources ("DNR") granted extended confidentiality for the well through September 3, 2002 although the Commission's records indicated that the status of this well is "Operation Shutdown". An audit of the Commission's records indicates that this status is in error. The Commission has determined that the Spark lA well was in fact completed (equipped and conditioned so that it was capable of producing or injecting fluids) on April 29, 2000 and is therefore subject to release after September 3, 2002. Unless the Commission hears from Phillips before September 20, 2002, the Spark lA file will be released to the public on September 23, 2002. James R. Winegamer September 17, 2002 Page 2 of 2 The following is a list of Phillips' NPRA wells that have projected release dates. Rendezvous A PTD # 200-054 5/27/03 Lookout 1 PTD # 201-003 5/4/04 Rendezvous 2 PTD # 201-007 5/28/03 Hunter A PTD # 202-013 4/26/04 Mitre 1 PTD # 202-026 5/21/04 Lookout 2 PTD # 202-027 6/5/04 Mooses Tooth C PTD # 201-049 5/6/03 If you have any questions about these release dates, please contact Steve Davies at 793- 1224. Although it has been the practice of the Commission to publish well data release dates in advance on its website, it is the operator's or owner's responsibility to make a timely application to the Department of Natural Resources in the event that extended confidentiality is desired. You should not rely on receiving any reminders from the Commission regarding the release dates for these wells. Sincerely, Cammy Oechsli Taylor Chair COT:\jjc cc: Mark Meyers, DOG CERTIFIED MAIL ~F7099 3220 0004 9021 6659 RETURN RECEIVr REQUESTED May 10, 200;! Richard P, Mort Vice President ........ Bxploration and Laud Phillips Alaska, lac,' P.O. Box 100360 Anchorage, Alaska 99510-0360 DECISION OF THE DIRECTOR ~Request for Extension of Confidentiality under 11 AAC 83,153 " Spark 1 APl #501032031300 Rendezvous 2 APl #501032036300 I Spark lA APl #501032031301 Lookout 1 APl #501032035900" Rendezvous A APl//501032031600 Moose's Tooth C API #501032031500 Clover A APl #501032031000 I am responding to your March 22, 2002, letter requesting extended confidentiality under 11. AAC 83,153 for well data, reports, and information generated from seven NPR-A wells, and. filed with the Alaska Oil and Gas Conservation Commission under AS 31.05.035, Based on your presentation to the Division on May 8, 2002, I extend the confidentiality time period for the data, reports, and information generated from four of the seven wells listed in Attachment ^ to your letter. This extension is granted based on the significance of the well information to evaluation of unleased acreage which will be offered for sale by the Bureau of Land Management's NPR-A sale now scheduled for June 3, 2002, No furore extensions will be granted for these wells, The information generated from the other three wells--Rendezvous 2, Lookout 1, and Moose's Tooth C--does not become public under AS 31.05,035 until the middle of next year, so I amnot extending the confidentiality time period for that information at this time, This confidentiality extension for the information from these four wells is through September 3, 2002, 90 days after the Bureau of Land Management's NPR-A lease sale scheduled for June 3, 2002. "Develop, Conserve, and Enhance Natural Resou,.ces for Prtsent and Future Aladmns." MAY 13 '0;:' 09:34AM ST-AK DMR IqATIER 90? 269 19947 By copy of this letter, I am notifying AOGCC of the extended ¢onfidenfialit'y granted these wells, A p~rson affected by this decision may appeal it in accordance with 11 AAC 02, Any appe. sl must be received within 20 calendar days after the date of "issUance" of this decision, as defi~ed in t ! AAC 02.040(c) and (d) and may be mailed or delivered to Pat Pourchot, Commissioner, Depa~u~nent of Natural Resources, ~50 W, 7~ Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1-907-269- 8918, or scat by electronic mail to d__nr, ap, p~a]~ @.al.ar.state,ak.us, This decision takes effect immediately. If no appeal is filed by the appeal deadline, this decision becomes a final admJ.nistrative order and decision of the department on the 31~t day after issuance, An eligible person must first appeal this decision ia accordance with 11 AAC 02 before appealin~ tM.s decision to Superior Court, A copy of 11 AAC 02 may be obtained from any regionS, information office of the Department of Natural Resources. Mark D. Myers Director Cc: Daniel Seamount, Commissioner, AOOCC Cammy Taylor, Commissioner, AO{3CC ~eff Landry, Dept. of Law Don Bfizzolara, DO&O MAY 13 'OP 09:32F~M ST-AK DHR WATER State of Alaska Department of Natural Resource Division of Oil & Gas ~50 West 7m Avenue, Suite BO0 Anchorage, AK 99501-3560 907 269 8947 P.1 (907) 269-8942 ANY~., . ' FAX NO.: {~0_7_} 269-111~42 .. Number of pageg Including cover sheet: ~:~' _. ~nt E] For Review n'! Please comment E] ~ you Requested E] FYi C'.~Userm~KIdWn~ Fenn,do= 0~/17101 .RECEIVED '""" ':' 2002 Alaska Oil & Gas Cons. Comm~on PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 TO: AOGCC 333 WEST7TH ANCHORAGE, AK. ATTN:BOBCRANDALL DATE: APRIL '12, 2002 AIRBILL: 5131166 AFT#: PBV02-04-11-01 CHARGE CODE: 42374 OPERATOR: Phillips Alaska, Inc. SAMPLE TYPE: DRY NUMBER OF BOXES: 9 BUNDLES NAME: SAMPLES SENT: 2,,~O ... O,]'tSPARK 1 ~ ~- OS'"I~SPARK lA ONE COMPLETE SET OF DRY CUTTING AS RECEIVED FROM THE RIG '--'---~Oq(o 100'-8850' ~ -~" ~ RENDEZVOUS A ~1 - 56-/RENDEZVOUS 2 3350'-8522' 250 -8333 ~~200'-8651' ~O'~- 0o'~ LOOKOUT 1 '2,,.I~11'"'" O"iff MOOSES TOOTH C /1,.O~--OI3 HUNTER A %02_ bj)..¢ITRE 1 L MITRE PB1 [ b"Z 2. 120'-8350' [6~1 170'-8738' l 0 ~ i~ 100'-9600' 1 O 8 3 80'-8090' '"5870'-8240' ~-b~? CLOVER A [b'~ I 100'-8570' UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND SEND A SIGNED COPY OF THIS TRANSMITTAL TO: RECEIVED BY: D. GARRARD G. WILSON R. CRANDALL / ~ ,, PAl # PAl AOGCC Phillips Alaska Inc. BAYVIEW GEOLOGIC FACILITY P. O. BOX 100360 ANCHORAGE, AK. 99510-0360 ATTN: D. L. Przywojski ABV-100 DATE: PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY EXPLORATION & LAND P.O. BOX 100360 ANCHORAGE. ALASKA 99510-0360 PHONE (907) 2~3-4556 FACSIMILE (907) 265-6339 Richard P. Mott Vice President March 22, 2002 Pat Pourchot, Commissioner State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7~ Ave., Suite 1400 Anchorage, AK 99501-3510 RECEIVED APR 5 200Z Re: Request for Extension of Confidentiality Alaska Statute 31.05.035 & Regulation 11 AAC 83.153 Phillips Alaska, Inc. ("PAI"), as operator for and on behalf of the working interest owners ("Lessees") of the wells listed in Attachment A hereto ("NPRA Wells"), hereby respectfully requests extended confidentiality for the reports and information generated from the NPR-A Wells and filed with the Alaska Oil and Gas Conservation Commission as required by state law ("Data"). All of the NPR-A Wells are located on federal lands located within the NPR-A. The Lessees make this request for the following reasons: (1) this Data is important to the Lessees in evaluating acreage in future federal oil and gas lease sales in the NPR-A; and (2) the Data for the NPR-A Wells is protected from public disclosure under federal law and state law. First, the Data from the NPR-A Wells contain significant proprietary and sensitive information relating to the valuation of unleased land within the NPR-A. Disclosing the Data to the public would cause financial harm to the Lessees because additional leasing of lands in the NPR-A will probably take place in the future. An EIS is currently underway for the planning of a federal oil and gas lease sale in the western NPR-A. Due to the remoteness of the lands that could be leased in the NPR-A and the restrictiveness of protections already in place for exploration and development of the leased lands within the NPR-A, disclosure of Data to the public about what the future potential for development for the currently leased lands, which Data was obtained at the sole risk and expense of the Lessees, would be detrimental to the Lessees' competitive position in NPR-A. Second, the Data is protected from disclosure under federal law. Federal statute 5 USC 552(b)(9) exempts "geological or geophysical information and data, including maps, concerning wells" from the right of public inspection and disclosure provided in the Freedom of Information Act at 5 USC 552(a). The NPR-A lease terms under which Lessees leased the lands on which the Wells were drilled states as follows: During existence of this lease, information obtained under this section [section 5] shall be closed to inspection by the public in accordance with the Freedom of Information Act (5 U.S.C. 552). Pat Pourchot, Commissioner State of Alaska, DNR March 22, 2002, Page 2 Paragraph 2, Section 5, NPR-A Lease Form, a copy of which is attached hereto as Attachment B. When a record is protected under federal law, it is also protected under Alaska law. Pursuant to AS 40.25.120(a)(4), a record required to be kept confidential by federal law or regulation is not available for public inspection. The focus of the provision for release of well data after two years under AS 31.05.035 appears to be data taken on state lands, not federal lands over which the Department of Natural Resources does not have jurisdiction. Because the Data is protected from disclosure by federal and state law, the commissioner should extend the confidential status of the Data. If you have any questions or require any additional information, please call me or Mr. Jim Winegarner at 265-6914 and we will arrange a meeting to review this request in more detail. Sincerely, Richard P. Mott Vice President Exploration and Land RPM:JPW C¢~ U.S. Department of Interior Bureau of Land Management 6881 Abbott Loop Road Anchorage, AK 99507-2591 Attn: Peter Ditton, Field Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 L/2t*'tTm: Cammy Taylor, Chairman Anadarko Petroleum Corporation 3201 C Street, Suite 603 Anchorage, AK 99503 Atto: John A. Bridges, Land Supervisor, Alaska State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Ave., Suite 800 Anchorage, AK 99501-3510 Attn: Mark Myers, Director Pat Pourchot, Commissioner State of Alaska, DNR March 22, 2002, Page 3 Attachment A Extended Confidentiality Requested for the following NPRA Wells Spark 1 Spark lA Rendezvous A API# 501032031300 API# 501032031301 API# 501032031600 05.13.02 Data Release Date 07.01.02 Data Release Date 06.03.02 Data Release Date Clover A API# 501032031000 05.22.02 Data Release Date Rendezvous 2 API# 501032036300 05.30.03 Data Release Date Lookoutl API# 501032035900 06.01.03 Data Release Date Moose's Tooth C API# 501032031500 07.01.03 Data Release Date ~. a, ttatchment B I"' ~NITED STATES DEPAk i~WqENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT ALASKA STATS OFFICE OFFER TO LEASE AND LEASE FOR OIL AND GAS ISerial No. AA-081819 The undersigned (reverse) offers to lease all or any of the lands in Item 2 that are available for lease pursuant to the Mineral Leasing Act of 1920, as amended and supplemented (30 U.S.C. 181 et seq.), the Mineral Leasing Act for Acquired Lands of 1947, as amended (30 U.S.C. 351-359), the Attorney General's Opinion of April 2, 1941 (40 Op. Atty. Gen. 41), or(he Naval Petroleum Reserve Production Act of 1976 (42 U.S.C. 6501 et seq.), as amended. I. Name S (reef READ INSTRUCTIONS BEFORE COMPLETING ARCO Alaska Inc. (78%) P.O. Box 100360 Anchorage, Alaska 99510 and Anadarko Petroleum Corporation (22%) P.O. Box 1330 Houston, Taxes 77251 City, State, Zip Code 2. This application/offer/lease is for Public Domain Lands in the National Petroleum Reserve - Alaska (NPR-A) Legal description of land requested: *Tract No.: 991-H-070 *SEE INSTRUCTIONS BELOW PRIOR TO COMPLETING PARCEL NUMBER AND SALE DATE T. R. Meridian State TllN, R2E Umiat SE 1/4 Amount remitted: Filing fee $ Rental fee $ 28,780.00 DO NOT WRITE BELOW THIS LINE *Sale Date (m/d/y): May / 05 / 1999 County Total acres applied for 5,756 Total $ 3. Land included in lease: T. R. TllN, R2E SE 1/4 Meridian Umiat State County Tom acres ia ~ 5,756 Rental retaiaedS 28,780.00 This lease is issued granting the exclusive right to drill for, mine, extract, remove and dispose of all the oil and gas (except helium) in the lands described in Item 3 together with the right to build and maintain necessary improvements thereupon for the term indicated below, subject to renewal or extension in accordance with the appropriate leasing authority. Rights granted are subject to applicable laws, the terms, conditions, and attached stipulations of this lease, the Secretary of the Interior's regulations and formal orders in effect as of lease issuance, and to regulafiona and formal order~ he~af'ter promulgated when not inconsistent with lease rights granted or specific provisions of this lease. NOTE: This lease is issued to the high bidder pursuant to his/her duly executed bid or nomination form submitted under 43 CFR Part 3130 and is subject to the provisions of that bid or nomination and those specified on this form. The pm'ties agree ~ 1) that this lease form replaces the previous lease form executed by the parties for this lease; 12) that this lease will be deemed to have been issued pursuant to this lemse form; (3) that this lease will be deemed to have been executed a.s of the original date each party executed the previous lease form: and (4) that the effective date of this lease is Sel>tember 1, 1999. TH~ UNITED STATES OF AMERICA Type and primary term of lease: by [ ] Noncompetitive lease (ten years) [ ] Competitive lease (ten years) [ X ] Other Competitive NPR-A Lease (ten years) (Signing Officer) Sr. Leasable Minerals Adjudicator . I 0q"} (Title) (Date) £~"~.C'nVE DATE OF L£ASE September 1, 1999 AK-3130-1 (April 1999) 4. (a) U/l'dersigned certifies that (1) offeror is a citizen of the ~" ' States: an association of such citizens: a municipality; or a corp~'" ~ organtzeo under the laws of the United States or of any State or ,~ minor under the laws of the State ia which TerritOry thereof; (2) all parties holding an interest in the offer[ mpliance with 43 CFR Part 3100 and the leasin~ authorities: (31, ,~r is not considered a the. lands covered by this offer are located. (b) Undersigned agrees that signature to this offer constitutes acceptance of this lease, including all terms, conditions, and stipulations of which offeror has been given notice, and any amendment or separate lease that may include any land described in this offer open to leasing at the time this offer was filed but omitted for any reason from this lease. The offeror further agrees that this offer cannot be withdrawn, either in whole or in part. This offer will be rejected and will afford offeror no priority if it is not properly completed and executed in accordance with the relictions, or if it is not accompanied by the required payments. 18 U.S.C. Sec. 1001 makes it a crime for any person 'knowingly and willfully to make to any Deparunent or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. NOTICE The Privacy Act of 1974 and the regulations at 43 CFR 2.48(d) provide that you be furnished with the following information: AUTHORITY: 50 Stat. 900:25 U.S.C. 500 PRINCIPAL PURPOSE: The primary uses of the records are (1) to determine your qualification to receive an oil and gas lease: and (2) to provide information concerning oil and gas leases for administrative and public use. ROUTINE USES: BLM and the Department of the Interior (DOB may disclose your information on this form: (1) to members of the public who have a need for the information that is maintained by BLM for public record: (2) to the U.S. Department of Justice, court, or other adjudicative body when DOI determines the information is necessary, and relevant to litigation: (3) to appropriate Federal, State, local or foreign agencies responsible for investigating, prosecuting violations, enforcing or implementing this statute, regulation, or lease: and (4) to a congressional office when you request the assistance of the Member of Congress in writing. EFFECT OF NOT PROVIDING THIS INFORMATION: If you do not furnish all the information required by this form, your application may be rejected. Duly executed this day of , 19 SEE ATTACI-~D SIGNATORY PAGE(S) (Signature of Lessee or Attorney-in-fact) LEASE TERMS Sec. 1. Rentals - Rentals shall be paid to the proper office of lessor in advance of each lease year. Annual rental rates per acre or fraction thereof are: (a) Noncompetitive lease, $1.50 for the first 5 years; thereafter $2.00; (b) Competitive lease, $1.50; for the fu'st 5 years; thereafter $2.00; (c) Other, see attachrr~at: or for NPR-A: $5 for Area A; $3 for Area B; as specified in the detailed statement of sale. If th.is lease or a portion thereof is committed to an approved cooperative or unit plan which includes a well capable of producing leased resources, and the plan contains a provision for allocation of production, royalties shall be paid on the production allocated to tiffs lease. However, annual rentals shall continue to be due at the rate specified in (a), (b), or (c) for those lands not within a participating area` Failure to pay annual rental, within 30 days after receipt of a Notice of Delinquency shall cause this lease to terminate, Rentals may be waived, reduced, or suspended by the Secretary upon a sufficient showing by lessee. Sec. 2. Royalties - Royalties shall be paid to proper office of lessor, Royalties shall be computed in accordance with regulations on production removed or sold. Royalty rules are: (a) Noncompetitive lease, 12~A%; (b) Competitive lease, 12½%; (c) Other, see attachment, or for NPR-A: 16~% for Area A; 12.5% for Area B as specified in the detailed statement of sale. Lessor reserves the right to specify whether royalty is to he paid in value or in kind. and the right to establish reasonable minimum values on products after giving lessee notice and an opportunity to be heard. When paid in value, royalties shall he due and payable on the last day of the month following the month in which production occurred. When paid in kind, production shall be delivered, unless otherwise agreed to by lessor, in merchantable condition on the premises where produced without cost to lessor. Lessee shall not be required to hold such production in storage beyond the last day of the month following the month in which production occurred, nor shall lessee be held liable for loss or destruction of royalty oil or other products in storage from causes beyond the reasonable control of the lessee. Minimum royalty in lieu of rental of not less than the rental which otherwise would be required for that lease year shall be payable at the end of each lease year beginning on or after a discovery in paying quantities. This minimum royalty may be waived, suspended, or reduced, and the a~ve royalty rates may be reduced, for all or portions of this lease if the Secretary determines that such action is necessary, to encourage the greatest ulttmate recovery of the leased resources, or is otherwise justified. An interest charge shall be assessed on late royalty payments or underpayraents in accordance with the Federal Oil and Gas Royalty Management Act of 1982 (FOGRMA) (30 U.S.C. 1701). Lessee shall he liable for royalty payments on oil and gas lost or wasted from a lease site when such loss or waste is due to negligence on the part of the operator, or due to the failure to comply with any rules, regulations, order, or citation issued under FOGRMA or the leasing authority. Sec. 3. Bonds - A bond shall be fried and maintained for lease operations as required under regulations. Sec. 4. Diligence, rate of development, unitization, and drainage - Lessee shall exercise reasonable diligence in :leveloping and producing, and shall prevent unnecessary damage to, loss of, or waste of leased resources. Lessor -eserves the right to specify rates of development and production in the public interest and to require lessee to ;ubscribe to a cooperative or unit plan, within 30 days of notice, il' deemed necessary for proper developn~nt and >peration of area. field, or pool embracing these leased lands. Lessee shall drill and produce wells necessary to ,rotect leased lands from drainage or pay compensatory royalty for drainage in amount determined by lessor. Sec. 5. Documents, evidence, and inspection - Lessee shall file with proper office of lessor, not later than 30 days afxer effective date thereof, any contract or evidence of other arrangement for sale or disposal of production. At such tm'~s and in such form as lessor may preserihe, lessee shall furnish detailed statements showing an~ums and quaiity of all products removed and sold, proceeds therefrom, and amount used for production purposes or unavoidably lost. Lessee may be required to provide plats and schematic diagrams showing development work and improvermnts, and reports with respect to parties in interest, expenditures, and depreciation costs. Ia the form proscribed by lessor, lessee shall keep a daily drilling record, a log, information on well surveys and tests, and a record of subsurface investigations and furnish copies to lessor when required. Lessee shall keep open at all reasonable times for inspection by any authorized officer of lessor, the leased premises and all wells, improven~uts, machinery, and fixtures thereon. and all books, accounts, maps, and records relative to operations, surveys, or investigations on or in the leased lands. Lessee shall maintain copies of all contracts, sales agreements, accounting records, ami doeurr~ntation such as billings, invoices, or similar documentation that support costs claimed as manufacturing, preparation, and/or transportation costs. All such records shall be maintained ia lessee's accounting office for future audit by lessor, la:ssee shall maintain requited records for 6 years after they are generated or, if an audit or investigation is underway, until released of the obligation to maintain such records by lessor. During existence of this lease, in.formation obtained under this section shall be closed to inspection by the public in accordance with the Freedom of Information Act (5 U.S.C. 552). Sec. 6. Conduct ot'operations - Lessee shall conduct operation in a manner that minimizes adverse impacts to the land, air, and water, to cultural, biological, visual, and other resources, ~ to other land uses or users. Lessee shall take reasonable measures deemed necessary by lessor to accomplish the intent of this section. To the extent consistent with lease rights granted, such measures may include, but are not limited to, m0dif~ation to siting or design of facilities, timing of operations, and specification of interim and final reclamation measures. Lessor reserves the right to continue existing uses and to authoraze future uses upon or in the leased land& including the approval of easeme,nts or rights-of-way. Such uses shall be conditioned so aa to prevent unnecessary or unreasonable interference with rights of lessee. Prior to disturbing the surface of the leased lands, lessee shall contact lessor to be apprised of procedures to be followed and modifications or reclamation measures that may be necessary. Areas to be: disturbed may require inventories or special studies to determine the extent of impacts to other resources. Lessee may be required to complete minor inventories or short term special studies under guideLines provided by lessor. If in the conduct of operations, threatened or endangered species, objects of historic or scientific interest, or substantial unanticipated environmental effects are observed, lessee shall immediately contact lessor. Lessee shall cease any operations that would result in the destruction of such species or objects. Sec. 7. Mining operations - To the extent that impacts from mining operations would be substantially different or greater than those associated with normal drilling operations, lessor reserves the right to deny approval of such operations. Sec. 8. Extraction of helium - Lessor reserves the option of extracting or having extracted helium from gas production in a manner specified and by ri'cans provided by lessor at no expense or loss to lessee or owner of the gas. Lessee shaft include in any contract of sale of gas the provisions of this section. Sec. 9. Damages to property - Lessee shall pay lessor tbr damage to lessor's improvermats, and shall save and hold lessor harn~ess from ail clam~ i'or dan~age or harm to persons or property as a result of lease operations. Sec. 10. Protection of diverse interests and equal opportunity - Lessee shall pay when due all taxes legally assessed and levied under laws of the State or the United States: accord all employees complete freedom of purchase; pay all wages at least twice each month in lawful money of the United States, maintain a safe working environn~ent in accordance with standard industry practices; and take measures necessary to protect the health and safety of the public. ~ssor resewes the right to ensure that production is sold at reasonable p6c~to prevem monopoly. If lessee opeC'ares a pipeline, or owns controlling interest in a pipeline or a company operatin,e a ptpelme, which may be operated accessible to oiJ derived from these leased lands, lessee shaf comply with section 28 of the Miner:q Le~ing Act of 1920. Lessee sh~l corr~ly with Executive Order No. 11246 of September 24, 1965, as amended, and regulations and relevant orders of the Secretary. of Labor issued pursuant thereto. Neither lessee nor lessee's subeomraclors shall rnmntam segregated facilities. During the performance of this lease, the Lessee must compb' ful¥ with par~raphs t 1) through (7) of~l CFR 60-1.4~a) with respect to employment discrm~ination on the basis of race, color, religion, sex or nanonal origin, and must incorporate the requirermms set forth in those paragraphs tn every, subcontract or purcha.se order, as provided by that regulation. Sec. 11. Transfer of lease interests and relinquishrnent of lease - As required by regulations, lessee shaft file with lessor any ass~gnn'~nt or other transfer of an interest in this lea.se. Lessee may relinquish this lease or any legal subdivision by f'ding in the proper offg:e a written relinquishment, v, hich sh~ be effective as of the date of tiling. subject to the connnued obligation of the lessee and surety to pay ~ accrued rentals and royalnes. Sec. 12. Delivery. of premises - tm~: as afl or portions of this lease am returned to ~essor, lessee shall place affected wefts in condition for suspension or abandorm~:nt, reclaim the land as specified by. lessor and, within a reasonable period oft/me, remove equipment and ut~rovements not deemed necess~ ~ I~ssor for preservation of producible wells. Sec, 13. Proceedings in case of default - If lessee fails to comply with any provisio~ of this lease, and the noncompliance continues for 30 days ~ter written notice thereof, this lease shall he subject to cancellation tmless or untd the leasehold comams a well capable or'production ofoil and gas in paying qua~titi~:s, or the lea.se is comtrutted to an approved cooperative or unit plan or commuhitization ,agreement which contai,n.s a well capable of production of uhitized substances tn paying quantities. This provision sh~ll not be construed to prevent the exercise by lessor of any other legal and equitable remedy, including waiver of the default. As such ren~dy or waiver shall prevent later cancetlation for the same default occurring at any other time. Lessee sh,~ be subject to applicable provisions and penalties of FOGRMA (30 U.S,C. 1"/01). Sec. 14.. Heirs and successors-in-interest - Each oblJffation of this lease shall extend to and be binding upon, and every, benefit hereof shaft inure to. the heirs, executors, administrators, successors, beneficiaries, or assi~ees of the respective pm-ties hereto. INSTRUCTIONS A. General 1. The front of this form is to be completed only by parties filing for a noncompetitive lease. The BLM will complete front of form for all other types of leases. 2. Entries must be typed or printed plainly in ink. Offeror must sign Item 4 in ink. 3. An original and two copies of this offer must be prepared and filed in the proper BLM State Office. See regulations at 43 CFR 1821.2-1 for office locations. 4. If more space is needed, additional sheets must be attached to each copy of the form submitted. B. Special: Item 1 - Enter offeror's name and billing address. Item 2 - A single tract number and Sale Date shall be the only acceptable description. Item 3 - This space will be completed by the United States. PAPERWORK REDUCTION ACT STATEMENT The Paperwork Reduction Act of 1990 (4~ U.S.C. 3501 et seq.) requires us to inform you that: 1. This information is being collected pursuant to the law. 2. This information will be used to create and maintain a record of oil and gas lease activity. 3. Response to this request is required to obtain a benefit. EFFECT OF NOT PROVIDING INFORMATION - If all the information is not provided, the offer may be rejected. See regulations at 43 CFR 3130. AK-3130-1 (April 1999) SIGNATORY PAGE FOR U.S. DEPT. OF INTERIOR B.L.M. OFFER TO LEASE & LEASE FOR OIL & GAS SERIAL NO. AA-081819 ARCO ALASKA, INC. Le~ee',~ Signat~r~ James M. Rj~(ud Attorney-in'Fact Lessee's Name (Print or Type) & Title January 31,2000 Date ARCO Alaska, Inc. Company Name THE UNITED STATES OF AMERICA STATE OF ALASKA This certifies that on the 31st day of January, 2000, before me, a notary public in and for the State of Alaska, duly commissioned and sworn, personally appeared James M. Ruud, to me known and known to me to be the person described in, and who executed the foregoing lease, .who then after being duly sworn according to law, acknowledged to me under oath that he executed same freely and voluntarily for the uses and purposes therein mentioned. WITNESS my hand and official seal the day and year in this certificate first above written. N~ta~ublic My Commission expires: 6-8-2003 SIGNATORY PAGE FOR U.S. DEPT. OF INTERIOR B.L.M. OFFER TO LEASE & LEASE FOR OIL & GAS SERIAL NO. AA-081819 ANADARKO PETROLEUM CORPORATION Lessee's S~gnature Todd L. Liebl Agent and Attorney-in-Fact Lessee's Name (Print or Type) & Title Janua_ry c¢~ , 2000 Date Anadarko Petroleum Corporation Company Name THE UNITED STATES OF AMERICA ) ) SS. STATE OF TEXAS ) This certifies that on the .~/~') day of January_, 2000, before me, a notary public in and for the State of Texas, duly commissioned and sworn, personally appeared Todd L. Liebl, to me known and known to me to be the person described in, and who executed the foregoing lease, who then after being duly sworn according to law, acknowledged to me under oath that he executed same freely and voluntarily for the uses and purposes therein mentioned. WITNESS my hand and official seal the day and year in this certificate first above written. N (~t a ry/~¢ ublic '~/O -,.~- ~.'.~. My Commission expires: SPECIAL STIPULATION(S) FOR LEASE AA-081819 Standard Lease Stipulation Numbers 1-24, 26-28, 30, 32, 34-38, 40-44, 46-48, 51, 53, 55-79, as identified and delineated in the Final Record of Decision and Detailed Statement of Sale, pertain to all leases created from the National Petroleum Reserve-Alaska Sale 991, and are herein incorporated by reference and made a part of this lease. The following Special Stipulation(s) is/are specifically delineated in the Record of Decision and Detailed Statement of Sale as pertaining to this tract, and is/are hereby made a part of this lease. This/these is/are a direct quote(s) from the Detailed Statement of Sale document. All references to Exhibit A pertain to Exhibit A of the Detailed Statement of Sale. No part of this lease is identified as Exhibit A.: III. The "No Permanent Oil and Gas Facilities" and "No Permanent Oil and Gas Facilities within 1/4 mile of Fish-Bearing Lakes Stipulations," Number 39, are identified on each specific tract in Exhibit A hereof. They pertain to some of the tracts in both Area A and Area B. ALASKA OIL AND GAS CONSERYA~ION COMMISSION Greg Wilson NPR-A Contact for Geologic Data Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510-0360 April 4, 2002 TONY KNOWI FS, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 . FAX (907) 276-7542 Dear Mr. Wilson: As operator of the following wells, Phillips Alaska, Inc. ("Phillips") is required to provide the Alaska' Oil and Gas Conservation Commission ("AOGCC") with Certain data within 30 days after completion, suspension, or abandonment of a well.. A review of AOGCC records indicates that Phillips has failed to provide the AOGCC with samples of drill cuttings as required by 20 AAC 25.071(b)(2) for the following wells: Spark 1 Spark 1-A Rendezvous A Lookout 1 Rendezvous 2 PTD# 200-034 PTD# 200-056 PTD# 200-054 PTD# 201-003 PTD~,,~96T Please ensure that Phillips brings itself immediately into compliance with .20 AAC 25.071(b)(2). Please contact me at 793-1230 if you have any questions. Since~ R°~ .-t ~'Tandall - Sr. Petroleum Geologist RC:33c PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DA TA * FROM: Sandra D. Lemke, ATO1486 Phillips Alaska, ]:nc. P.O. Box 100360 Anchorage AK 99510-0360 TO: RE: Mooses Tooth C, Rendezvous 2, Lookout 1 DATE: 09/20/2001 Lisa Weepie AOGCC 333 W. 7~ Ave., Suite 100 Anchorage, Alaska 99510 Transmitted herewith is the following: 3.5'~lisk + hardcopy reports v' Sperry Sun directional surveys, Lookout 1, Nooses Tooth C, Rendezvous 2 Please check off each item as received, sign and return transmittal to address below All data to be held confidential until State of Alaska designated release date (AOGCC) Approx. 5/2003 *"On behalf of itself and [Anadarko Petroleum], Phillips Alaska, Inc. submits the attached data for 3 NPRA 2001 drilling season Wells, as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the use of the Commission in carrying out its duties, we question whether any future disclosure to DNR or the public would be appropriate or valid. However, it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, so that we may be heard on the issue." Date: Return receipt to: Phillips Alaska, Inc. AT, N: S. Lemke~ ATO-1486 700 G. Street Anchorage, AK 99501 RECEIVED SEP 2 5 2001 Alaska Oil & Gas Cons. Commission Prepa~/~g~andra D. Lemke Phillips Alaska 1T Technical Databases 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 September 18, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Rendezvous #2 (201-007) Completion Report - Corrected Dear Ms. Commissioner: Phillips Alaska, Inc., as operator of the Rendezvous #2 exploration well, submits the attached corrected "Well Completion Report" (AOGCC form 10-407). The bottomhole location has been corrected. No other documents are attached in this package. 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 Bill Lloyd at 265-6531. Sincerely, ~ e. Mazz'olini ................. .,~ Exploration Drilling Team Leader PA1 Drilling PM/WL/skad $£P 1 7 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA '"A{ ,KA OIL AND GAS CONSEFIVATION C~ /IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r-] Gas E] Suspended ~] Abandoned r~ service E] "~ 2. Name of Operator ~ 7. Permit Number Phillips Alaska, Inc.~ 201-007 / 3. Address '~-.,'~..j~f,~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360~' ~'~'~ 50-103-20363-00 4. Location of well at surface 9. Unit or Lease Name 1707' FNL, 2523' FWL, Sec. 6, T9N, R2E, UM (ASP: 285382, 5913243) "t-: .: ;:'"r::.-, Exploration NPRA At Top Producing Interval'-~~J ,,, _..~ :, 10. Well Number 1659' FNL, 2472' FWL, Sec. 6, T9N, R2E, UM (ASP: 285332, 5913292) - Rendezvous #2 At Total Depth !. ;/~'~-]'~'~"" ...... ;ii 11. Field and Pool 1659' FNL, 2574' FWL, Sec. 6, T9N, R2E, UM (ASP: 285434, 5913290) i,.;'4-~_~ Exploration 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. GL 115' & 35' RKBI ADL AA-81781 ALK 5126 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions April 8, 2001 April 19, 2001 April 22, 2001I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 8650' MD / 8649' TVD 8325' MD / 8324' TVD YES [~] No E]I N/A feet MD 598' MD 22. Type Electric or Other Logs Run EWR/ROP/DGR, CNP/SLD/DGR, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 63# B Surface 115' 24" 280 sx AS 1 9.625" 40# L-80 Surface 2673' 12.25" 42o sx AS III Lite, 170 sx LiteCRETE 7" 26# L-80 Surface 8602' 8.5" 140 sx LiteCRETE, 190 sx GasBLOK set plug @ 8325' MD 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 8394' 7952' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8344' - 8390' MD 8343' - 8389' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 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 IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press, psi 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 $£P 1 7 2001 ,Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GE OL O GI C MARi~.''"- FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Base Permafrost 598' 598' Top Nanushuk 2921' 2921' Top HRZ 7408' 7407' J-4 Unconformity 8392' 8391' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, As-Built, Core Description Ilowing is true and correct to the best of my knowledge. 32. I hereby certify that the I.~o Questions? Call William Lloyd 265-6531 · / f?, Ddllln,q Team Leader Date ¢- /'~-0/ INSTRUCTIONS Prepared by Sharon AIIsup-Dral~e 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 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. F~ a C ~'~ ~V;~, t'i~'"'} Item 28: If no cores taken, indicate "none". Form 10-407 $£P 1 ? Alaska Oil & Gas Cons. Commiss Anchorage Rpt Date 03/15/01 12:00 AM 03/15/01 12:00 AM 03/15/01 12:00 AM Begin Time 00:00 08:00 09:00 03/16/01 12:00 AM 00:00 03/16/01 12:00 AM 12:00 03/17/01 12:00 AM 00:00 03/17/01 12:00 AM 06:00 03/17/01 12:00 AM 18:00 03/18/01 12:00 AM 00:00 Operations Summary Rendezvous 2 Move End Time 08:00 09:00 15:30 12:00 00:00 Comments Replace brake bands on drawworks. Sring up new drilling line. Rig down floor - clear floor, R.D. floor, lay down kelly, prepare koomey house to be set off. Put DP and HWDP in lower pipe shed. PJSM. Telescope derrick down, secure derrick board, continue to drain up water lines, complete telescoping ops, seperate pipe shed from drilling module, prepare air tugers for move. PJSM. Store tugger lines & unstring drlg line, rig down LanTec winch, disconect hydraulic lines / rams from derrick, secure Iron Rough Neck, rig down drill floor equip. 06:00 18:00 00:00 00:00 Set out pipe shed to move, & move mud pits Crane ops suspended as per cold wx [<-35 dg F] policy until 0600hrs. Continue w/non-heavy wt ops. PJSM. Crane set derrick on trailor. {Peak truck - trailer to unable to start, lost 3 hrs]. Remove drlg line spool & hydraulic cylinders, set Iron Rough Neck from rig floor. Crane crew x-o & PJSM. RR down & set off remaining wind wallks, roof over draw works, hydromatic water tank, & V- doors. PJSM. REMOVE MISC EQUIP FROM RIG FLOOR - DRAWWORKS, WALK AROUND FLOOR PLATES, TOOL HOUSE, UNBOLT FLOOR SECTION - REMOVE ROTARY TABLE, PIPE RACK, DOGHOUSE, KOOMEY HOUSE 03/19/01 12:00 AM 00:00 03/19/01 12:00 AM 12:00 '03/20/01 12:00 AM 00:00 03/20/01 12:00 AM 12:00 03/20/01 12:00 AM 20:00 03/21/01 12:00 AM 12:00 03/21/01 12:00 AM 23:00 03/22/01 12:00 AM 00:00 03/22/01 12:00 AM 11:00 03/22/01 12:00 AM 16:00 12:00 00:00 12:00 20:00 00:00 23:00 00:00 11:00 16:00 21:30 NOTE: Held weekly safety meetings w/2 drill crews / PPCO reps, discusssed safety o PJSM. UNBOLT AND REMOVE FLOOR SECTION WITH DERRICK A-LEG. ( READY 60 MAN CAMP FOR MOVE - SHUT DOWN WATER AT 02:00 HRS.) PULL WIRES ON - CAMP SECURE INSIDE - LOAD OUT 60 MAN CAMP AND MOVE TO RENDEZVOUS.#2. LAY HERCULITE AND SET MATTING BOARDS. R.D. AND MOVE 60 MAN CAMP TO RENDEZVOUS #2. R.U. 60 MAN CAMP ON RENDEZVOUS pAD. WAIT ON TRUCKS TO MOVE RIG. INSTALL JEEP UNDER SUBSTRUCTURE. Moving Rig to RendeZvous #2 Rig fell through ice road on mile 12. Jacking rig up & using matting boards to repair road. Gather equipment & material. Jack up rig & place matting boards under entire sub base. Move sub base module to Colville River crossing. Build alternate ice road around weak spot in main ice road. Move remainder of modules & rig equipment across Colville River crossing. Operations Summary Rendezvous 2 Move 03/22/01 12:00 AM 03/22/01 12:00 AM 03/23/01 12:00 AM 03/23/01 12:00 AM 03/24/01 12:00 AM 21:30 23:30 00:00 12:00 00:00 23:30 00:00 12:00 18:00 12:00 Move rig from Colville River to mile #1 marker on NPRA road. Change tire on pipe shed module. Finish moving rig modules to location. Unload crane. Wait on trucks with floor sections. PJSM with truck & crane crews. Setting floor sections, Koomey house, & stair tower. Offload trucks as needed. 03/24/01 12:00 AM 03/25/01 12:00 AM 03/25/01 12:00 AM 03/26/01 12:00 AM 03/26/01 12:00 AM 12:00 00:00 12:00 00:00 07:00 00:00 12:00 00:00 07:00 00:00 Begin moving Ross Camp from Palm location @ 10:00 a PJSM with truck & crane crews. Set pipe rack floor section, Dog house, walkway off driller side, rotary table, tool house, drawworks, hydro matic tank, lantex winch, & small windwalls. Ross camp arrived 2000 hrs. Spread hercalite, set shop & half way hou PJSM with crane crew as needed for each operation. Install, raising cylinders, windwalls around floor, work on steam system, lug up 480 electric lines, & install iron roughnek & track. PJSM with crane crew as needed for each operation. Install roof wind wall panel, windwall track system, & back windwalls. Set derrick & pin same. Rig up hydraulic system & prepare derrick to raise. PJSM with crane crew. Rig up hydraulic system, fastline, & air tugger lines to raise derrick. Raise derrick & raising cyclinder on drillers side failed with derrick @approximately 70 degree angle. Begin lowering derrick, hydraulic system failure, dropped Begin tap root investigation. Wait on Phillips Superintendent & Dreco derrick representative. 03/27/01 12:00 AM 03/28/01 12:00 AM 00:00 12:00 00:00 12:00 Rig crews working on mud pumps, auger system, & stove replacement for 60 man camp Rig crews working On service line in pump room-pit area. Start preparing rig for demob. Continue cleanup oil on rig floor. Clear pipe shed of rental tools. Remove bolts on flOor section draw works. Load trucks with rental drilling equipment. Unhook service Finish pulling seats out of mud pumps. Move equipment from top of pipe shed to lower pipe shed. Dreco derrick rep inspected derrick. Nabors insurance rep inspected rig damage. 03/29/01 12:00 AM 00:00 00:00 Load out trucks to return rental equipment & Phillips equipment. Offload Spe Finish palleting mud products in pit room. PJSM with Peak Crane crew. Set off wind walls. PJSM with Peak crane crew on liftin derrick off sub base. Tied 2 cranes to derrick, tied up all loose lines, blocks and cut off debris that could interfer with the d Operations Summary Rendezvous 2 Move 03/30/01 12:00 AM 03/31/01 12:00 AM 04/01/01 12:00 AM 04/02/01 12:00 AM 04/03/01 12:00 AM 04/04/01 12:00 AM 00:00 00:00 00:00 00:00 00:00 00:00 00:00 00:00 00:00 00:00 00:00 00:00 Remove cross beams under floor-lantec winch-back roof panels-drillers console-floor plates-back wind walls- hydromatic tank-rotary table-front section rig floor-drilling line spool. Clean off broken derrick stand and kinked drilling line. PM Remove dog ho Mount BOPE in cradle. Lay down BOPE with crane. Work on auger in mud pits. Reroute fire lines on motor and pit modules. Put jeep under motor module. Pull all pipe out of pipe shed. Put knee braces back on tool house frame. Installing new auger in pit room. Hook up trucks to modules. The rig modules left location at 1600 hours. Arrived at the Ublutoach at 2130 hours and were crossing the Colville with Continue moving pipe shed, pit and motor modules to Prudhoe Bay from NPRA. Moved from The Colville river to J pad at 2400 hours. The rig modules were at Frontier yard at 0430 hours 4/3/01. Move 6 impassable wide loads from Rendezvous 2 to Prudhoe Bay. The loads left location at 1530 hours on 4/3/01 and arrived at KOC at 0220 4/4/01. The 20 man camp is at pad 6 at 6 am changing flat tires, the remainder of the equipment is proceeding to Fron Broke down 60 man camp and moved 13 loads to Prudhoe Bay. Plan to move12 loads on day shift today and finish getting remiander of loads of the Ioaction Friday morning. Operations Summary I"' Rendezvous 2 Rpt Date 04/07/01 12:00 AM 04/08/01 12:00 AM 04/09/01 12:00 AM 04/10/01 12:00 AM 04/11/01 12:00 AM Comments Hook up trucks to rig modules & sub base. Move rig to Rendezvous 2 location. spot sub base - pits - pump modules. Shim & level modules. Set motor module & hook up service lines. Set pipe sheds & working on rig acceptance checklist. Set rock washer & work on berms. Set berms & Tioga. Finish rig acceptance checklist. Offloading 580 bbls mud into active pit system. Nipple up 21 3/4" Hydril - knife valve & 110' 20" diverter line. Finishing offloading drlg mud. Load pipe shed with BHA. ***RIG accepted 1700 hrs 04/07/01 Function test diverter system - koomey unit & gas detectors. Witness & approved by John Spaulding AOGCC. Pre spud meeting with both rig crews & service companies. Finish Pre spud mtg with both crews & service companies. NU riser & flowline. Change out handling equipment, strap 4" DP & 4" hwdp. PU 120 jts 4" DP & stand in derrick Rig repair - top drive electrical system. Change out drive sub on top drive to 4" FH connection. Slip & cut 65' drlg line. PU 3 - 8" NMDC & stand in derrick. PU Baker 9 1/2" drlg motor - 12 1/4" bit - stabilizer - & 1 std 4" HWDP. PJSM - Fill conductor with mud. Test rig pumps & cheak mud system for leaks. Drill 108' - 313' ART = 3.5 hrs (Spud Well) POOH to pickup remainder BHA PU Sperry Sun tools - download - orient. PU DCS. Drlg 313' - 475' MD 475' TVD ART 0.70 hrs. Drilling 475'- 1627' MD 1627' TVD ART=9.6 hrs: Circulate hole clean. Monitor well, static. Wiper trip 1627'-210' TIH wash 10' bottom, no fill. Drlg 1627' - 2192' MD 2192' TVD ART 5.6 hrs Drlg 2192 - 2680'. Cir hi vis sweep Wiper trip to 1567' no problems / no fill, Cir 40 bbl hi - vis pill & bottoms up / clean shakers. Pooh, Id bha [stand back hwdp] & down load mwd /Iwd data MU float equip/ck operation & continue to rih w/34 of 68 total jts of 9. 625" x BT&C x 40 ppf x L-80 csg. Monitor for correct disp. Complete running a total of 68 jts 9.625" x BT&C x 40 ppf x L-80 csg, FMC hanger & Idg jt to land @ 2672.81'. Refer to csg rpt for details. Cir & condition mud:initial prop 10 ppg, vis 61, PV/YP 16/31, final 10'ppg, vis 56, PV/YP 18/32. Cmt csg w/417 sx lead @ 10.7 ppg followed by 174 sx tail @ 12.0 ppg, displaced w/184 of 186.3 bbls mud, plug bumped 2000 psi over disp press, held 5 min bled off - floats held. Refere to cmt rpt for details. Rig down cmt equip & police floor. PJSM ND diverter system. Install csg hd & NU 13 5/8" x 5k psi bop. Operations Summary Rendezvous 2 04/12/01 12:00 AM 04/13/01 12:00 AM 04/14/01 12:00 AM 04/15/01 12:00 AM 04/16/01 12:00 AM PJSM Install test plug, x-out lower pipe rams, open annular valve & monitor contineously through out bop testing. Test bope equip 250 / 5000 psi 10 min & annular 250 / 3500 psi 10 min. Recover test plug, ck annulus valves closed, install wear bushing. Pick up sufficient dp to drill to td w/stands. Pick/make up bha, set AKO @ .9 deg. Trip in to tag cmt @ 2585'. Test csg to 2500 psi / 30 minutes. Drlg cmt 2585 - 2680' & new hole to 2700'. Pump 40 bbl hi vis pill & displaced hole to conditioned 9.5 ppg PH/PA Kcl [6%] mud. Conducted F.I.T. test to 14.5 PPG Eq MW. Drlg 2700 - 2843' Ran PWD base line. Drlg 2843 - 3406'. Drlg 3406 - 4819' (Rot w/.5 hr slide for az control). Cir sweep w/bu, ck well static & pump dry slug. Pooh to bha. Stand back bha down load logging tools, recovering rd source, x,out jets to 3-13 & 3. 14 for tfa of .84in2, Rih installing source to dp. Tih to 2650 testing Iwd @ 310'. Cut 156' drlg line, service top drive. Continue tih to td of 4819', wash last 90' to rd, no detectable fill. Slow wash rate due to overloaded shakers. Drill 4819'-6600'. LWD/PWD weak from onset & becoming unuseable. Sonic inop after 6 hrs. last 90' controlled drilled @ 100, 80, & 60 fph while varing rpm, bit weight & flow rates w/no improvement in down hole tool response. Cir shakers clean, ck well static, & pump dry slug. Pooh to bha ( monitor well dead @ shoe). Stand back bha, recover rd source, down load data, Id down Iwd / mwd tools, & ck bit & motor. Pick up mwd / Iwd tools, install rd source, make surface cks/motor operation. Tih to tag bridge @ 6460'. Wash bridge 6460 - 6580' clean out to rd. Re-ream 6520 to td [6600'] for mwd tie in. Drlg 6600 - 7265' w/50' / 2 hr slide for azimuth control. Present MTM 11.2 going to 11.3 by 7300' Drlg 7265'- 8150'. Control drlg 50 & 25 fph 8150'-8293'. Lost all returns, spot 50 bbl Icm pill on bottom & fill.hole from via annulus; lost 230 bbl mud. Pooh to 7500' Increase circulation rate in stages to 11 bpm [drlg parameter] w/90 to 100% returns. Trip in to td, wash bridge @ 8275, wash on to bottom [precautionary], lost 50 to 100% returns before getting to rd. Then drilled on to 8293 - 8305'. Spot 70 bbl leto pill on bottom. Pooh to 7800'. Circulate @ 3 bpm allowing formation to heal to full returns. Return to rd, no hole problems Drill 8305 - 8309' [attempting to drlg / cir sample] while circulating a 70 bbl Icm pill in place [precautionary]. Lost partial returns then full returns after 833 of 4600 strokes pumped necessary to recover sample. Additional 257 bbl mud lost Pooh to 7400'. t' Operations Summary iil Rendezvous 2 04/17/01 12:00 AM 04/18/01 12:00 AM 04/19/01 12:00 AM 04/20/01 12:00 AM Brought up circulation slowly to 3 bpm w/70% to full returnes. Continued to add lost cir materialshakers by-passed.Total mud losses = 487 bbl @ rpt time. Cir / cond reducing mw from 11.3 to 11.0 ppg. Tih to 8292'. Wash / ream 8292 - 8309' [td], Isot 70 bbl mud. Rig repair - Iow drum chain, cir @ spr. Spot 25 bbl Icm pill on bottom, observe well dead, pooh to 6890'. Observe well dead & pump dry slug. Pooh, ck well static 3700' & shoe [service rig], Id bha, stand back Iwd for download. PU/MU 60'+ of coring tools & remaining bha. Continue tih to 8207 displacement 10 bbl over. Wash / ream 92' to td minor losses while washing to td string taking weight to 7k lbs while washing down - unable to determine if bridges / fill / or hole swelling. Drop coring diverter ball @ midnight. Core from 8309' - 8369'. Initial rop 8 - 30 fph, avg 45 fph, final 30 fph. Parameters = 60 rpm / 5k lbs bt wt. +/- 7 bpm / 1550 psi. Total mud lost during coring ops +/- 3OO bbl. Ck well static, pull to 6280' & spot 25 bbl hi concentration Icm pill, mud losses nill. Pooh to 7400', well static, cir bu & pump dry slug. Pooh to 2600', fill up corr [shoe 2672'], well static. Pooh to core barrels [ unfluted inter barrel procedures ] ,well static. Pjsm & recover 59.7' of core [barrels full]. Police / clean floor/prep to cut drlg line CUt 78' of drlg line. Prepare to Id remaining coring equip. Ld coring tools~ Pu / mu bha [3rd RR of bit #2] & tih to 7650' @ rpt time. Complete tih to 8000', wash & ream to start core pt of 8309', by passed shakers w/ 50% of flow to retain Icm in system. Lost 38 bbl mud, numerous spots in bore where string taking up to 15k lbs. Wash / ream 8300 - 8369' [end core run] @ < 70 fph to obtain Iwd logs across coreed well bore. Drill 8369 - 8650'. Cir bottom up & sweep hole, observe well static. Short trip to 8200', over pulls to 60k lbs over, hole fill / disp correct. Cir bottoms up & observ, well static. Pooh to bha, checking well dead @ 2600' [shoe 2672'], & bha. Ldbh, recover ra source, download Iwd data, continue to Id bha [incomplete @ rpt time]. Complete Id bha. Recover wear busing. Install test plug, xo / test upper pipe rams to 7" & rec test plug. Rig up to run 7" csg.. MU shoe / float collar [2 jt shoe track], & rih w/208 joints total ' of 7" x L-80 x 26 ppf x bt&c csg. Difficut working through 8200 ' 8325', remainder of hole down to 8637' required washing through numerous tight spots. Unable to Work below 8637'. Ld 1 jt 7", Mu landing jt to csg string. Land out csg w/207 jts in hole @ 8602.17'. Cir/cond mud / hole @ 4 bpm'/450 psi, losing 50 - 90% returnes. Pumped 100 bbls 25 ppb nutplug [mixed on fly] into csg & turned well to Dowell for cmt ops. t' Operations Summary i" Rendezvous 2 04/21/01 12:00 AM 04/22/01 12:00 AM 04/23/01 12:00 AM Sch. Dowell cmted & 7" as follows: Pumped 20 bbl chem flush, 50 bbl mud flush, lead cmt of 58.5 bbl [140sx] 12.0 ppg LiteCrete + adds followed tail cmt of 34 bbl [190 sx] 15.8 ppg GasBLOK-Class G + adds. Flushed down csg w/10 bbl 9.6 ppg brine. Complete cmt ops; Rig completed displacing cmt w/a total disp vol of 324 of 326.5 bbl of 9.6 ppg brine. Final disp press of 1000 psi, bumped 1000 over to 2000 psi. held 5 min, bled off floats held good. Install hanger pack off & test to 5000 psi. Install var 3.5 - 6" variable rams in upper cavity. Test bope 250 / 5000 psi annular 3500 psi. Install wear busing. PJSM. Schlumberger made 2 gage ring [6.13"] / junk basket runs: 1st stopped @ 8420', 2nd @ 8450', recovered brass wire [simi coiled 2 & 4 "x 1/16" & metal shavings]. Trip in hole w/geo-phone for vsp & run same w/82' stations from xxxx' to possible "free" pipe @ +/- 7544', then check shots to +/- 1000'. Complete VSP. RunCBL, Cmt top 7550'. Press test csg to 2500 psi / 30 minutes. Clean pits, clean rock washer & move out from rig, load remaining 3.5" to pipe shed. Ld 4" dp & handling tools. Retrieve wear bushing. Ru to run 3.5" tbg, organize aux tbg hardwear, mu nipples to tbg & loads guns into pipe shed. PJSM Pu guns [40'], lower completion equipment, space out pups, packer & rih w/3.5" x 9.6 ppf x L-80 x 8rd AB-mod EUE tubing as per detail (incomplete @ rpt time). Complete running 3.5" completion as per calculated tallY. Circulate one tbg volume. Correlate guns w/Schlumberger to perforation depth & set packer @ 7952'. Shear out of PBR, space out tbg & land hanger. Set back press valve,set back bops, & install x'mass tree. Test pack off & tree to 5000 psi, pull back press valve. Test tbg to -53000 psi / 30 min., bled tbg to 1000 psi & test tbg annulus to 3500 psi. Shear valve in GLM @ 2500'. Install back press valve. Secure well & clean cellar. Blow down lines, secure for move. Rig released @ midnight 23/24 Apr. Rendezvous 2 Summary 4/26/01: PULL 1" SHEAR VALVE W/BK LATCH OUT OF GLM AT 2500' RKB FREEZE PROTECT W/70 BBLS DIESEL SET 1" DGLV AT 2500' RKB COULD NOT PULL 1" DGLV OUT OF GLM AT 7850' RKB - PULL BALL & ROD ASSB. FROM 8322' WLM LATCH RHC AT 8322' WLM HAD TO BEAT FOR 5 MIN TO GET IT OUT OF XN NIPPLE CAME UP TO 7898' WLM HUNG UP IN X NIPPLE & BEAT FOR 20 MIN & PULLED EXPANDER & FISH NECK OUT OF STUCK RHC SUB. 4/27/01: PLANT 33.5" BAIT SPEAR -JARRED 140 tIMES AND UNABLE TO MOVE PAST X NIPPLE- READY FOR COIL. 4/28/01: PRESSURE FIRED 40' 3-3/8" TCP GUNS. PRESSURED WHP TO 4700 PSI, BLED TO ZERO PSI, GUNS FIRED AFTER 5 MIN 10 SEC, GOOD INDICATION OF FIRING. NO PRESSURE BUILDUP. RU SLICKLINE, TAGGED TOP OF FIRING HEAD AT 8344' MD, COULD NOT BEAT THROUGH. SET XXN PLUG IN XN NIPPLE AT 8325' MD. NOTE: X NIPPLE AT 7899' MD WILL NOT PASS LARGER THAN 2.79" OD. Phillips Alaska, Inc. Core Chip Descriptions Operator and Well NameRendezvous 2 ~ ~'~"/R~, ~.. IDate 16-April, 2001 Location ' ' ~ ~'~1/~'/~! I Described by NE NPRA~1~/, I Greg Wilson, Ken Helmold Oil Fluorescence , , ~ · o~ Chip ~ ~ Co ~e ._~ O Oil c Depth ~ -~ ~ ~ ~ Residual (fi) ~ ~ ~ ~ '~ O ~ Remarks Stain Odor % [ Color Cut Residual Fluoresc. 8309.0 ss ~L 2-3 >95 tr-1 Bioturbated, subang to subround, well consol N Y 70 bright pale yel 'slow bl~m 3ale straw med yel ~12.0 ss ~L 2-3 >95 tr-1 Bioturbat~, subang to subround, well consol N Y 50 bright pale yel ~slow bloom 3ale straw med yel ~15.0 ss ~L 4, fL >95 tr-1 Bioturbat~, subang to submund, well cons( N Y 90 brighl pale yel slow bl~m pale straw med yel. ~18.0 ss ~L 4, fL >95 tr-1 Bioturbat~, subang to subround, well consol N Y 35 bright pale yel slow bloom straw med yel 8321.0 ss ~L ' 4, fU >95 tr-1 Bioturbated, subang to subround, well con~ N Y ~ bright pale yel slow bloom straw med yel Bioturbated; traces visible; subang to submund, wel ,..' 8324.0 ss ~L 4, fL >95 tr-1 cons N Y 45 bright., pale yel slow bl~m straw med yel 8327.0 ss ~L-U 3-4 >95 tr-1 Bioturbat~, subang to subround, well cons( N Y 85 brighl ~ale yel slow bloom dark straw med yel ~0.0 ss' ~L-U 3-4 >95 tr-1 Bioturbat~, subang to subround, well cons( N Y 90 bdghl 3ale yel slow bloom dark straw m~ yel ~.0 ~ ~L 3~ ~U >95 tr-1 Clay-lin~ burrows, subang to subround, well cons~ N Y 80 brighl 3ale yel slow bl~m dark straw m~ yel.. ~.0 ss ~L-U 3~ >95 tr-1 Clay-lin~ burrows, subang to subround, well consol N Y 40 bright pale yel slow streaming straw m~ yel 8337.8 ss ~L 1-2 >95 tr-1 Bioturbat~, subang to submund, well cons( N Y 15 bright ~pale yel slow bl~m straw med yel ~41.0 ~ ~L 3-4, ~U >95 tr-1 Bioturbat~, subang to submund, well cons( N Y 40 bright 3ale yel slow bl~m straw m~ yel 8344.0 ss ~L-U 1-3 >95 tr-1 Bioturbat~, subang to submund, well cons( N Y 50 bright 3ale yel slow bl~m straw med yel 8347.0 ss ~L 2-3 >95 tr-1 Bioturbated, subang to submund, well cons( N Y 70 bright ~ale yel slow bl~m straw m~ yel ' ~50.0 ss ~L 3-4 ~U >95 tr-1 Clay-lin~ burrows, subang to subround, well cons~ N Y 60 brighl ~ale yel slow bl~m straw m~ yel ~53.0 ~ ~L 3~ >95 tr-1 Bioturbated, subang to submund, well cons( N Y 85 brighl pale yel slow bloom straw med yel ~56.0 ss~ ~L-U 3-4 >95 tr-1 Bioturbat~, subang to submund, well cons( N Y 98 brighl pale yel slow bl~m straw m~ yel Clay and sand-filled burrows, subang to submund, wel 8359.0 ~ ~L-U 3-4 >95 tr-1 consol N Y 85,bright pale yel slow bl~m dark straw med yel Bioturbat~; high ~ment clay-fill~ burrows, subang t~ ~62.0 ss ~L-U 4-5 >95 tr-1 subround, well consolidat~ N Y 50 bright pale yel slow bloom straw m~ yel Bioturbat~, relict ~dding? subang to submund, wel ~65.0 ~ ~L 3~, ~U >95 tr-1 consol N Y 80 bright pale yel slow bl~m dark straw med yel Bioturbat~ - 35% clay burrows, subang to submund ~67.0 ss ~L-U 3~, ~U >95 tr-1 well consol N Y 85ibright pale yel slow bl~m dark straw reed yel In shod, the chips from every 3 feet of core suggest that the entire cored interval is a relatively homogenous sequence of very-fine-grained slightly glauconitic bi°turbated sandstone, similar to what has been called the 'Stillstand" in the Alpine field. There is no evidence that the J4 Siltstone hag been penetrated. The fluorescence and cuts suggest that there is a high gravity oil preSent. The fluorescence will be checked again after 24 hours to compare it to Rendezvous A core, which displayed no fluorescence after being slabbed. BAKER HUGHES INTEQ CORING SUMMARY NOTES CORE RUN #1: PICKED UP 60' OF CORE BARRELS AND PROCEEDED TO RUN IN THE HOLE. WELL HAD BEEN LOSING APPROXIMATELY 40 BARRELS PER HOUR OF FLUID PRIOR TO CORING RUN. AN LCM PILL WAS MIXED AND PUMPED TO SEAL THE FORMATION. WE RAN TO BOTTOM AND WASHED 103 FEET OF FILL IN 1 HR. WE STARTED CORING AND CONTINUED TO LOSE MUD WHILE CORING. WE LOST ABOUT 300 BARRELS OF MUD WHILE CUTTING THE 60' OF CORE. CORE RUN WENT WELL WITH NO PROBLEMS. WHEN RUN WAS DONE, WE TRIPPED OUT AND RECOVERED ALL 60'. UPON INSPECTION OF THE BHA, THE BIT HAD I SPALLED CUTTER. IBH INTEQ REPRESENTATIVE: IFRED ANTONSEN I -I1~ ~ FSales Order NO' I BAKER HUGHES I Core Job Summary I INTEQ Customer: 'Phillips Alaska, Inc. Hole Size: 8 1/2" Date On: 14-Apr-01 Well: RENDEZVOUS # 2 Hole Angle: 0 DEC Date Off: 19-Apr-01 Rig.' ~ DOYON #141 Last Cs!~ Size: 9 5/8" PmplLnrs: 6 X 12 Engineer: FRED ANTONSEN Csg Shoe Depth: 2672 Mud Type: KCL Core DEPTH CORE BARREL Barrel Length Length % Coting Run Depth(ff.) Depth(ft.) Size Inner Tube Catcher Length Cut Recovered Recovery Hours ROP No. From To Type Type (feet) Ft/Hr I 8309 8369 6 314" X 4" Aluminum Low Invasion Spring60 60 60 100% 1.53 39.22 I- i I ,_ I- i CUMULATIVE PERFORMANCE 60 60 100%, 1.53 39.22 [ Corehead Usage J.' I_ Core SERIAL NO. SIZE ~.'WPE TFA FEET HOURS ROP CONDITION !% Worn) i ' ' CUT R/Hr Before After 1 4508263 8 112" X 4" ARC425C3 0.75 60 1.53 39.22 NEW 5% WORN . II BAKER HUGHES INTEQ cL,,E BARREL ASSEMBLY #1 J Company: Phillips Alaska, lnc. J 60' BBL Contractor: DOYON i ................................................ Rig Name: # 141 Well Number: RENDEZVOUS # 2 2.31~ TOP SUB :.. Complete Coring Company Rep.: RAY SPRINGER 3.7~--~ LD ADJUST SUB ~ BHA Lenglh Service Eng.: FRED ANTONSEN 4' ,~ STABIUZER i 79.67' 8 7/16" : B H I Core Barrel -- St~le: HT30 Size: 6 3/4" x 4- Length: 60' Feet Weight: 9 K. Ibs Operating Parameters 26'"-'~ OUTER BARREL MIU Torque: 30 KftLbs. 6 3/4" O.D, X 5 3/8" I,D~ Max. Pulh 571 K. lbs i ~__ PBL 8.21' W.O.B. 4'- 7 K. Ibsi ,~..=, TOOL Rotary: 50 -70 r.p.m. L..,.....=, Flow Rate: 300 g.p.m.; · Coreheads on Location Size StTle Ser. No. Cond. 1 8 1/2" ARC425C3 4508263 NEW 2 8 1/2" ARC425C3 4508510 NEW 3 8 1/2" ARC412C3 4507260 NEW 4 -~ STABILIZER 4 87/16" 5 6 7 Comments: At end of run, bit had I Spalied Cutter. 26' .-~ OUTER BARREL 6 3/4" O.D. X 5 3/8" I.D. Corehead Specifications: Hughes Christensen ,k ~ ARC425C3 ' / SIN 4508263 1 TFA .75 1.40 J-J ~ 4.-.j STABILIZER / ~ 8 7/16" ,4 8 112" ..~J ii IT BAKER HUGHES INTEQ BOTTOM HOLE ASSEMBLY Well Name & No.: RENDEZVOUS # 2 TYPE ARC425C3 HT30 PiN HT30 PiN HT30 PIN HT30 PIN HT30 PIN HT30 PIN HT30 PIN 41/'Z' IF PIN 4 1/2" IF PIN 4 1/2" H90 Pin 4 1/2" H90 Pin 4 1/2" Hg0 Pin HT30 BOX HT30 BOX HT30 BOX HT30 BOX HT30 BOX HT30 BOX 4 IlZ' IF BOX 4 1/2" IF BOX 4 IlZ' H90 BOX 4 IlZ' H90 BOX 4 IlZ' H90 BOX 4 IlZ' H90 BOX DOYON #141 4508263 Field: EXPLORATION SMes O~1~ # D~lr. 147644 1 17-Apr-01 Location: NORTH SLOPE, AK USA Depth In~ Depth out 8,309 8,369 Fish Neck Lengtt)(ft) Z36 4.00 26.00 2.37 3.99 2.39 1.68 1.8 1.4 1.83 4.01 3.75 2.31 8.21 1.4 Total :Length(fi) 5.4 31.4 35.39 61.39 65.4 69.t5 71.46 79.67 2.10 81.77 29.76 111;53 29.27 ' ' 140.8 30.47 1'71.27 1.61 ' 184.32 29.03" 707.04 172.88 357.2 386.23 1093.27 Stabilizer Description DifferenCe: Stabilizer Size STABILIZER 8 7116 STABILIZER 8 7116 RWM PREVIOUS B Blade Spiral RWM Gauge:Length 0.80 0.79 ' 1093.27 In X X 34.0 15.0 S135 4 3 6/16 14 :BHA:'. CUT60'OF CORE connection~ 4" FH Be~l~ 17.0 CUT60',RECOVERED60' FULL CORE BARREL FRED' ANTONSEN '.' *" .:~' ": I Sales Order # I 147644 .; /:..~ ....:,. ,. , BAKER HUGH" I" ! CORE RUN LOG It' INTEQ [CORE#: g_.!_a COMPANY Phillips Alaska. Inc. DEPTH IN(FT.): 8309 FORMATION- ALPINE RIG: DOYON #141 DEPTH OUTIFT.): 8369 DESCRIPTION: SANDSTONE WELL No.: RENDEZVOUS # 2 HOLE SIZE: 8 1/2" FTG. THIS RUN: 60 HOLE ANGLE: 0 DEG PREV. FOOTAGE: 0ITOTAL FT: DATE: 17-Apr-01 EQUIPMENT BARREL SIZE: 6 314" X 4" COREHEAD/BIT #' ARC425C3 1 SURF TEMP 50 LENGTH (ft): 60 SERIAL No. ' 4508263 DH TEMP. 158 INNER TUBE TYPE: ALUMINUM SIZE: 8 1/2" X 4" SPACING L.SHOE/CATCHER: LOW INVASION SPRING DAFD TOOL: NO CORE JAM INDICATOR: INNER TUBE STABILIZER' lYES BIT END BEARING: COREHEAD CONDITION: IR OR DC LOC BIS GI16 CC R PLD o 0 NO A X I NO ,,, 1 1 NO A X I NO FULL CORE BARREL BIT CONDITION AT RUN START: INEW BIT CONDITION AT RUN END: [5% WORN 1 SPALLED CU'I-rER B~.CKGROUND PARAMETERS t OFF BTM STRING WTS TOROUE(KFtLbs) BALL VALVE; PRESS IHC, PRE~SURE - BALL SEATED ROTATING IKIbs) 156 ON BOTTOM 15 PRESSURE INCREASE 210 PSI IOFF BOTTOM 1500 PSI DOWN {Klbs) 154 ON BO'F'~,,O.M 1550 PSI ' MUD VISC WT PV YP GEL WL % SAND, SOLIDS TYPE CORING FLUID 90 10.3 30 24 6/17 2,8 0,1 10.9 HOUR) OF START ,, PICK UP START IN DROP CORING & P.O.O.H. LAY DOWN BBL HOLE BALL ' CONNS; SERVICE BBL STD BCK BBL START: 4:00 PM 5:30 PM 11:30 PM 12:00 AM 2.'00 AM 10:30 AM STOP: · 5:30 PM 10:30 PM 12:00 AM 2:00 AM 10:30 AM 1:00 PM INTERVAL 1.5 S 0. s 2 8.5 2,50 CONNECTIONS: Connection I 2 i , i , i , i , i., PERFORMANCE DePth in Depth Out Feet Cut Coring ROP FTIHR Feet Recovered % Recovered Hours 8309 8369 60 1.53 39.22 60 100% EFFICIENCY:I,looo~IREASON FOR STOPPING CORING: J FULL CORE BARREL SPARE PARTS USED: 12 ALUMINUM INNER BARRELS " 2 INER BBL STABS 1 EA SPRING CORE CATCHER lEA LOW INV SHOE 1 EA UPPER SHOE 1 EA THRUST BEARING IEA BEARING RETAINER , ,, Customer Representative: I RAY SPRINGER I BH INTEQ Representative: I FRED ANTONSEN q q q q 4 II II II II m ~ m SALES ORDER t~: INTEO t4114,1 COMPANY: Phillip~AL, mk~lng. COREBARRELStZE: 13/4'X4'XM' DATE. :' 11~1/01 ~F-'~EF.~ WEII No.: RENDEZVOUS # 2 Bff SIZE & TYPE : i 1/2" X 4' ARC425C3 CORE No: I FRED ANTC)I~EN RIG No. : DOYON 141 CORE INTERVAL : 8309 - 83~ ~0' REC.% : 100~, ~ NO. R.O.P PENETRATION RATE, FT~R. OPERATING CONI~TIONS FORMAl'tON FT. CORED. I~n/Ft Fbi-lin W.O.B R.P.M F.RATE PRESS. TORQUe[ TYPE IK)09 0.00'k ---J--:~ l±iil .. ,,l,II ..- 4 50. 300 1550 -- .N.PINE .~o ~ ,.oo ~.~ BI I! , ~o.. ~ ~, 5-,0o I~16 7 2.~0 30,0 '''I ml-~'-m 7 60 300 1550 58~0 .N.PINE ~4 ~ ~.~o ao.o BBII ? ~o ~o ~5~ .~o ~U~INE 8~ ~6 ~.o~ ~.o ~11 ~ ~o, ~ ~.o ..o ~o =o ~.oo ~o.o ~!1 ~! ~ ~o 3oo ~ ~ /~u:~.~ 8330 ~ ~.oo 13.o '''l'l.--~'-m_ ~ 70 30o ,~o 5700 ~,.E 8331 22 ZOO 30.0 ~m 7 70 300 1550 5~30 ALPINE 8332 23 2.00 3O.0 Bill 7 70 300 1550 5800 ALPINE 8333 24 2.oo 3o.0 /111 ~ ~o 3oo ~5.o .oo ~.E .334 25 2.oo 30.0 III. 7 70, 300 1550 57'00 ALPINE .33~ 26 2.0o 3o.o /111 7 70 300 1550 5800 ALPINE ~ ~7 2.oo 3o.0 IIII ~ m-~l-I 7 70 300 1550 5800 N.PINE 8338 29 1.00 ~0.0 ' ~ [] I 7 70 300 1550 5700 N. PINE 8339 3o ~.00 .0.0 /11 7 70, 300 155q 5800 ALPINE 8340 31 1.00 60.0 ''lI m II ~ 7 70 300 1550 5800 ALPINE ,34~ 3~ ~.00 .0.0 /11 7 7o 30o ~550 .00 8342 33 ~.00 60.0 III ~ 70 300 1550 5700 ALPINE ,343 34 2.00 30.0 """ m m-m~ 7 70 3oo ~. .oo ~,.E ,34~ 35 .!.00 .0.0 III ' 7 70 3oo ~e .00 ALF~.E ,345 3, ~.00 60.0 III 7 70 ~ ~e 5,OO 8346 37 1.00 60.0 'II ~ .llm-{-~~---- 7 70 300 1550 5700 ALPIN. E 8347 38 1.00 60.0 ~/i~~ 7 70 300 1550 5800 ALPINE, 8348 39 1.00 60.0 '""---- 7 70 300 1550 5800 N.PINE 8349 40 1.00 60.0 III ? 70 300 1550 5800 Al. PINE 8350 41 .2.00 30.0 ~ · I 7 70 300 1550 5700 ALPINE,, 6352 43 1.00 60.0 m · I , 7 70 300 1550 5800 ALPINE ,~3 4, ~.00 60.0 ~ ·1 7 70 3oo ~550 5,00 ~NE ~5 4. ~.00 60.0 ~ ·l ? 70 = ~= moo AU=~N.E 8356 47 1.00 60.0 ml~l 7 70 300 1550 5800 'N.PINE 8358 49 2.00 30.0 / l ! '7 70 300 1550 5700 ALPI..NE 835~ 50 2.00 3o.0 ~ 7 7o 30o ~ .00 ~,,E ,~0 5~ 2.0o 30.0 ~ I 7 70 300 ~s50 .oo AU,NE 8362 53 1.00 60.0 I 7 70 300 1550 ,5700 ALPINE ,3.3 ~, ~.00 60,0 /11 7 70 30o ~5,0 ~ AU=,N.E 8385 56 1.00 60.0 ~~l 7 70 300 1550 5800 ALPINE ' - ,7 ~.oo ,.o mmm ~mmm~ ,7 170 3~ 1550 5700 ALPINE 83.8 '~ 2.OO 30.0 III 7 70 300 1550 5800 ALPINE ., ,o 2.oo 3o.0 /11 7 70 300 1550 5800 ALPINE i I llll) I , I IIIII 7 70 300 1550 5700 ALPINE i To~l Minu~s 92 mmm · Ill Ill Ill .amm--im~ "" m-mm il!~ ... --"mm " Ill II ''' mlil mmm mmim Nmi , m mmmm I mmmm il.m, 'm 'i I .~1. o^~I .~-i o. I^..Ik, O1001ACsOESCmP~ON !REVI O^~E I "¥ I CK A"P t OES~'~. BY LOUNSBURY ~ ASSOC. ' '-~' ,~¢ ¢' ~ 2. COORDINATES SHOWN ARE ALASKA STATE PLANE ~ ~ *- ~¢~ ZONE 4. NAD 27. ~~.~ ' ~%~]~ MRCO 3PA~ ¢ll~ ~~ 3. GEOGRAPHIC COORDINATES ARE NAD 27. ~ ~~,~}~ 4. ELEVATIONS SHO~ ARE BRITISH PETROLEUM I ' ~ MEAN SEA LEVEL DATUM. ~ _~, % ~ ~o° ~ ~ ', 5. ALL DISTANCES ARE TRUE.~,~~~ ' %~e' ~, ' 7. DATE OF SURVEY: 5/2~/2~1, FB L~1-15 P.61. ~ % _RENDEZVOUS ~2 , ~ , LOCATED WiTHiN PROTRACTED % %~'~'~ ~ ~ SEC. 6, T 9 N, ~ R 2 E, .f' ' ,,~~~¢ UN]AT MERIDIAN. ~ ~' ~ ~ ~ ' LAT 7~'~9'57.176" ~' ~ ~ ' ~ = .. ,' Y = 5,913,243.1~ ~ ,~E :0 ,, I~zzvous ' ~ .. , ~.~~ ' ~o 17~7' F.N.L., 2525' F.W.L. ~ ~ ~~ ~ ,~ ~ ~ "~ ~ROUND ELEVATION = 92.7' RIG PAD ELEV. 95.7' . VICINITY MAP SCALE: 1" = 2 MILE'S ~ ~F ~9th ~ ~'~ '. k ~ ¢ ~ ,,SCALE:', ~' i ReUDeZVOt ~ ~ ' . SURVEYOR'S CERTIHCA TE ~~ ' k ' I HEREBY OER,FY ~AT I A,.PR~ERLY'. ' " REGIS~RED AND LIOEN~D TO PRAO~CE ' ~. . .. LAND SUR~N¢ IN .~E STA~ A SURLY D~E BY ME ~.UNDER MY . DIREGT SUPER~SION AND ~A.T ALL .' DIMENSIONS AND O~ER DETAILS '[~}' PHILLIPS Alaska, Inc.' RENDEZVOUS 2 (~~'A Subsidiary of PHILLIPS PETROLEUM COMPANY EXPLORATORY WELL CONDUCTOR ~' ASBU]LT LOCATION CADD FILE .0. I DRA~NO NO: ISHEET: . L~6~4~¢ '5/2~/~ CEA-MIXX-6¢1D41¢, 1 OF ~ , 1 Measured Inclination Direction Depth (feet) (degrees) (degrees) 0.00 0.00 0.00 108.00 0.00 0.00 355.56 0.53 89.32 530.19 0.48 98.93 720.01 0.43 71.36 905.38 0.34 66.18 1368.08 0.43 305.91 1840.75 0,78 305.21 2306.43 0.48 255.93 2607,43 0.50 272.20 2759,15 0.50 296.40 2852.37 0.50 291.25 3321.00 0.72 283,49 3792,84 1.00 119,37 4265.94 0,87 104.22 4733.74 0,17 32.10 5199,48 0.12 126,32 5670,83 0.06 33.46 6140.89 0.12 180.28 6610,75 0.61 62.26 7081,14 3.27 56,87 7551.65 2.24 51.86 8017.67 1.44' 34.09 8485,54 1.10 21,47 8557.88 1.09 19.48 8650.00 1.09 19.48 Directional Survey' o Vertical Latitude I~'e pCa~"~¥ert!cal D gleg Depth ~'S~~.~,,~_.,, (feet) (feet) (feet) (~'~.'~.~eg/lOOf) 0.00 0.00 N 0.00 E - "~'~ ~'0.00' ~ TIE-IN 108.00 0.00 N 0.00 E 0.00 0.00 355.56 0.01N 1.13 E 0.01 0.21 530.18 0.09 S 2.66 E -0.09 0.05 719.99 0.01 N 4.12 E 0.01 0.12 905.36 0.45 N 5,28 E 0.45 0.05 1368.05 2.02 N 5.10 E 2.02 0.14 1840,70 4.93 N 1.02 E 4.93 0.07 2306.35 6,29 N 3.48W 6,29 0.13 2607,34 6.03 N 6.02W 6.03 0,05 2759.05 6.35 N 7.27W 6.35 2852,27 6.67 N 8,01W 6.67 3320.88 8.09 N 12.76W 8.09 3792,70 6.76 N 12.04W 6.76 4265,73 3.85 N 4.95W 3.85 4733,51 3,58 N 1.13W 3.58 5199,25 3.88 N 0.35W 3.88 5670.60 3.79 N 0,20 E 3.79 6140,66 3.50 N 0.34 E 3.50 6610.51 4,16 N 2.54 E 4.16 7080,59 12.66 N 16,01 E 12.66 7550.55 25.69 N 34.50 E 25.69 8016.33 36,16 N 44.95 E 36.16 8484.08 45.21N 49.89 E 45,21 8556.41 46,50 N 50,37 E 46.50 8648.51 48.15 N 50.95 E 48.15 0.14 0.05 · 0.05 0.36 0.06 0.18 0.05 0.03 0.04 0.14 0.57 0.22 0.21 0.09 0.06 0.00 Job No,: AK-MM-10101 Well No.: Rendezvous #2 End of Well Report Page9 J CONFIDE ./E Kuparuk RiVerUnit North Slope, Alaska EXPLORATION_NON-PAD' Slot Rendezvous 2 Rendezvous 2 Job No. AKMMI0101, Surveyed: 19 April, 2001 1004192733 SURVEY REPORT 22 May, 2001 Your Ref: ~C~,q32CCC70- Surface Coordinates: 5913243.10 N, 285381.98 E (70° 09' 57.1764" N, 157° 43' 37.5127" VV) Kelly Bushing: 123.05ft above Mean Sea Level DRILLING SERVICE=; A Halliburton Company Survey Ref: svy9519 Sperry-Sun Drilling Services Survey Report for Rendezvous 2 Your Ref: ~e,14~J-2e6-3¢o ~<-~ / c~ ~, ~.o~(o~ Job No. AKMM10101, Surveyed: 19 April, 2001 Kuparuk River Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -123.05 0.00 108.00 0.000 0.000 -15.05 108.00 355.56 0.530 89.320 232.51 355.56 530.19 0.480 98.930 407.13 530.18 720.01 0.430 71.360 596.94 719.99 905,38 0.340 66.180 782.31 905.36 1368.08 0.430 305.910 1245.00 1368.05 1840.75 0.780 305.210 1717.65 1840.70 2306.43 0.480 255.930 2183.30 2306.35 2607.43 0.500 272.200 2484.29 2607.34 2759.15 0.500 296.400 2636.01 2759.06 2852.37 0.500 291.250 2729.22 2852.27 3321.00 0.720 283,490 3197.82 3320.87 3792.84 1.000 119.370 3669.64 3792.70 4265.94 0.870 104.220 4142.68 4265.73 4733.74 0.170 32.100 4610.46 4733.51 5199.48 0.120 126.320 5076.20 5199.25 5670.83 0.060 33.460 5547.55 5670.60 6140.89 0.120 180.280 6017.61 6140.66 6610.75 0.610 62.260 6487.46 6610.51 7081.14 3.270 56.870 6957.54 7080.59 7551.65 2.240 51.860 7427.50 7550.55 8017.67 1.440 34.090 7893.28 8016.33 8485.54 1.100 21.470 8361.04 8484.09 8557.88 1.090 19.480 8433.36 8556.41 8525.47 8650.00 1.090 19.480 8648.52 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5913243.10 N 285381.98 E 0.00 N 0.00 E 5913243.10 N 285381.98 E 0.01 N 1.14 E 5913243.08 N 285383.12 E 0.09 S 2.68 E 5913242.93 N 285384.65 E 0.01 N 4.14 E ' 5913243.00 N 285386.11 E Dogleg Rate (°/'~OOft) 0.000 0.214 0.056 0.117 0.46 N 5.30 E 5913243.41N 285387.29 E 0.052 2.03 N 5.15 E 5913244.98 N 285387.18 E 0.145 4.93 N 1.08 E 5913247.99 N 285383.20 E 0.074 6.28 N 3.40W 5913249.47 N 285378.76 E 0.127 6.02 N 5.94W 5913249.29 N 285376.22 E 0.047 6.34 N 7.19W 5913249.64 N 285374.97 E 0.138 6.67 N 7.93W 5913249.99 N 285374.24 E 0.048 8.10 N 12.70W 5913251.56 N 285369.51E 0.050 6.77 N 12.00W 5913250.21 N 285370.18 E 0.361 3.86 N 4.92W 5913247.10 N 285377.17 E 0.059 3.58 N 1.11W 5913246.71N 285380.98 E 0.178 3.88 N 0.35W 5913246.98 N 285381.74E 0.046 3.79 N 0.19 E 5913246.88 N 285382.28 E 0.029 3.50 N 0.32 E 5913246.59 N 285382.40 E 0.037 4.18 N 2.53 E 5913247.20 N 285384.63 E 0.144 North Slope, Alaska EXPLORATION NON-PAD Vertical Section Comment 0.00 0.00 0.01 -0.09 0.01 0.46 2.03 4.93 6.28 6.02 6.34 6.67 8.10 6.77 3.86 3.58 3.88 3.79 3.50 4.18 12.67 N 15.99 E 5913255.32 N 285398.32 E 0.566 12.67 25.69 N 34.46 E 5913267.80 N 285417.15 E 0.225 25.69 36.16 N 44.90 E 5913277.97 N 285427.89 E 0.209 36.16 45.21 N 49.84E 5913286.88 N 285433.08 E 0.094 45.21 46.50 N 50.32 E 5913288.16 N 285433.60 E 0.054 46.50 48.16 N 50.91E 5913289.79 N 285434.23 E 0.000 48.16 MWD Magnetic 22 May, 2001 - 21:46 Page 2 of 3 DriilQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for Rendezvous 2 Your Ref: 50103206370 Job No. AKMMI0101, Surveyed: 19 April, 2001 Kuparuk River Unit North Slope, Alaska EXPLORATION NON-PAD All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 24.900° (07-Apr-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True)'. Based upon Minimum Curvature type calculations, at a Measured Depth of 8650.00ft., The Bottom Hole Displacement is 70.08ft., in the Direction of 46.591° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 8650.00 8648.52 48.16 N 50.91 E Comment Projected Survey '-~ Survey tool program for Rendezvous 2 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 8650.00 8648.52 Survey Tool Description MWD Magnetic 22 May, 2001 - 21:47 Page 3 of 3 DrillQuest 2.00.08.005 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 September 4, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Rendezvous #2 (201-007) Completion Report Dear Ms. Commissioner: Phillips Alaska, Inc., as operator of the Rendezvous #2 exploration well, submits the attached "Well Completion Report" (AOGCC form 10-407). Other attachments to the completion report include the directional survey, report of daily well operations, core description and an as-built. We will send under separate cover the logs, the mud logs, and other well data and reports. 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 Bill Lloyd at 265-6531. Sincerely, P. Mazzolini Exploration Drilling Team Leader PAI Drilling SEP 1 1 ZOOl Alaska Oit & Gas Cons. Commission ,Anchorage PM/TJB/skad ORI®INAL MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O.Taylor,c~ DATE: Chair Tom Maunder, ~.~~ P.I. Supervisor THRU: August 12, 2001 FROM' Lou Grimaldi, SUBJECT: Petroleum Inspector Location Inspection Rendezvous #2 .,Ph.!!!!p.s Alaska Inc. ,.: _;,,,: ,~.; ,~. ,,, Sunday, Auqust 12, 2001;, I made a Location Inspection on Phillip's Suspended well "Rendezvous #2". This exploratory location was clean with no evidence of ddlling activity other than the Suspended tree and wellhead guard around it. The well sign hung on the tree was of a somewhat poor design, made of plywood and hung with wire on the tree this well sign will most likely end up on the Tundra. I requested that plans be made to secure this sign in a more secure manner. Rick Overstreet (P.P.Co. rep) will take care of this. The information on the sign matched the Permit to Drill SUMMARy: I made a Location Inspection on Phillip's suspended Exploratory well "Rendezvous #2". ,A.tta,.c. hments' Rendezvous #2 tree 8-12-01 LG,jpg Rendezvous ~Y2 Airshot 8-12-01 LG.jpg cc: Overstreet/Morrison (Phillip's Alaska Inc.) NON-CONFIDENTIAL 010812-Location Inspection Rendezvous #2-LG.doc PHILLIPS Alaska, Inc! A Subsidiary of PHILLIPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DA TA * FROM: Sandra D. Lemke, ATO1486 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Rendezvous 2 DATE: 08/07/2001 Lisa Weepie AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Transmitted herewith is the following: Rendezvous 2 501032036300 9ermit 201-007 CD R~/~(dig/tal) and one blue#ne print each - logging data ~ [~ 9~ k Sperry Sun - DGR/CNP/SDL/EWR/ROP/DGR/BAT; LIS data; log image files and BAT/VDL .lPG's; .lune 28,2001 CD ROyd/g/ta/) and core photo report ~P t ~ ;L}O u- Core Labs :Inc. Slabbed Core - Natural and U.V. Color core photos with CD ROM digital core photos, ~CD18326; REPORT /Core Labs Inc. Core Analysis results; CL file 57111-01105; 7/9/2001 P/ease check off each/tem as rece/ved, s/gn and return one copy of the transm/tta/ to the address be/ow. The other copy is for your flies All data to be held confidential until State of Alaska designated release date (AOGCC) Approx. 5/2003 *"On behalf of itself and [Anadarko Petroleum], Phillips Alaska, Inc. submits the attached data for the Rendezvous 2Well, Drilling Permit No. 201-007as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the use of the Commission in carrying out its duties, we question whether any future disclosure to DNR or the public would be appropriate or valid. However, it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, so that we may be heard on the issue." CC: Greg Wilson, PA:I Geologist Recei~ Date: Return receipt to: Phillips Alaska, Inc. ATrN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 RECEIVED AUG 0 8 2001 Alaslm 0il & Gas Cons. Commiltaion ~c~orage Prepared by: Sandra D. Lemke Phillips Alaska TI' Technical Databases R£S£R¥OIR OPTIHI2ATION ao ~ ~o,o 7 CORE LABORATORIES CORE ANALYSIS RESULTS PHILLIPS ALASKA, INC. "RENDEZVOUS" #2 COLVILLE RIVER - SW FIELD UMIAT MERIDIAN, ALASKA CL FILE #57111-01105 Performed by: Core Laboratories 3430 Unicorn Road Bakersfield, CA 93308 (661) 392-8600 Final Report Presented July 9, 2001 TABLE OF CONTENTS DESCRIPTION OF SERVICES SECTION CORE ANALYSIS DATA - TABULATED RESULTS HYDRAULIC UNIT ANALYSIS RESULTS PROFILE PERMEAMETER RESULTS CORE INVENTORY INTRODUCTION Core Laboratories was selected by Arco Alaska Inc. to perform a core analysis study upon samples recovered from the Colville River- SW Field, Umiat Meridian, Alaska. Conventional aluminum inner barrel cores were submitted. Presented herein are the results of analysis. This report is divided into five sections. The first section provides a description of services. The second section contains tabulated results of standard PKS analysis. Hydraulic unit classifications in tabular presentation are i~cluded in the third section,. The fourth section contains results of pressure- decay profile pereameter measurements performed upon the slabbed core, and a core inventory comprises the final section.. I, · Core Processing Cores were handled in the field, and all core processing was performed by Core Laboratories personnel from our Anchorage office. Core Gamma Surface Log Each core was scanned for natural gamma radiation utilizing Corelab's gamma spectrometer. · Total gamma radiation is reported in APl units. Core Sampling and Slabbing After the gamma measurement, a sample segment approximately three tenths of a foot long was tal~en from each foot of core for horizontal and vertical plug sampling. The remaining core from each foot was slabbed parallel to the core axis utilizing a one/third - two/thirds cut. Liquid nitrogen was used as the blade coolant. For photography, viewing, description and additional sample selection by Phillips' representatives the one-third sections were placed into slab boxes with styrofoam inserts. Each of the approximately seven tenths of a foot segments of the two-third bulk core (left after the material for the plug samples had been removed) were preserved by wrapping with six layers of Saran wrap, three layers of aluminum foil, and then dipping in Core Seal. Sample Preparation Both horizontally and vertically oriented one-inch diameter plugs were drilled from each of the three-tenth foot core sections taken for sampling. Isopar mineral oil was used as the bit coolant and lubricant. Each plug was weighed, wrapped with Saran wrap and aluminum foil, and sealed in a sample ja~ as drilling was completed. After all of the samples were taken, the plugs were packaged and shipped to our Bakersfield California facility. Analysis Techniques Fluid Extraction Samples taken with horizontal orientation were weighed and placed into tared extraction thimbles. Water and the oil were extracted from the samples by Dean Stark methods with toluene as the solvent. The samples were held in the Dean Stark extractors for a minimum of sixteen hours after which the receiving tubes were periodically checked to determine when the samples ceased to produce water. The plugs were removed from the Dean-Stark extractors after stable water readings had been obtained. Complete hydrocarbon extraction was conducted using soxhlet extractors with methylene chloride as the solvent. Cleaned samples were removed from the soxhlets and dried in a convection oven at 230°F for a minimum of forty-eight hours and were removed once their weights had stabilized. The dried samples were cooled to laboratory temperature in a desiccator prior to analysis. Samples designated for vertical permeability determinations were "batch" cleaned in large Dean Stark extractors with toluene to remove water and then transferred to soxhlet extractors for batch cleaning with methylene chloride. Drying was performed as for the horizontal plugs prior to permeability measurements. Grain Density Determinations Grain yolumes were determined using a Boyle's Law extended range helium porosimeter. Metal jacket and end-screen weight and volume corrections were applied to any jacketed samples. Grain densities were calculated using Equation 1. 5ma = -)~g (1) Where: 5ma = Mg = = Matrix / grain density (g/cc) Grain mass (g) Grain volume (cc) Confining Pressure for Porosity and Permeability Measurements Following grain volume determinations, the plug samples were placed into a Hassler-type holder and a confining pressure of 400 psig was applied. Measurements made with a confining pressure of 400 psig are considered to be essentially "ambient" condition measurements. The minimal pressure acts to prevent gas by-pass during measurements but does not compress the samples. Porosity Determination Direct pore volume measurements were made upon confined samples utilizing Boyle's Law double-cell methods. Porosity values were calculated using Equation 2. + I/~ * 1 O0 (2) Where: ~ = Porosity (%) Vp = Pore volume (cc) Vg = Grain volume (cc) Fluid Saturation Calculations Oil and water saturation results were calculated using Equations 3 and 4. SO = SW -- M~ -Ma -M,,. · * 100 g (3) (4) I . Where: S0 = Mf = Md = Mw Vw = <30 = Vp = Oil saturation (%) Water saturation (%) Fresh sample mass (g) Extracted and dried sample mass (g) Extracted water mass (g) Extracted water volume (cc) Density of oil Pore volume (cc) Permeability to Air Permeability determinations were made following the pore volume determinations again using Hassler-type core holders. The permeability values were calculated utilizing Darcy's Equation for compressible fluids, Equation 5. Where: Ka = Permeability to air (md) Pa = Atmospheric pressure vg = Gas viscosity (cp) AP = Differential pressure ~P = Mean pressure Qa = Flow rate (cc/sec) L = Length (cm) Vb = Bulk volume (cc) Phillips Petroleum Co. Rendezvous 2 Colville River - SW File No.: 57111-01105 Loc.: 'Sec. 8.T9NIR2E APl No.: 50-103-20363 CORE ANALYSIS RESULTS 8309.0 - 8368.7 Core # 1 Cut 60' Recovered I 8309.1 0,083 0,058 13,7 35,4 35.0 70,4 1.01 2,68 2 8310,1 0,080 0,055 13.0 17,0 56.3 73,3 0.30 2.68 3 8311.1 0,086 0,029 11.5 t2.0 69.6 81,6 0.17 2.68 4 8312,1 0.088 0,067 t3.6 17.9 52.9 70,6 0,34 2,67 5 8313.1 0,090 0,078 13,7 30.7 46.3 77,0 0,66 2.67 6 8314.1 0.091 0,069 12.8 23.2 47.5 70.7 0.49 2,68 7 8315.1 0,098 0.056 13,3 23.9 50.6 74,5 0.47 2.68 8 8316,1 0.030 0,023 9.5 19.2 61.9 81.1 0,31 2,70 9 8317,1 0,057 0.082 12.3 15.8 60.9 76.7 0,26 2.68 10 83t 8.1 0.063 0,081 13.2 16.5 58.2 74,7 0.28 2,67 11 8319.1 0.078 0,066 13.2 18.2 53.6 71,8 0,34 2,67 12 8320.1 0.092 0,081 14.0 23,3 47.2 70,5 0,49 2.67 13 8321.1 0,085 0,077 13,5 18.4 55.0 73.4 0,33 2.66 14 8322,1 0,086 0,055 14.1 20,7 53,4 74,t 0.39 2.67 15 8323.1 0.050 0,051 12,1 42,6 44,6 87.2 0,96 2.68 - 16 8324,1 0.053 0,056 12.7 30.7 47,5 78.2 0,65 2.68 17 8325.1 0,073 0.057 12.9 28,0 47.8 75.8 0.59 2,68 18 8326.1 0.102 0.054 14.6 31,0 45.6 76,6 0,68 2,68 19 8327.1 0.12I 0.110 15.3 20.7 45.3 68.0 0.46 2.71 20 8328.1 0.089 0.068 13.5 38.6 36.0 74.6 1.07 2.68 21 8329.1 0.132 0.081 15.0 39.1 34.7 73,8 1,13 2.68 22 8330,1 0.101 0,086 14,7 38.5 37.8 76.3 1.02 2.69 23 8331.1 0.090 0,088 13.2 17,3 54,3 71,6 0.32 2.68 24 , 8332.1 0.159 0.073 14,6 20,1 50.8 70,9 0,40 2.72 25 8333.1 0,098 0.068 13,9 20,8 52.4 73.2 0,40 2,67 26 8334.1 0,102 0,093 13,6 21.4 50.7 72,1 0,42 2.68 27 8335.1 0.096 0.064 13.0 31,1 45,8 76.9 0.68 2.68 28 8336.1 0,077 0.072 13,0 25,9 46.4 72.3 0.56 2,68 29 8337.1 0.065 0,046 12.3. 21,5 69.6 81,1 0,36 2.68 Sst It tan vsity It stn wh-gtd flu Sst It tan vsity It atn wh-gld flu Sst gry-it tan vfgr vslty sh It sp stn wh-gld flu Sst It tan vfgr vsity It stn wh-gld flu Sst g~y-it tan vfgr ~ It ap stn wh-gld flu Sat It tan vfgr vsity It stn wfl-gid flu Sst It tan vfgr vslty It stn wh-gld flu Sst gry-R tan vfgr vsity It ap stn wh-no flu Sst gry-it tan vfgr vslty It sp sin wh-gld flu Sst gry-it tan vfgr vaity It sp stn wh-gld flu Sst Ittan vfgr vslty It s~n wh-gld flu Sst E tan vfgr vstty It stn wh-gld flu Sst It tan vfgr valty It stn wh-gld flu Sst It tan vfgr vsity It sin wh-gld flu Sst gry-It tan vfgr vsity It strk sin wh-gld flu Sst gry-lt ~ vfgr v~tylt strk stn wh-gld flu Sst it tan vfgr vslty It stn wh-gld flu Sst It tan vfgr vsity It stn wh-gld flu Sst It tan vfgr vaity It stn wh-gld flu Sst It tan vfgr vslty It stn wh-gld flu Sst It tan vfgr v$1ty It sin wfl-gld flu Sst It tan vfgr vslty It stn wh-gld flu Sst It tan vfgr vsity Itstn wh-gtd flu Sst It tan vfgr vslty It stn wh-gld flu Sst It tan vfgr vslty It stn wh-gld flu SSt It tan vfgr vslty It stn wh-gld flu Sst It tan vfgr vslty It stn wh-gld flu Sst It tan vfgr vslty it stn wh-~d flu Sst It tan vfgr vsity It stn wh-gld flu Phillips Petroleum Co. Rendezvous 2 Colville River - SW CORE ANALYSIS RESULTS File No.: 57111-0110,5 Loc.: Sec. 8-TgNIR2E APl No.: 50-103-20363 30 8338.5 0,094 0.079 14.4 24,8 50.3 75.1 0.49 2.67 31 8339.1 0.056 0.069 13.5 23.5 48.1 71.6 0,49 2.67 32 8340.1 0,111 0.073 14.4 29,8 43,9 73.7 0.68 2.67 33 8341,1 0,097 0,086 14.3 28,3 45.8 74.1 0,62 2.68 34 8342.1 0.116 0,093 13,8 28.1 49.0 77.1 0,57 2.67 35 8343.1 0,111 0,078 13,7 29.9 47.1 77,0 0,63 2.67 36 8344,1 0,104 0.075 t4.3 24,1 49,5 73.6 0.49 2,68 37 8345.1 0,099 0.083 14.0 28,9 44,9 73.8 0,64 2.68 38 8346,1 0.115 0.082 14.7 27.6 49,1 76,7 0.56 2,68 39 8347, t 0,107 0,076 t5.3 25.1 50.2 75.3 0,50 2.70 40 8348.1 0.074 0.077 13,6 20.5 51,7 72,2 0.40 2.67 41 8349.t 0,075 0.068 12,t 20,0 59.1 79,1 0,34 2,68 42 8350,1 0.078 0,053 12.8 2'1,8 57,4 79,2 0,38 2,68 43 8351,1 0.082 0.086 12.9 21,3 57.5 78.8 0,37 2.68 44 8352.1 0.101 0.071 13.2 29.5 46.1 75.6 0,64 2.68 45 8353,1 0,149 0,099 14.4 34).9 44.1 75.0 0,70 2.67 46 8354,1 0.132 0,092 t4.1 29.4 44.5 73,9 0,66 2.68 47 8355. t 0.163 0.130 14.3 36.8 39.8 76.6 0.92 2.68 48 8356.1 0.201 0.149 14.2 40.1 42.4 82.5 0.95 2.67 49 8357.1 0.215 0.134 13,9 29.8 43.3 73.1 0.69 2.67 50 8358.1 0.218 0.196 14.4 38.8 41.5 80.3 0.93 2.67 51 8359.4 ' 0,222 0,172 14.7 30.3 41.6 71.9 0.73 2.68 52 8360,4 0,087 0.153 13,6 60.7 18.5 79.2 3.28 2.67 53 8361.4 0,110 0.076 13.6 27,2 47.2 74,4 0,58 2.67 54 8362.1 0.092 0.061 13,3 21,8 56.6 78.4 0.39 2.67 55 ' 8367.1 O. 100 0.082 14.0 34.3 44.4 78.7 0.77 2.67 Sst It tan vfgr vsity It stn wh-gld flu Sst It tan vfgr vsity It sin w~-gkl flu Sst It tan vfgr vsity It sin wh-gld flu 8st It tan vfgr vslty It stn wh-gld flu Sst It tan vfgr vslty It stn wh-gld flu Sst It tan vfgr vsity It stn wh-gld flu Sst It tan vfgr vsity It stn wh-gld flu Sst It tan vfgr vsity It stn wh-gld flu Sst It tan vfgr vslty It stn wh-gld flu Sst Ittan vfgr vsity Itstn wh-gld flu Sst It tan vfgr vsity It stn wf~gld flu Sst It tan vfgr vslty It stn wh-gld flu Sst It tan vfgr vslty It stn wh-gld flu Sst It tan vfgr vslty It stn wf~gld flu Sst It tan vfgr vslty It stn wh-gld flu Sst It tan vfgr vsity It stn wh-gld flu Sst It tan vfgr vsity It sin wh-gld flu Sst It bm vfgr slty rn stn wh-gld flu Sst It bm vfgr sity m stn wh-gld flu Sst tan vfgr vsity It stn wh~glcl flu Sst It bm vfgr rdty m stn wh-gtd flu Sst It bm vfgr valty m stn wh-gld flu Sst tan vfgr vsity It sm wh-gld flu Sst tan vfgr vsity It stn wh~gld flu Sst tan vfgr vslty It stn wh-gld flu Sst tan vfgr vsity It stn wh-gtd flu Phillips Petroleum Co, Rendezvous 2 Colville River - SW HYDRAULIC UNITS 8309,1 0,15120 0.024 7 8310,1 0.16407 0.025 7 8311,1 0.18342 0.024 7 8312,1 0.16069 0.025 7 8313,1 O, 16023 0,025 7 8314,1 0,18096 0.027 7 8315, t O. 17547 0,027 7 8316.1 0.16807 0.018 7 8317,1 0.15215 0.021 7 8318.1 0,14174 0.022 7 8319.1 0,15880 0.024 7 8320,1 0.15685 0.025 7 8321.1 0.15844 0.025 7 8322.1 0.14912 0.025 7 8323,1 0.14668 0.020 7 8324,1 0.13965 0.020 7 8325,1 0.15919 0.024 7 8326,1 0.15296 0,026 7 8327.1 0.15413 0,028 7 8328.1 0,16345 0.025 7 8329.1 0.16632 0,029 7 8330,1 O. 15075 0,026 7 8331.1 0,17072 0.026 7 8332.1 0,19059 0.033 7 8333,1 0.16425 0.026 7 8334.1 0.17326 0.027 7 8335,1 0.18104 0.027 7 8336,1 0.16037 0,024 7 8337.1 0,16231 0,023 7 File No,: $7111-0110S Loc,: Sec, 8,TgNIR2E APl No.: 60-103-20363 8309,1 0,15120 0.024 7 8310.1 0.16407 0,025 7 8311,1 0,18342 0.024 7 8312.1 O, 16069 0.025 7 8313.1 0.16023 0,025 7 8314.1 0.18096 0,027 7 8315,1 O, 17547 0,027 7 8316.1 0.16807 0.018 7 8317,1 0.15215 0.021 7 8318.1 0.14174 0.022 7 8319,1 0.15880 0.024 7 8320,1 0.15685 0,025 7 8321,1 O, 15844 0.025 7 8322.1 0,14912 0,025 7 8323,1 0,14668 0.020 7 8324,1 0.13965 0,020 7 8325.1 0.15919 0,024 7 8326,1 0,15296 0,026 7 8327.1 0.15413 0.028 7 8328.1 0,16345 0,025 7 8329.1 0.16632 0.029 7 8330,1 O, 15075 0,026 7 8331,1 0.17072 0.026 7 8332.1 0,19059 0.033 7 8333,1 0.16425 0.026 7 8334.1 0.17326 0.027 7 8335.1 0.18104 0.027 7 8335,1 0,16037 0.024 7 8337,1 0,16231 0,023 7 Phillips Petroleum Co. Rendezvous 2 Colville River - SW HYDRAULIC UNITS 8338.5 0.15096 0.025 7 8339.1 0.16076 0.025 7 8340.1 0.16420 0.028 7 8341,1 0,15526 0.026 7 8342.1 0.17892 0.029 7 8343.1 0.17832 0.028 7 8344.1 0.16060 0,027 7 8345.1 0,16200 0.026 7 8346.1 0.16093 0.028 7 8347.1 0.14498 0,026 7 8348.1 0.14713 0.023 7 8349.1 0.17821 0.025 7 8350.1 0.16684 0.024 7 8351.1 0.16947 0.025 7 8352.1 0.17966 0.027 7 8353.1 0.19066 0.032 7 8354.1 0,18633 0.030 7 8355.1 0.20049 0,033 7 8356.1 0,22564 0.037 8 8357.1 0.24062 0.039 8 8358.1 0.22982 0.039 8 8359.4 0.22490 0.039 8 8360.4 0.15878 0.025 7 8361.4 0,17973 0.028 7 8362.1 0,17086 0.026 7 8367.1 0.16272 0.027 7 File No.: 57111-01105 Loc.: Sec. 8-TgNIR2E APl No.: 50-103-20363 8338.5 0,15096 0.025 7 8339,1 0,16076 0.025 7 8340.1 0.16420 0,028 7 8341,1 0.15526 0,026 7 8342.1 0.17892 0.029 7 8343.1 0.17832 0.028 7 8344.t 0.16060 0.027 7 8345.1 0,1 6200 0.026 7 8346.1 0.16093 0,028 7 8347.1 0.14498 0.026 7 8348.1 0.14713 0.023 7 8349.1 0.17821 0.025 7 8350.t 0.16684 0.024 7 8351.1 0.16947 0,025 7 8352.1 0.17966 0,027 7 8353,1 0.19066 0.032 7 8354.1 0.18633 0.030 7 8355.1 0.20049 0.033 7 8360.4 0.15878 0.025 7 8361.4 0.17973 0.028 7 8362.1 0.17086 0.026 7 8367.1 0.16272 0.027 7 8356,1 0,22584 0.037 8 8357.1 0.24062 0.039 8 8358.1 0.22982 0,039 8 8359.4 0.22490 0.039 8 Phillips Petroleum Co. Rendezvous 2 Colville River - SW Profile Permeameter Results 8309.07 8309,21 8309,41 8309.61 8309.80 8310.01 8310,20 8310.40 8310.61 8310.80 8311.01 8311 2.0 8311.40 8311.60 8311.80 8312.07 8312.21 8312.40 8312.60 8312.81 8313.0'1 8313.21 8313.41 8313.60 8313.80 8314.00 8314.20 8314.40 1.2 0.82 0.85 0.55 0.55 0.33 0.49 0.29 0.83 0.53 0.25 0.13 0.51 0.30 1.3 0.85 0.42 0.24 1.0 0.67 1.3 0.92 5. 4.1 1.5 1.0 0.91 0.59 1.2 0.81 1,7 1~ 2,5 1.8 1.3 0.88 1,0 0.68 1.3 0.86 1,2 0.81 0.47 0.27 0.75 0.47 2.1 1,5 2.1 1.5 0,45 026 0,87 0.56 1.1 0.71 File No.: 57111-01105 Loc.: Sec. 8-TgNIR2E APl No.: 50-103-20363 4,0" Diameter Core Standard Probe Tip Phillips Petroleum Co. Rendezvous 2 Colville River - SW Profile Permeameter Results 8314.60 0.81 0.52 8314.81 t .7 1,2 8315.06 2.8 2.1 8315,17 1,6 1.1 8315.40 1.5 1.0 8315.61 2.8 2,1 8315.80 2,2 1.6 8316.00 2.5 1.8 8316.20 0.71 0.45 8316.41 1.5 1,1 8316.60 2.8 2,1 8316.80 0.65 0.40 8317.01 1.4 0,94 8317.21 1,3 0,89 8317.40 2,5 1.9 8317,60 2,5 1,8 8317,81 2.7 2.0 8317.92 2.2 1.6 8318.20 0,53 0.31 8318.40 1.2 0,82 8318,60 1.6 1,1 8318.81 0,86 0.55 8318.99 1,7 1,2 8319.20 2,3 1.7 8319.40 2.3 1.7 8319,60 2,3 1.7 8319.80 3,3 2.5 8320,00 2.9 2.2 File No.: 57t 11-01105 Loc.: Sec. 8.TgNIR2E APl No.: 50-103-20363 4.0" Diameter Core Standard Probe Tip Phillips Petroleum Co, Rendezvous 2 Colville River. SW Profile Permeameter Results 8320.21 4.2 3,2 8320.41 6, 4,3 8320.61 7. 5. 8320,80 7, 6, 8321.06 11, 9. 8321.21 9. 8. 8321.41 18. 15. 8321,61 12. 10. 8321.81 0.67 0.42 8322.00 1.9 1,4 8322.21 1.5 1.0 8322.40 0.99 0.65 8322,61 1.6 1.1 8322,81 2,0 1,5 8323.00 - 2.1 1,5 8323,19 t.6 1,1 8323.40 3.8 2,9 8323.61 3.0 2.2 8323,81 4.8 3.7 8324.05 12. 10, 8324,21 16. 14, 8324,41 7, 5, 8324,6~ 4.8 3.7 8324.80 7, 6, 8325,01 4.7 3,6 8325,21 1.2 0.79 8325,41 1,5 1.0 8325,60 1.5 1,0 File No. · 57111-01105 Loc.: Sec. 8-TgNIR2E APl No.: 50-103-20363 4.0" Diameter Core Standard Probe Tip Phillips Petroleum Co. Rendezvous 2 Colville River - SW Profile Permeameter Results 8325,80 2,5 1.8 8325.99 1,9 1,3 8326,21 54, 49. 8326.40 32, 28. 8326.61 11, 9. 8326.80 12, 10. 8327.01 6. 4.6 8327.20 0.37 0.21 8327,40 0,33 0.18 8327.61 0.52 0,31 8327.81 0.70 0,44 8328.01 0.61 0.37 8328.41 6, 4,9 8328.61 3,1 2,3 8328.80 9. 7. 8329.02 1,5 1,0 8329.21 1,4 0.92 8329.40 2,3 1.6 8329.61 0,18 0.087 8329.80 1.1 0.73 8330,03 5. 4.2 8330.20 5. 3,9 8330.41 3,5 2.7 8330.81 4.0 3.0 8330.81 4.2 3.2 8331.00 2.3 1.7 8331,20 1,7 1,2 8331.41 2.8 2.1 File No.: 571114)1105 Loc.: Sec. 8-TgNIR2E APl No.: 60-103-20363 4,0" Diameter Core Standard Probe Tip Phillips Petroleum Co. Rendezvous 2 Colville River - SW Profile Permeameter Results 8331.60 2.3 1.7 8331.80 3,1 2,3 8332.00 2.7 2.0 8332.20 2.4 1.8 8332,40 4.3 3.3 8332,60 4.3 3.3 8332.81 $, 4,7 8333.03 8. 7, 8333.21 15, 13. 8333.41 t5, 12. 8333.61 13. 11, 8333,80 1,00 0.66 8334.00 1,6 1,1 8334.20 1,6 1.1 8334.40 1,6 1.1 8334.60 1.6 1,1 8334.80 1,2 0.81 8335.00 1.2 0,78 8335.20 1.2 0.82 8335.40 1.1 0.73 8335.61 1.1 0.75 8335.81 1,9 1.4 8336,07 0.84 0,54 8336,20 1,8 1.3 8336,40 5. 4,2 8336.60 7. 6, 8336,81 8. 6, 8337.04 9. 7. File No.: 57111-01106 Loc.: Sec, 8-TgNIR2E APl No.: 60-103-20363 4,0" Diameter Core Standard Probe Tip Phillips Petroleum Co. Rendezvous 2 Colville River - SW Profile Permeameter Results 8337.20 12, 9, 8337.40 12, 10. 8337.60 9. 7, 8337,80 9. 7, 8338.00 9. 7. 8338.20 6. 4.4 8338.40 5, 4.1 8338.60 9, 7, 8338.80 12, 10. 8339.04 16. 13. 8339.21 18. 16, 8339.40 15. 13, 8339.60 15. 13. 8339.80 1.7 1.2 8340.02 1.6 1,1 8340.20 1.5 1.1 8340.40 3.1 2.3 8340.60 3,7 2.8 8340.80 5. 4,2 8341.00 17. 14. 8341.20 8, 7. 834'1.40 11. 9. 8341,81 7. 5. 8342.05 3.8 2.9 8342.21 10. 8, 8342.61 4,1 3.1 8342,80 7. 6. 8343.02 8. 7, File No.: 57111.01105 Loc.: Sec. 8-T9NIR2E APl No,: $0-103-20363 4,0" Diameter Core Standard Probe Tip IPhillips Petroleum Co, Rendezvous 2 Colville River - SW Profile Permeameter Results 8343.21 6. 5. 8343.40 4.0 3.0 8343.61 4.0 3.0 8343.81 5. 4.0 8344.01 7. 5. 8344.20 0.44 0.25 8344.40 0.81 0.52 8344.61 1.7 1 2. 8344.80 2,7 2.0 8344.99 3.0 2.2 8345.21 0.50 0.30 8345.41 0.53 0.32 8345.60 1.1 0.76 8345.81 1.3 0.89 8346.01 0,49 02.9 8346.20 1.6 1.1 8346.40 1.5 1.0 8346.60 2,0 1.4 8346.81 2.3 1.6 8347.01 1.6 1.1 8347.20 4.1 3.1 8347.41 3.1 2.3 8347.60 3.4 2,6 8347.81 5, 3,9 8348.03 4,4 3.4 8348.20 7. 6. 8348.40 9, 7, 8348.61 1.1 0.72 File No,: $71t1-01105 Loc,: Sec, 8-T9NIR2E ..APl No.: 50-103-20363 4.0" Diameter Core Standard Probe Tip Phillips Petroleum Co, Rendezvous 2 Colville River - SW Profile Permeameter Results 8348.81 1.3 0.84 8349.00 1 ,'1 0.75 8349.20 2.2 1.6 8349.40 1,3 0,86 8349.60 1,1 0.73 8349.80 0,97 0.63 8350.04 1.3 0,85 8350.21 1,6 1,1 8350.40 1,4 0.94 8350.60 1.8 1,3 8350.80 2.5 1.8 8351.20 5. 4.0 8351.40 3,6 2.7 8351.60 9. 7, 8351.80 10. 8, 8352.00 0.55 0.33 8352.20 1,3 0.88 8352.40 1,3 0.91 8352.61 0.72 0.46 8352.80 1.3 0.90 8352.99 0.73 0.46 8353.20 1,0 0.69 8353.40 1.5 1,0 8353.60 0.99 0.66 8353,80 1,8 1,2 8353.97 1.8 1.2 8354.07 0.14 0.065 8354.20 0,33 0.18 .File No,: $7111-01105 Loc,: Sec, 8-TgNIR2E .,APl No,: 50-t03-20365 4.0" Diameter Core Standard Probe Tip Phillips Petroleum Co. Rendezvous 2 Colville River - SW 8354,40 8354,60 8354.80 8355.03 8355.20 8355.40 8355.60 8355,81 8356,01 8356,20 8356.40 8356.6O 8356.8O 8356.93 8357,06 8357.20 8357.41 8357.60 8357.81 8358.03 8358.20 8358.40 8358.61 8358.80 8359,00 8359.20 8359,41 8359.61 Profile Permeameter Results O.43 O,25 0.92 0,60 0,O65 O,O24 0,011 0.002 0,16 0.075 0.52 0.31 0.26 0.13 0.31 0.17 0.23 0,12 1,0 0.66 0,96 0.63 1.6 1.1 2.7 1.9 1.3 0,89 2.3 1.7 4,0 3,1 0.84 0.54 1.4 0.99 1.5 1.1 0.23 0,12 0.19 0.090 0.41 0.24 0,074 0.028 0,092 0.037 0.26 0,14 0.27 0,14 0.86 0.56 0.20 0,097 File No,: 57111-01105 Loc.: Sec. 8.T9NIR2E APl No.: 50-103-20363 4,0" Diameter Core Standard Probe Tip Phillips Petroleum Co. Rendezvous 2 Colville River - SW Profile Permeameter Results 8359,81 0,25 0.13 8359,91 0.13 0.055 8360,06 0.26 0.14 8360.20 1,6 1.1 8360.40 1.6 1,1 8360,60 4.7 3,6 8360.80 1,7 1,2 8361,02 4,8 3,7 8361,20 1.6 1.1 8361.41 1.8 1,3 8361.60 2.6 1.9 8361.80 1.3 0,85 8361.97 0.35 0,19 8362.19 0,70 0.44 8362.40 4.5 3,5 8362.62 0.84 0.54 8362,81 1,6 1.1 8363,15 4.2 3,2 8363,40 1,2 0.82 8363.61 2.3 1,7 8364.00 2,2 1,6 8364,55 0,51 0,30 8364,74 0,14 0,063 8364.98 0.62 0.38 8365,18 0.45 0.26 8365.35 0.61 0,37 8366,13 1.7 1.2 8366.29 0.58 0.36 File No.: 57111.01105 Loc.: Sec. 8.TgNIR2E APl No.: 50.103-20363 4.0" Diameter Core Standard Probe Tip Phillips Petroleum Co. Rendezvous 2 Colville River. SW Profile Permeameter Results 8366.51 2,0 1.4 8366,70 1.4 0.94 8367.00 0.67 0,42 8367.20 0,52 0.31 8367,40 0.54 0.33 8368.8~ 2,4 1,7 File No.: 57111-01106 Loc.: Sec. 8-TgNIR2E APl No.: $0-103-20365 4.0" Diameter Core Standard Probe Tip Phillips Petroleum Co. Rendezvous 2 Colville River - SW CORE INVENTORY C-1 8309.0 - 8368.7 1 8309.0 - 8312,0 2 8312,0 - 8315,0 3 8315.0 - 8318.0 4 8318.0 - 8321.0 5 8321.0 - 8324,0 6 8324.0 - 8327,0 7 8327.0 - 8330.0 8 8330.0 - 8333.0 9 8333.0 - 8336.0 10 8336.0 - 8339.0 11 8339.0 - 8342.0 12 8342.0 - 8345.0 13 8345.0 - 8348,0 14 8348.0 - 8351.0 15 8351.0 - 8354.0 16 8354.0 - 8357.0 17 8357.0 - 8360.0 18 8360.0 - 8362.3 19 8362.3 - 8365.0 20 8365.0 - 8368.0 21 8368.0 - 8368.7 File No.: $7111.Ol105 Loc.: Sec. 8-TgNIR2E APl No.: 50-103-20363 CORE LABORATORIES PHILLIPS PETROLEUM RENDEZVOUS NO. 2 PH ]PS pETROLEU~ pHI~..LiPS PETROLEUM W~LL ~H!LLIP$ PETRGLEUM PHILLIPS Alaska, Inc. A Subsidiaxy of PHILMPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DATA* FROM: Sandra D. Lemke, ATO1486 Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Rendezvous 2 DATE: 06/08/2001 TO: Lisa Weepie AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Transmitted herewith is the following: Rendezvous 2 501032036300 permit 201-007 Log data film~. V/Epoch formation log 2"-100' V/Schlumberger - Ultrasonic Imager log 4-22-01 Co/or I~ print V Schlumberger - Ultrasonic Imager Log 4-22-01 Please Check off each item as received, sign qnd return transmittal'to address below All data to be held cOnfidential until State of AlaSka desighated release date (AOGCC) Approx. 5/2003 *"On behalf of itself and [Anadarko Petroleum], Phillips Alaska, Inc. submits the attached data for the Rendezvous 2 Well, Drilling Permit No. 201-007 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the use of the Commission in carrying out its duties, we question Whether any future disclosure t° DNR or the public'would be appropriate or valid. However, it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, so that we may be heard on the issue." CC: Greg Wilson, PAl Geologist Receipt: ate: Return receipt to: Phillips Alaska, Inc. A'rrN: S. Lemke, ATO-1486 700 G. Street 'Anchorage, AK 99501 Prepared by: Sandra D. Lemke Phillips Alaska TI' Technical Databases RECEIVED JUN 11 2001 Alaska Oil& GasCons. Commmmor, PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY o1'- c.o'--f TRANSMITTAL CONFIDENTIAL DA TA * FROM: Sandra D. Lemke, ATO1486 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Rendezvous 2 DATE: 05/26/2001 Lisa Weepie AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Transmitted herewith is the following: Rendezvous 2 501032036300 permit 201-007 DJIi;g report~. poch Final well report, 4/20/01, well information, drilling and geologic discussion, lithology, daily activity, Survey, daily mud, bit, daily reports, logs, + color formation log, Drilling Dynamics log, DML MWD Combo log Please check off each item as received, sign and return transmittal to address below All data to be held confidential until State of Alaska designated release date (AOGCC) ApProx. 5/2003 *"On behalf of itself and [Anadarko Petroleum], Phillips Alaska, Inc. submits the attached data for the Rendezvous 2 Well, Drilling Permi{ No. 201,007as specified in 20 AAC 25.071. We request that this. data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the use of the Commission in carrying out its duties, we question whether any future disclosure to DNR or the public would be appropriate or valid. However, it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, so that we may be heard on the issue." CC: Greg Wilson, PAI Geologist Receipt: ~.~.~ . ~_ Date: ~/c~/D? Return receipt to: Phillips Alaska, Inc. Al'tN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Prepared by: Sandra D. Lemke Phillips Alaska IT Technical Databases From: Core Laboratories 600 W. 58th Ave., Unit D Anchorage,Alaska 99618 907-349-3541 Date: W~ll Name: Number of Samples: Contact: Descdption of Material: Core Laboratories - Alaska To: Alaska Oil & Gas Conservation Commission 333 W. 7th #100 Anchorage, Alaska 907-279-1433 4/30101 Phillips Alaska Inc. Rendezvous # 2 Greg Wilson Phillips Alaska Corn Chip Samples 8309-8368.7 Received By: Tim Lawlor I Core Laboratories PHILLIPS. PHILLIPS ALASKA, INC. RENDEZVOUS #2 NPRA - EXPLORATION NORTH SLOPE BOROUGH, ALASKA FINAL WELL REPORT April 20, 2001 Tim Smith- Sr. Logging Geologist Andrew Buchanan- Sr. Logging Geologist Bob Nichol- Logging Geologist EPOCH PHILLIPS PHILLIPS ALASKA, INC. RENDEZVOUS #2 NATIONAL PETROLEUM RESERVE ALASKA. EXPLORATION NORTH SLOPE BOROUGH, ALASKA TABLE OF CONTENTS TABLE OF CONTENTS ................ , ................................................................................. 2 WELL RESUME ............................................................ 3 m · m · ·· · · m ~m · · m·mm·mmm·mmm·mmm·mmmmm·mmmmm·m·mmmmm·· MTHOLOGY AND COMMENTS ..................................................................................... 4 SURVEY RECORD...................................... mm mm · mm mm mmmm· mm mm mm 35 mmmm mmmmmmmmm mmmmmmmmmmmmmm mmmmmmmml mmmm mmm mi1 BIT RECORD ........................................................... 37 mm · Il/Il · · · · Im mmmmml /il · · · mmmmmm mm· mm · · mm mm mmm mm · · em · DALLY REPORTS ............ APPENDIX A · mm mmmmmmlmmmmmmmmmm · mmmmmm em mm · m · Immmmmmmmmmmlmm mmmmmmmmmmmmmmm mmmmm · mmmmmmmm FINAL LOGS ............................................................................................... APPENDIX B ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 Company: Well: Field: Region: Location: Coordinates: Elevation: County, State: APl Index: Spud Date: Total Depth: Contractor: Company Representative: Rig/Type: Epoch Logging Unit: Epoch Personal: Company Geologist: Casing Data: Hole size: Mud Type: Logged Interval: WELL RESUME Phillips Alaska, Inc. RENDEZVOUS #2 Exploration North Slope Borough Sec. 6, T.9N, R2E UM FWL Ground Level: 93.7' (ice pad) Drill Floor: 128.7' North Slope, Alaska 50-103-20363-00 04/08/01 8650' at 04/19/01 Doyon Drilling, Inc. Dearl Gladden Ray Springer Doyon #141 Top Drive Triple MLOA3 Andrew Buchanan Bob Nichol Greg Wilson, Ken Helmold, Paul Decker, Surface: 9 5/8" 12 %" to 2680' 8 W' to 8650' Baroid 200' to 8650' EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 LITHOLOGY AND COMMENTS 200' SAND = GRAYISH RED TO BROWNISH GRAY; TRANSPARENT TO TRANSLUCENT GRAY TO OCCASIONALLY MEDIUM GRAY; VERY FINE TO OCCASIONALLY MEDIUM GRAINED WITH OCCASIONALLY FRACTURES; TRANSPORTED COARSE GRAINS; MODERATELY SORTED; PREDOMINANTLY SUBROUNDED; MODERATE SPHERICITY; UNCONSOL; WK-MODERATE REACTION WITH HCI; PREDOMINANTLY QUARTZ WITH MINOR FELDSPAR AND LITHIC MATERIAL, 250' CLAY = LIGHT BROWNISH GRAY; VERY SOFT MODERATE ADHESION; LOW TO MODERATECOHESlON; EASILY SOLUBLE; OCCURS AS AMORPHOUS LUMPS; LUMPY TO CLOTTED CONSISTENCY; SUSPENDS QUARTZ GRAINS; WEAKLY- MODERATELY REACTIVE WITH DILUTE HC. SOME LESSER MEDIUM/DARK CLAYSTONE RANDOMLY 315' TUFFACEOUS ASH = VERY LIGHT GRAY / PALE YELLOWISH BROWN; VERY SOFT - SOFT; CRUMBLY TO PASTEY; IRREGULAR FRACTURE; NODULAR TO MASSIVE CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE; VERY FAINT DULL YELLOW FLUORESCENCENT SPECKLES; ASSOCIATED DISSEMINATED BURNT WOOD FRAGMENTS 355' SILTSTONE = BROWNISH GRAY TO MEDIUM DARK GRAY PREDOMINANTLY SOFT TO FIRM; OCCASIONALLY CRUMBLY IRREGULAR FRACTURE; TABULAR TO MASSIVE CUTTINGS HABIT; DULL EARTHY LUSTER; SILTY TO GRITTY TEXTURE; NON- REACTIVE WITH DILUTE HCl; NO VISIBLE OIL SIGN; SOME SCATTERED MEDIUM-DARK BROWNISH GRAY SILTSTONE 395' SAND = LIGHT GRAY TO LIGHT BROWNISH GRAY; VERY FINE LOWER TO MEDIUM LOWER WITH OCCASIONALLY MEDIUM AND COARSE QUARTZ GRAINS; MODERATE TO WELL SORTED; SUBROUNDED; MODERATE SPHERICITY; UNCONSOLIDATED NO VISIBLE CEMENT; CLAY MATRIX IN PART; SILTY TO VERY SILTY; GRADES TO SILTSTONE; 475' SILTSTONE = BROWNISH GRAY TO MEDIUM DARK GRAY PREDOMINANTLY SOFT TO FIRM; OCCASIONALLY CRUMBLY IRREGULAR FRACTURE; TABULAR TO MASSIVE CUTTINGS HABIT; ROUNDED EDGES; DULL EARTHY LUSTER; SILTY TO GRITTY TEXTURE; NON-REACTIVE WITH DILUTE HCI; SOME SCATTERED MEDIUM-DARK BROWNISH GRAY SILTSTONE RANDOMLY; 5% DARK GRAY CARBONACEOUS MATERIAL DISSEMINATED WEAK SCATTERED YELLOW CUT FLUORESCENCE ONLY [::1 EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 525' CHERT = GRAYISH BLACK; CONCHOIDAL FRACTURE; VERY HARD - PROBE LEAVES STEEL ON SURFACE; IRREGULAR SIZE GRAINS; POSSIBLE DETRITAL MATERIAL; SHARP, ANGULAR CUTTINGS HABIT 575' SAND = LIGHT GRAY TO LIGHT BROWNISH GRAY; VERY FINE LOWER TO MEDIUM LOWER WITH OCCASIONALLY MEDIUM AND COARSE QUARTZ GRAINS; MODERATE TO WELL SORTED; SUB ROUNDED; MODERATE SPHERICITY; UNCONSOLIDATED; NO VISIBLE CEMENT; CLAY MATRIX IN PART; SILTY TO VERY SILTY; GRADES TO SILTSTONE; GLAUCONITE IS COMMON (1-5%); CALCITE FRAGMENTS DISSEMINATED RANDOMLY; COARSE GRANITIC FRAGMENTS SCATTERED THROUGHOUT. UP TO 3% CHERT FRAGMENTS NOTED 635' TUFFACEOUS ASH = VERY LIGHT GRAY / PALE YELLOWISH BROWN; VERY SOFT - SOFT; CRUMBLY TO PASTEY; IRREGULAR FRACTURE; NODULAR TO MASSIVE CUTTINGS HABIT; DULL TO SLIGHTLYWAXY LUSTER; SMOOTH TEXTURE; PERVASIVE UNCUT LIGHT YELLOW FLUORESCENCE - PROBABLY DUE TO LIGHTER COLORED TUFF. 675' SAND/SANDSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; VERY FINE LOWER TO MEDIUM LOWER WITH OCCASIONALLY MEDIUM AND COARSE QUARTZ GRAINS; MODERATE TO WELL SORTED; SUB ROUNDED; MODERATE SPHERICITY; POORLY CONSOLIDATED; NO VISIBLE CEMENT; CLAY MATRIX IN PART; SILTY TO VERY SILTY; GRADES TO SlLTSTONE; GLAUCONITE IS COMMON ;OCCASIONAL CALCITE FRAGMENTS AND RARE GRANITIC FRAGMENTS DISSEMINATED. 725' SILTSTONE = BROWNISH GRAY TO MEDIUM DARK GRAY; PREDOMINANTLY SOFT TO FIRM; OCCASIONALLY CRUMBLY IRREGULAR FRACTURE; TABULAR TO MASSIVE CUTTINGS HABIT; ROUNDED EDGES; DULL EARTHY LUSTER; SILTY TO GRITTY TEXTURE; NON- REACTIVE WITH DILUTE HCI; SOME SCATTERED MEDIUM-DARK BROWNISH GRAY SILTSTONE RANDOMLY; 5% DARK GRAY CARBONACEOUS MATERIAL DISSEMINATED WEAK SCATTERED YELLOW CUT FLUORESCENCE ONLY. 775' SANDSTONE = DARK GRAY; (COLOR CHANGE @ 740') FINE-MEDIUM GRAINED; 40% DARK GRAY LITHIC MATERIAL THROUGHOUT; HARD; CRUMBLY; BLOCKY, IRREGULAR CUTTINGS; CLAST-SUPPORTED; SILICA>> CALCITE CEMENTED; PYRITE TO 2% GROWING WITHINTERSTICES; CALCITE FRAGMENTS DISSEMINATED THROUGHOUT; RARE CHERT SCATTERED SPARINGLY; NO OIL INDICATORS EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 845' SILTSTONE = BROWNISH GRAY TO MEDIUM DARK GRAY; FIRMS WITH DEPTH; OCCASIONALLY CRUMBLY; IRREGULAR FRACTURE; TABULAR TO MASSIVE CUTTINGS HABIT; ROUNDED EDGES; DULL EARTHY LUSTER; SILTY TO GRITTY TEXTURE; NON-REACTIVE WITH DILUTE HCl; SOME SCATTERED MEDIUM-DARK BROWNISH GRAY SILTSTONE RANDOMLY; TRACE DARK GRAY CARBONACEOUS MATERIAL DISSEMINATED 890' CLAY/CLAYSTONE= BROWNISH GRAY; VERY SOFT; MODERATE ADHESION; LOW TO MODERATE COHESION; EASILY SOLUBLE; OCCURS AS AMORPHOUS LUMPS; LUMPY TO CLOTTED CONSISTENCY; SUSPENDS QUARTZ GRAINS; DARK BROWNISH GRAY CLAYSTONE HORIZONS RANDOMLY; NO OIL INDICATORS 930' TUFFACEOUS ASH = VERY LIGHT GRAY / PALE YELLOWISH BROWN; VERY SOFT- SOFT; CRUMBLY TO PASTEY; IRREGULAR FRACTURE; NODULAR TO MASSIVE CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE; 960' SILTSTONE = BROWNISH GRAY TO MEDIUM DARK GRAY; FIRMS WITH DEPTH; OCCASIONALLY CRUMBLY; IRREGULAR FRACTURE; TABULAR TO MASSIVE CUTTINGS HABIT; ROUNDED EDGES; DULL EARTHY LUSTER; SILTY TO GRITTY TEXTURE; NON- REACTIVE WITH DILUTE HCI; SOME SCATTERED MEDIUM-DARK BROWNISH GRAY SILTSTONE RANDOMLY; TRACE DARK GRAY CARBONACEOUS MATERIAL DISSEMINATED 1005' CLAY/CLAYSTONE= BROWNISH GRAY; VERY SOFT; MODERATE ADHESION; LOW TO MODERATE COHESION; EASILY SOLUBLE; OCCURS AS AMORPHOUS LUMPS; LUMPY TO CLOTTED CONSISTENCY; SUSPENDS QUARTZ GRAINS; DARK BROWNISH GRAY CLAYSTONE HORIZONS RANDOMLY; NO OIL INDICATORS 1045' TUFFACEOUS ASH = VERY LIGHT GRAY TO OFF WHITE TO OCCASIONALLY TRANSLUCENT GRAY; VERY SOFT TO OCCASIONALLY FIRM; PASTEY TO CRUMBLY; IRREGULAR FRACTURE; MASSIVE TO RARE BLOCKY CUTTINGS; DULL TO WAXY LUSTER; SMOOTH TEXTURE; OCCASIONALLY VISIBLE GLASS SHARDS; OCCASIONAL TRACE DULL YELLOW FLUORESCENCE. 1090' SILTSTONE = BROWNISH GRAY TO MEDIUM GRAY; FIRM TO STIFF; IRREGULAR TO BLOCKY FRACTURE; MASSIVE TO BLOCKY CUTTINGS; OCCASIONALLY EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 ROUNDED EDGES; DULL F_ARTHY LUSTER; SILTY TO GRITTY TEXTURE; TRACE CARBONACEOUS MATERIAL; TRACE SANDY. 1125' CLAY/CLAYSTONE = BROWN GRAY; VERY SOFT TO SOFT; MODERATE ADHESION; LOW TO MODERATE COHESION; SOLUBLE; LUMPY TO CLOTTY CONSlSTANCY; MASSIVE AMORPHOUS CUTTINGS. 1155' TUFFACEOUS ASH = VERY LIGHT GRAY TO OFF WHITE TO OCCASIONALLY TRANSLUCENT GRAY; VERY SOFT TO OCCASIONALLY FIRM; PASTEY TO CRUMBLY; IRREGULAR FRACTURE; MASSIVE TO RARE BLOCKY CUTFINGS; DULL TO WAXY LUSTER; SMOOTH TEXTURE; OCCASIONALLY VISIBLE GLASS SHARDS; OCCASIONAL TRACE DULL YELLOW FLUORESCENCE. 1200' SAND/SANDSTONE = LIGHT GRAY TO WHITISH GRAY; VERY FINE LOWER TO MEDIUM LOWER; MODERATE TO WELL SORTED; SUB ROUNDED; MODERATE SPHERICITY; PREDOMINANTLY GRAIN SUPPORTED; ABUNDANT CLAY/TUFFASH MATRIX; 70% QUARTZ, 30% CHERT AND META-LITHiC FRAGMENTS; TRACE GLAUCONITE; COMMON PYRITE ACCUMULATIONS; ESTIMATED POOR TO FAIR INTERGRANULAR POROSITY; NO VISIBLE OIL INDICATORS; ABUNDANT RECRYSTALLIZED VOLCANO-CLASTIC SAND SIZE GRAINS IN DESCRETE BEDS. 1265' CLAY/CLAYSTONE = BROWN GRAY; VERY SOFT TO SOFT; MODERATE ADHESION; LOW TO MODERATE COHESION; SOLUBLE; LUMPY TO CLOTTY CONSlSTANCY; MASSIVE AMORPHOUS CUTTINGS. 1295' TUFFACEOUS ASH = VERY LIGHT GRAY TO OFF WHITE TO OCCASIONALLY TRANSLUCENT GRAY; VERY SOFT TO OCCASIONALLY FIRM; PASTEY TO CRUMBLY; IRREGULAR FRACTURE; MASSIVE TO RARE BLOCKY CUTTINGS; DULL TO WAXY LUSTER; SMOOTH TEXTURE; OCCASIONALLY VISIBLE GLASS SHARDS; OCCASIONAL TRACE DULL YELLOW FLUORESCENCE. 1340' SAND/SANDSTONE = LIGHT GRAY TO WHITISH GRAY; VERY FINE LOWER TO MEDIUM LOWER; MODERATE TO WELL SORTED; SUB ROUNDED; MODERATE SPHERICITY; PREDOMINANTLY GRAIN SUPPORTED; ABUNDANT CLAY/TUFF ASH MATRIX; 70% QUARTZ, 20% CHERT AND META-LITHIC FRAGMENTS, 10% VOLC-LITHIC; TRACE GLACUONITE; OCCASIONALLY PYRITE; POOR TO FAIR INTERGRANULAR POROSITY; COMMON LAMINAE OF CARBONACEOUS MATERIAL. EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 1395' SILTSTONE = LIGHT GRAY TO MEDIUM GRAY; PREDOMINANTLY QUARTZOSE WITH SILT AND LITHIC FRAGMENTS; SOFT TO FIRM; IRREGULAR FRACTURE; MASSIVE TO BLOCKY CUTTINGS; DULL TO OCCASIONALLY WAXY LUSTER; GRITTY TEXTURE; ABUNDANT CLAY AND ASH MATRIX. 1435' CLAY/CLAYSTONE = BROWN GRAY; VERY SOFT TO SOFT; MODERATE ADHESION; LOW TO MODERATE COHESION; SOLUBLE; LUMPY TO CLOTTY CONSISTANCY; MASSIVE AMORPHOUS CUTTINGS. 1465' TUFFACEOUS ASH = VERY LIGHT GRAY TO OFF WHITE TO OCCASIONALLY TRANSLUCENT GRAY; VERY SOFT TO OCCASIONALLY FIRM; PASTEY TO CRUMBLY; IRREGULAR FRACTURE; MASSIVE TO RARE BLOCKY CUTTINGS; DULL TO WAXY LUSTER; SMOOTH TEXTURE; OCCASIONALLY VISIBLE GLASS SHARDS; OCCASIONALLY APPEARS AS A DEVITRIFIED WELDED TUFF. 1510' SILTSTONE = LIGHT GRAY TO MEDIUM GRAY; PREDOMINANTLY QUARTZOSE WITH TUFFACEOUS AND LITHIC FRAGMENTS; SOFT TO FIRM; IRREGULAR FRACTURE; MASSIVE TO BLOCKY CUTTINGS; DULL TO OCCASIONALLY WAXY LUSTER; GRITTY TEXTURE; ABUNDANT CLAY AND ASH MATRIX. 1550' SANDSTONE = WHITISH GRAY TO LIGHT GRAY; UNCONSOLIDATED TO HARD; VERY FINE LOWER TO COARSE LOWER GRAINS; PREDOMINANTLY FAIR TO POOR SORTING; SUBROUNDED TO ROUNDED; MODERATE TO HIGH SPHERICITY; PREDOMINANTLY GRAIN SUPPORTED; ABUNDANT CLAY/ASH MATRIX; WELL CEMENTED IN PART; SILICEOUS CEMENT IN PART; 60% QUARTZ, 10% CHERT, 30% LITHIC FRAGMENTS; TIGHT TO FAIR INTERGRANULAR POROSITY SHOWS NO OIL STAINING OR FLUORESCENCE; TRACE GLAUCONITE; OCCASIONAL CARBONACEOUS MATERIAL. 1615' TUFFACEOUS ASH = VERY LIGHT GRAY TO OFF WHITE TO OCCASIONALLY TRANSLUCENT GRAY; VERY SOFT TO OCCASIONALLY FIRM; PASTEY TO CRUMBLY; IRREGULAR FRACTURE; MASSIVE TO RARE BLOCKY CUTTINGS; DULL TO WAXY LUSTER; SMOOTH TEXTURE; OCCASIONALLY VISIBLE GLASS SHARDS; OCCASIONALLY APPEARS AS A DEVITRIFIED WELDED TUFF; DARK GRAY THIN LAMINATIONS - ASH FALL TUFF PROBABLY WATER-LAIN 1670' COAL = BLACK, HARD; SUBCONCHOIDAL FRACTURE BLOCKY; LEAVES FAINT OILY RESIDUE WHEN CRUSHED; APPEARS TO BE .5cm BEDS; FRAGMENTS SCATTERED THROUGHOUT SAMPLE. EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 1695' SANDSTONE = WHITISH GRAY TO LIGHT GRAY; ALSO GREYISH-RED THIN BDD SANDSTONE TO 10%; UNCONSOLIDATED TO HARD; DOMINANTLYVERY FINE LOWER TO LOWER MEDIUM QUARTZ GRAINS; PREDOMINANTLY FAIR TO POOR SORTING; SUBROUNDED TO ROUNDED; GOOD SPHERICITY; PREDOMINANTLY GRAIN SUPPORTED; LIGHT GRAY CLAY/ASH>SILICA MATRIX; TRACE KSPAR; 60% QUARTZ, 10% CHERT, 30% LITHIC FRAGMENTS; TRACE DISSEMINATED GLAUCONITE; PLENTIFUL CARBONACEOUS MATERIAL; GOOD INTERGRANULAR POROSITY; NO OIL INDICATORS; QUARTZ GRAIN SIZE VARIES RAPIDLY. 1715' SANDSTONE = WHITISH GRAY TO LIGHT GRAY; ALSO GREYISH-RED THIN BDD SANDSTONE TO 10% BETTER CONSOLIDATED GRAYSH RED TO DARK BROWN; PREDOMINANTLY QUARTZOSE WITH SILT AND LITHIC FRAGMENTS; SOFT TO FIRM; IRREGULAR FRACTURE; MASSIVE TO BLOCKY CUTTINGS; DULL TO OCCASIONALLY WAXY LUSTER; GRITTY TEXTURE; ABUNDANT CLAY ASH MATRIX; NON-REACTIVE WITH DILUTE HCI. EASILY SCORED WITH PROBE. 1805' SANDSTONE = WHITISH GRAY TO LIGHT GRAY; UNCONSOLIDATED TO HARD; DOMINANTLY VERY FINE LOWER TO LOWER MEDIUM QUARTZ GRAINS; PREDOMINANTLY FAIR TO POOR SORTING; SUBROUNDED TO ROUNDED; GOOD SPHERICITY; PREDOMINANTLY GRAIN SUPPORTED; LIGHT GRAY CLAY/ASH>SILICA MATRIX; TRACE SPAR; 60% QUARTZ, 10% CHERT, 30% LITHIC FRAGMENTS; OCCASIONAL CARBONACEOUS MATERIAL DISSEMINATED; GOOD INTERGRANULAR POROSITY; NO OIL INDICATORS; QUARTZ GRAIN SIZE VARIES RAPIDLY.VERY RARE WHITE, THIN BDD QUARTZITE LAYERS. NOTE- SANDSTONE COLOR CHANGE @ 1830' 1875' TUFFACEOUS ASH = VERY LIGHT GRAY TO WHITE; VERY SOFT TO OCCASIONALLY FIRM; PASTEY TO CRUMBLY; IRREGULAR FRACTURE; MASSIVE TO OCCASIONALLY BLOCKY CUTTINGS; DULL TO WAXY LUSTER; SMOOTH TEXTURE; OCCASIONALLY VISIBLE GLASS SHARDS; OCCASIONALLY APPEARS AS A DEVITRIFIED WELDED TUFF; DARK GRAY THIN LAMINATIONS - ASH FALL TUFF PROBABLY WATER-LAIN. NO OIL INDICATORS. 1925' SANDSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY; UNCONSOLIDATED TO HARD; DOMINANTLY VERY FINE LOWER TO LOWER MEDIUM QUARTZ GRAINS; PREDOMINANTLY FAIR TO POOR SORTING; SUBROUNDED TO ROUNDED; GOOD SPHERICITY; PREDOMINANTLY GRAIN SUPPORTED; MEDIUM GRAY CLAY/ASH/SILICA MATRIX; TRACE KSPAR 60% QUARTZ, 10% CHERT, 30% LITHIC FRAGMENTS; BLACK CARBONACEOUS MATERIAL DISSEMINATED; GOOD INTERGRANULAR POROSITY; NO OIL INDICATORS; QUARTZ GRAIN SIZE VARIES RAPIDLY. EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 1980' TUFFACEOUS CLAYSTONE = LIGHT GRAY; VERY SOFT TO SOFT; MODERATE ADHESION; LOW TO MODERATE COHESION; SOLUBLE; LUMPY TO PASTY CONSISTANCY; MASSIVE SMOOTH TEXTURE; SCATTERED DARK GRAY CARBONACEOUS MATERIAL RANDOMLY. NO OIL INDICATORS. 2015' SANDSTONE = MEDIUM GRAY TO DARK GRAYISH GRAY; UNCONSOLIDATED TO HARD; DOMINANTLY FINE LOWER TO UPPER FINE QUARTZ GRAINS; PREDOMINANTLY FAIR TO POOR SORTING; SUBROUNDED TO ROUNDED; MODERATE SPHERICITY; PREDOMINANTLY GRAIN SUPPORTED; MEDIUM GRAY CLAY/ASH/SILICA MATRIX; TRACE SPAR, 80% QUARTZ, 20% LITHIC FRAGMENTS; BLACK CARBONACEOUS MATERIAL DISSEMINATED; MODERATE INTERGRANULAR POROSITY; NO OIL INDICATORS; QUARTZ GRAIN SIZE VARIES RAPIDLY. 2070' TUFFACEOUS ASH = VERY LIGHT GRAY TO WHITE; VERY SOFT TO OCCASIONALLY FIRM; PASTEY TO CRUMBLY; IRREGULAR FRACTURE; ROUNDED, BLOCKY CUTTINGS; DULL TO WAXY LUSTER; SMOOTH TEXTURE; RARELY VISIBLE GLASS SHARDS; OCCASIONALLY APPEARS AS A DEVITRIFIED WELDED TUFF; DARK GRAY THIN LAMINATIONS- ASH FALL TUFF PROBABLY WATER-LAIN. NO OIL INDICATORS. 2120' SANDSTONE = BROWNISH GRAY TO MEDIUM DARK GRAY; DOMINANTLY UNCONSOLIDATED OCCASIONALLY HARD; DOMINANTLY VERY FINE LOWER TO LOWER MEDIUM QUARTZ GRAINS; PREDOMINANTLY FAIR TO GOOD SORTING; SUBROUNDED TO ROUNDED; GOOD SPHERICITY; PREDOMINANTLY GRAIN SUPPORTED; MEDIUM GRAY'CLAY/ASH/SILICA MATRIX; TRACE KSPAR 90% QUARTZ, 5% CHERT, 5% LITHIC FRAGMENTS; BLACK CARBONACEOUS MATERIAL DISSEMINATED; GOOD INTERGRANULAR POROSITY; NO OIL INDICATORS; QUARTZ GRAIN SIZE VARIES RAPIDLY. 2175' SILTSTONE = LIGHT TO MEDIUM GRAY; PREDOMINANTLY QUARTZOSE WITH TUFFACEOUS SILT AND LITHIC FRAGMENTS; SOFT TO FIRM;IRREGULAR FRACTURE; MASSIVE TO BLOCKY CUTTINGS; DULL TO OCCASIONALLY WAXY LUSTER; GRITTY TEXTURE; ABUNDANT CLAY ASH MATRIX; NON-REACTIVE WITH DILUTE HCI. EASILY SCORED WITH PROBE. 2235' CLAY/CLAYSTONE = LT-MEDIUM GRAY; VERY SOFT TO SOFT; MODERATE ADHESION; LOW TO MODERATE COHESION; SOLUBLE; LUMPY TO CLOTTED CONSISTANCY; MASSIVE AMORPHOUS CUTTINGS; SMOOTH TEXTURE; DULL LUSTER.NO VISIBLE OIL SIGNS; MICROSPARKLES DISSEMINATED. EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 2270' SANDSTONE = BROWNISH GRAY TO MEDIUM DARK GRAY; DOMINANTLY UNCONSOLIDATED OCCASIONALLY HARD; DOMINANTLY VERY FINE LOWER TO UPPER MEDIUM QUARTZ GRAINS; PREDOMINANTLY FAIR TO GOOD SORTING; SUBROUNDED TO ROUNDED;INCREASING MEDIUM DARK GRAY SANDSTONE CONSISTENTLY MODERATE HARD TO HARD; SILICA CEMENTED; COARSER GRAINED; GOOD SPHERICITY; PREDOMINANTLY GRAIN SUPPORTED; NO APPARENT OIL SIGNS.MEDIUM GRAY CLAY/ASH/SILICA MATRIX; TRACE KSPAR 90% QUARTZ, 5% CHERT, 5% LITHIC FRAGMENTS; BLACK CARBONACEOUS MATERIAL DISSEMINATED; POOR INTERGRANULAR POROSITY. 2335' TUFF = VERY LIGHT GRAY TO WHITE; VERY SOFT TO OCCASIONALLY FIRM; PASTEY TO CRUMBLY; IRREGULAR FRACTURE; ROUNDED, BLOCKY CUTTINGS; DULL TO WAXY LUSTER; SMOOTH TEXTURE; NO VISIBLE OIL INDICATORS. 2370' CLAY/CLAYSTONE = MEDIUM DARK GRAY; VERY SOFT TO SOFT; MODERATE ADHESION; MODERATE TO GOOD COHESION; SOLUBLE; LUMPY TO CLOTTED CONSISTANCY; MASSIVE ROUNDED EDGED CUTTINGS; SMOOTH TEXTURE; DULL LUSTER. NO VISIBLE OIL SIGNS; MICROSPARKLES DISSEMINATED. 2405' SILTSTONE = MEDIUM DARK GREY- MEDIUM GRAY; PREDOMINANTLY QUARTZOSE WITH TUFFACEOUS SLIGHT AND LITHIC FRAGMENTS; SOFT TO FIRM; IRREGULAR FRACTURE; MASSIVE TO BLOCKY CUTTINGS; DULL TO OCCASIONALLY WAXY LUSTER; GRITTY TEXTURE; ABUNDANT CLAY ASH MATRIX; NON-REACTIVE WITH DILUTE HCI. EASILY SCORED WITH PROBE. , 2450' TUFF = VERY LIGHT GRAY TO WHITE; VERY SOFT TO OCCASIONALLY FIRM; PASTEY TO CRUMBLY; IRREGULAR FRACTURE; ROUNDED, BLOCKY CUTTINGS; DULL TO WAXY LUSTER; SMOOTH TEXTURE; NO VISIBLE OIL INDICATORS. 2485' CLAY/CLAYSTONE = MEDIUM DARK GRAY; VERY SOFT TO SOFT; MODERATE ADHESION; MODERATE TO GOOD COHESION; SOLUBLE; LUMPY TO CLOTTED CONSISTANCY; MASSIVE ROUNDED EDGED CUTTINGS; SMOOTH TEXTURE; DULL LUSTER. NO VISIBLE OIL SIGNS; MICROSPARKLES DISSEMINATED. 2535' SANDSTONE = BROWNISH GRAY TO MEDIUM DARK GRAY; DOMINANTLY UNCONSOLIDATED OCCASIONALLY HARD; DOMINANTLY VERY FINE LOWER TO UPPER MEDIUM QUARTZ GRAINS; PREDOMINANTLY FAIR TO GOOD SORTING; SUBROUNDED TO ROUNDED; MODERATE HARD TO HARD; SILICA CEMENTED; [::l EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 COARSER GRAINED; GOOD SPHERICITY; PREDOMINANTLY GRAIN SUPPORTED; NO APPARENT OIL SIGNS. 2575' TUFF = VERY LIGHT GRAY TO WHITE; VERY SOFT TO OCCASIONALLY FIRM; PASTEY TO CRUMBLY; IRREGULAR FRACTURE; ROUNDED, BLOCKY CUTTINGS; DULL TO WAXY LUSTER; SMOOTH TEXTURE; OCCASIONALLY VISIBLE GLASS SHARDS; NO VISIBLE OIL INDICATORS. 2610' SAND/SANDSTONE = WHITE TO LIGHT GRAY; VERY FINE LOWER TO MEDIUM WITH COMMON UNCONSOLIDATED UPPER MEDIUM TO COARSE GRAINS, CONSOLIDATED CHIPS ARE MODERATE TO WELL SORTED; SUBROUNDED TO SUBANGULAR; MODERATE SPHERICITY; PREDOMINANTLY LOOSELY CONSOLIDATED WITH CLAY ASH MATRIX; GRAIN AND MATRIX SUPPORTED; COMPOSED OF 60% QUARTZ, 20% CHERT, 20% LITHIC FRAGMENTS; NO VISIBLE CEMENT; ESTIMATED VERY POOR TO POOR INTERGRANULAR POROSITY SHOWS NO OIL INDICATORS; UNCONSOLIDATED GRAINS ARE PREDOMINANTLY QUARTZ WITH CHERT AND RARE LITHIC FRAGMENTS. 2720' CLAYSTONE = MEDIUM GRAY TO MEDIUM LIGHT GRAY; SOFT, OCCASIONALLY SLIGHTLY FIRM; LOW TO MODERATE ADHESION; MODERATE COHESION; LOW SOLUBILITY; CURDY TO CLOTTED CONSISTENCY; PASTY TO MUSHY; AMORPHOUS AND MASSIVE CUTTINGS; SMOOTH TO SILTY TEXTURE; DULL TO EARTHY LUSTER; 2755' TUFF = VERY LIGHT GRAY TO WHITE WITH SOME PALE REDDISH BROWN SECTIONS; VERY SOFT TO OCCASIONALLY FIRM; PASTEY TO OCCASIONALLY CRUMBLY; IRREGULAR FRACTURE; ROUNDED EDGES; BLOCKY CUTTINGS; DULL TO WAXY LUSTER; SMOOTH TEXTURE; NO VISIBLE OIL INDICATORS. 2790' SANDSTONE = MEDIUM TO DARK GRAY; VERY FINE LOWER TO MEDIUM CONSOLIDATED CHIPS ARE MODERATE TO WELL SORTED; SUBROUNDED TO SUBANGULAR; MODERATE SPHERICITY; PREDOMINANTLY LOOSELY CONSOLIDATED WITH CLAY ASH MATRIX SUPPORT; POOR-MODERATE INTERGRANULAR POROSITY; THIN BEDDING IN BOTH SILTSTONE AND SANDSTONE DELINEATED BY DARK GRAY CARBONACEOUS MATERIAL; NO VISIBLE OIL INDICATIONS 2845' SILTSTONE = MEDIUM DARK GREY- MEDIUM GRAY; PREDOMINANTLY QUARTZOSE WITH TUFFACEOUS SILT AND LITHIC FRAGMENTS; SOFT TO FIRM; IRREGULAR FRACTURE; MASSIVE TO BLOCKY CUTTINGS; DULL TO EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 OCCASIONALLY MATTE LUSTER; GRI3-rY TEXTURE; ABUNDANT CLAY ASH MATRIX; NON-REACTIVE WITH DILUTE HCI. EASILY SCORED WITH PROBE. 2890' CLAYSTONE = MEDIUM DARK GRAY TO DARK GRAY; SOFT, OCCASIONALLY SLIGHTLY FIRM; LOW TO MODERATE ADHESION; MODERATE COHESION; SLIGHTLY SOLUBLE; CURDY TO CLOTTED CONSISTENCY; PASTY TO MUSHY; AMORPHOUS AND MASSIVE CUTTINGS; SMOOTH TO SILTY TEXTURE; DULL TO EARTHY LUSTER; NO VISIBLE OIL INDICATORS. 2930' TUFF = VERY LIGHT GRAY TO WHITE WITH RARE PALE REDDISH BROWN SECTIONS; VERY SOFT TO OCCASIONALLY FIRM; PASTEY TO OCCASIONALLY CRUMBLY; IRREGULAR FRACTURE; ROUNDED EDGES; BLOCKY CUTTINGS; DULL TO WAXY LUSTER; SMOOTH TEXTURE; NO VISIBLE OIL INDICATORS. 2965' SILTSTONE = MEDIUM DARK GREY- MEDIUM GRAY; PREDOMINANTLY QUARTZOSE WITH TUFFACEOUS SILT AND LITHIC FRAGMENTS; SOFT TO FIRM; IRREGULAR FRACTURE; MASSIVE TO BLOCKY CUTTINGS; DULL TO OCCASIONALLY MATTE LUSTER; GRITTY TEXTURE; ABUNDANT CLAY ASH MATRIX; NON-REACTIVE WITH DILUTE HCI. EASILY SCORED WITH PROBE. 3010' CLAYSTONE = MEDIUM DARK GRAY TO DARK GRAY; SOFT, OCCASIONALLY SLIGHTLY FIRM; LOW TO MODERATE ADHESION; MODERATE COHESION; SLIGHTLY SOLUBLE; CURDY TO CLOTTED CONSISTENCY; PASTY TO MUSHY; AMORPHOUS AND MASSIVE CUTTINGS; SMOOTH TO SILTY TEXTURE; DULL TO EARTHY LUSTER; VERY SPOTTY WEAK CUT FLUORESCENCE. 3065' SILTSTONE = MEDIUM BROWNISH GREY- MEDIUM GRAY; PREDOMINANTLY QUARTZOSE WITH SILT AND LITHIC FRAGMENTS; SOFT TO FIRM; IRREGULAR FRACTURE; MASSIVE TO BLOCKY CUTTINGS; DULL TO OCCASIONALLY MATTE LUSTER; GRITTY TEXTURE; ABUNDANT CLAY ASH MATRIX; NON-REACTIVE WITH DILUTE HCI. EASILY SCORED WITH PROBE. 3110' TUFF = VERY LIGHT GRAY TO WHITE WITH RARE PALE REDDISH BROWN SECTIONS; VERY SOFT TO OCCASIONALLY FIRM; PASTEY TO OCCASIONALLY CRUMBLY; IRREGULAR FRACTURE; ROUNDED EDGES; BLOCKY CUTTINGS; DULL TO WAXY LUSTER; SMOOTH TEXTURE; NO VISIBLE OIL INDICATORS. 3145' CLAYSTONE = MEDIUM DARK GREY- BROWNISH GRAY; SOFT, OCCASIONALLY SLIGHTLY FIRM; LOW TO MODERATE ADHESION; MODERATE COHESION; SLIGHTLY SOLUBLE; CURDY TO CLOTTED CONSISTENCY; PASTY TO MUSHY; EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 AMORPHOUS AND MASSIVE CUTTINGS; SMOOTH TO SILTY TEXTURE; DULL TO EARTHY LUSTER; INCREASINGLY PLANAR BEDDING NOTED; 3185' SILTSTONE = MEDIUM BROWNISH GREY- MEDIUM GRAY; PREDOMINANTLY QUARTZOSE WITH SILT AND LITHIC FRAGMENTS; SOFT TO FIRM; IRREGULAR FRACTURE; MASSIVE TO BLOCKY CUTTINGS; DULL TO OCCASIONALLY MATTE LUSTER; GRITTY TEXTURE; ABUNDANT CLAY MATRIX; NON-REACTIVE WITH DILUTE HCI. EASILY SCORED WITH PROBE. 3230' CLAYSTONE = BROWNISH GRAY; SOFT TO VERY SOFT; OCCASIONALLY SLIGHTLY FIRM; MODERATE TO HIGH ADHESION; MODERATE COHESION; SLIGHTLY SOLUBLE; DOMINANTLY CURDY TO CLOTTED CONSISTENCY; PASTY TO MUSHY; AMORPHOUS AND MASSIVE CUTTINGS; SMOOTH TO SILTY TEXTURE; DULL TO EARTHY LUSTER; OCCASIONALLY PLANAR BEDDING NOTED; LIGHT GRAY VOLCANIC TUFF PARTICLES DISSEMINATED TO 3-5%. NO VISIBLE OIL INDICATORS. 3280' SILTSTONE = MEDIUM BROWNISH GREY- MEDIUM GRAY; PREDOMINANTLY QUARTZOSE WITH SILT AND LITHIC FRAGMENTS; SOFT TO FIRM; IRREGULAR FRACTURE; MASSIVE TO BLOCKY CUTTINGS; DULL TO OCCASIONALLY MATTE LUSTER; GRITTY TEXTURE; ABUNDANT CLAY MATRIX; NON-REACTIVE WITH DILUTE HCI. EASILY SCORED WITH PROBE. 3325' SANDSTONE = MEDIUM GRAY TO BROWNISH GRAY; VERY FINE LOWER TO MEDIUM CONSOLIDATED CHIPS ARE MODERATE TO WELL SORTED; SUBROUNDED TO SUBANGULAR; MODERATE SPHERICITY; PREDOMINANTLY LOOSELY CONSOLIDATED WITH CLAY MATRIX SUPPORT; OCCASIONALLY THIN, MORE RESISTANT ZONES; NO VISIBLE OIL INDICATIONS POOR-MODERATE INTERGRANULAR POROSITY; 3375' CLAYSTONE = BROWNISH GRAY; SOFT TO VERY SOFT; OCCASIONALLY SLIGHTLY FIRM; MODERATE TO HIGH ADHESION; MODERATE COHESION; SLIGHTLY SOLUBLE; DOMINANTLY CURDY TO FECAL CONSISTENCY; PASTY TO MUSHY; AMORPHOUS AND MASSIVE CUTTINGS; SMOOTH TO SILTY TEXTURE; DULL TO EARTHY LUSTER; OCCASIONALLY THIN PLANAR BEDDING NOTED IN MORE RESISTANT LAYERS; LIGHT GRAY VOLCANIC TUFF PARTICLES DISSEMINATED TO 2%. NO VISIBLE OIL INDICATORS. 3430' SILTSTONE = MEDIUM BROWNISH GREY- MEDIUM GRAY; PREDOMINANTLY QUARTZOSE WITH SILT AND LITHIC FRAGMENTS; SOFT TO FIRM; IRREGULAR FRACTURE; MASSIVE TO BLOCKY CUTTINGS; DULL TO OCCASIONALLY MATTE EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 LUSTER; GRITTY TEXTURE; ABUNDANT CLAY MATRIX; NON-REACTIVE WITH DILUTE HCl. EASILY SCORED WITH PROBE. 3475' CLAYSTONE = BROWNISH GRAY; SOFT TO VERY SOFT; OCCASIONALLY SLIGHTLY FIRM; MODERATE TO HIGH ADHESION; MODERATE COHESION; SLIGHTLY SOLUBLE; DOMINANTLY CURDY TO FECAL CONSISTENCY; PASTY TO MUSHY; AMORPHOUS AND MASSIVE CUTTINGS; SMOOTH TO SILTY TEXTURE; DULL TO EARTHY LUSTER; OCCASIONALLY THIN PLANAR BEDDING NOTED IN MORE RESISTANT LAYERS; LIGHT GRAY VOLCANIC TUFF PARTICLES DISSEMINATED TO 2%. NO VISIBLE OIL INDICATORS. 3530' SILTSTONE = MEDIUM DARK GREY- DARK GRAY; PREDOMINANTLY QUARTZOSE WITH SILT AND LITHIC FRAGMENTS; SOFT TO FIRM; IRREGULAR FRACTURE; MASSIVE TO BLOCKY CUTTINGS; DULL TO OCCASIONALLY MATTE LUSTER; GRITTY TEXTURE; ABUNDANT CLAY MATRIX; NON-REACTIVE WITH DILUTE HCI. EASILY SCORED WITH, PROBE. 3590' CLAYSTONE = BROWNISH GRAY; SOFT TO VERY SOFT; OCCASIONALLY SLIGHTLY FIRM; MODERATE TO HIGH ADHESION; MODERATE COHESION; SLIGHTLY SOLUBLE; DOMINANTLY CURDY TO FECAL CONSISTENCY; PASTY TO MUSHY; AMORPHOUS AND MASSIVE CUTTINGS; SMOOTH TO SILTY TEXTURE; DULL TO EARTHY LUSTER; OCCASIONALLY THIN PLANAR BEDDING NOTED IN MORE RESISTANT LAYERS; LIGHT GRAY VOLCANIC TUFF PARTICLES DISSEMINATED 5 TO 10%. NO VISIBLE OIL INDICATORS. 3645' $1LTSTONE = MEDIUM DARK GREY- DARK GRAY; PREDOMINANTLY QUARTZOSE WITH TUFFACEOUS SILT AND LITHIC FRAGMENTS; SOFT TO FIRM; IRREGULAR FRACTURE; MASSIVE TO BLOCKY CUTTINGS; DULL TO OCCASIONALLY MATTE LUSTER; GRITTY TEXTURE; ABUNDANT CLAY MATRIX; NON-REACTIVE WITH DILUTE HCI. EASILY SCORED WITH PROBE, 369O' CLAYSTONE = BROWNISH GRAY; SOFT TO VERY SOFT; OCCASIONALLY SLIGHTLY FIRM; MODERATE TO HIGH ADHESION; MODERATE COHESION; SLIGHTLY SOLUBLE; DOMINANTLY CURDY TO FECAL CONSISTENCY; PASTY TO MUSHY; AMORPHOUS AND MASSIVE CUTTINGS; SMOOTH TO SILTY TEXTURE; DULL TO EARTHY LUSTER; OCCASIONALLY THIN PLANAR BEDDING NOTED IN MORE RESISTANT LAYERS; SCATTERED DARK GRAY/BI.ACK CARBONACEOUS MATERIAL TO 2%. 3740' EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 TUFF = VERY LIGHT GRAY TO WHITE WITH RARE PALE REDDISH BROWN SECTIONS; VERY SOFT TO OCCASIONALLY FIRM; PASTEY TO OCCASIONALLY CRUMBLY; IRREGULAR FRACTURE; ROUNDED EDGES; BLOCKY CUTTINGS; DULL TO WAXY LUSTER; SMOOTH TEXTURE; NO VISIBLE OIL INDICATORS. 3775' SILTSTONE = MEDIUM DARK GREY- DARK GRAY; PREDOMINANTLY QUARTZOSE WITH SILT AND LITHIC FRAGMENTS; SOFT TO FIRM; IRREGULAR FRACTURE; MASSIVE TO BLOCKY CUTTINGS; DULL TO OCCASIONALLY MATTE LUSTER; GRITTY TEXTURE; ABUNDANT CLAY MATRIX; NON-REACTIVE WITH DILUTE HCI. 3815' CLAYSTONE = BROWNISH GRAY; SOFT TO VERY SOFT; OCCASIONALLY SLIGHTLY FIRM; MODERATE TO HIGH ADHESION; MODERATE COHESION; SLIGHTLY SOLUBLE; DOMINANTLY CURDY TO FECAL CONSISTENCY; PASTY TO MUSHY; AMORPHOUS AND MASSIVE CUTTINGS; SMOOTH TO SILTY TEXTURE; DULL TO EARTHY LUSTER; 3850' SILTSTONE = MEDIUM GRAY TO BROWNISH GRAY; SOFT TO SLIGHTLY FIRM, OCCASIONALLY MODERATELY FIRM; CRUMBLY TO SUBCRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; MASSIVE CUTTINGS HABIT; DULL LUSTER; SILTY TO SLIGHTLY GRITTY TEXTURE; INTERBEDDED WITH AND GRADATIONAL TO CLAYSTONE; NON-TO VERY SLIGHTLY CALCAREOUS. 3890' SANDSTONE = MEDIUM GRAY TO OLIVE GRAY TO BROWNISH GRAY; FRIABLE TO FIRM FRIABLE; LOWER FINE GRADING TO SILT; FAIR TO WELL SORTED; SUBANGULAR TO SUBROUNDED, OCCASIONALLY ANG; MODERATE TO HIGH SPHEROIDAL SPHERICITY; PREDOMINANTLY CLAY MATRIX SUPPORTED AND CEMENTED WITH POSSIBLY PYRITE OVERGROWTH CMTN; ABUNDANT DISSEMINATED PYRITE XTALS; 30 - 50% QUARTZ WITH BALANCE VARYING AMTS METALITHIC FRAGMENTS AND CARBONACEOUS DEBRIS; POORESTIMATED VISIBLE POROSITY; DULL MEDIUMYELLOW SAMPLE FLUORESCENCE; VERY SLOW PALE BLUE-WHITE MULTI-STREAMING CUT; DULL DARK YELLOW TO YELLOW-GOLD RESIDUAL FLUORESCENCE. 3965' CLAYSTONE = LIGHT BROWNISH GRAY TO OLIVE GRAY; VERY SOFT TO SOFT; MODERATELY COHESIVE; HIGH TO MODERATE ADHESIVE; LOW SOLUBLE; CURDY TO CLOTTED CONSISTENCY; PREDOMINANTLY AMORPHOUS MASSIVE CLAY WITH OCCASIONALLY IRREGULAR FRACTURE ON MORE INDURATED CUTTINGS; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, LOCALLY OCCASIONALLY SILTY; THICK BEDDED GRADING TO AND INTERBEDDED WITHIN SILTSTONE; NON TO POSSIBLY SLIGHTLY CALCAREOUS. EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 4015' SILTSTONE = MEDIUM GRAY TO BROWNISH GRAY; SOFT TO SLIGHTLY FIRM, OCCASIONALLY MODERATELY FIRM; CRUMBLY TO SUBCRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; MASSIVE CUTTINGS HABIT; DULL LUSTER; SILTY TO SLIGHTLY GRITTY TEXTURE; INTERBEDDED WITH AND GRADATIONAL TO CLAYSTONE; NON-TO VERY SLIGHTLY CALCAREOUS. 4055' SAND = WHITE TRANSLIGHTLY TO TRANSP; 100% UNCONSLIGHTLY AND IMBEDDED IN SOFT CLAYEY CUTTINGS; PREDOMINANTLY UNDIFFERENTIATED CHERT AND QUARTZ GRAINSWITH OCCASIONALLY LITHIC FRAGMENTS OF VARYING HUES; LOWER VERY FINE TO SILT; WELL SORTED; SUBANGULAR TO SUBROUNDED ON LARGER GRAINS; HIGH TO MODERATE SPHEROIDAL SPHERICITY OVERALL; LOOSE VERY THIN INTERBEDS AND BIT-FREED GRAINS FROM SILTSTONE INFERRED; NO DISCERNIBLE SAMPLE FLUORESCENCE OR CUT. 4110' TUFF = WHITE TO VERY LIGHT GRAY; VERY SOFT; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT APPEARS PARTIALLY BLENDED WITH CLAYSTONE IN SAMPLE, NO CONSOLIDATED CUTTINGS DETECTED; WAXY LUSTER; SMOOTH TO CLAYEY TEXTURE; NO DISCERNIBLE STRUCTURE. 4145' CLAYSTONE = LIGHT BROWNISH GRAY TO OLIVE GRAY; VERY SOFT TO SOFT; MODERATELY COHESIVE; HIGH TO MODERATE ADHESIVE; LOW SOLUBLE; CURDY TO CLOTTED CONSISTENCY; PREDOMINANTLY AMORPHOUS MASSIVE CLAY WITH OCCASIONALLY IRREGULAR FRACTURE ON MORE INDURATED CUTTINGS; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, LOCALLY OCCASIONALLY SILTY; THICK BEDDED GRADING TO AND INTERBEDDED WITHIN SILTSTONE; NON TO POSSIBLY SLIGHTLY CALCAREOUS. 4195' SILTSTONE = MEDIUM GRAY TO BROWNISH GRAY; SOFT TO SLIGHTLY FIRM, OCCASIONALLY MODERATELY FIRM; CRUMBLY TO SUBCRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; MASSIVE CUTTINGS HABIT; DULL LUSTER; SILTY TO SLIGHTLY GRITTY TEXTURE; INTERBEDDED WITH AND GRADATIONAL TO CLAYSTONE; NON-TO VERY SLIGHTLY CALCAREOUS. 4235' CLAYSTONE = LIGHT BROWNISH GRAY TO OLIVE GRAY; VERY SOFT TO SOFT; MODERATELY COHESIVE; HIGH TO MODERATE ADHESIVE; LOW SOLUBLE; CURDY TO CLOTTED CONSISTENCY; PREDOMINANTLY AMORPHOUS MASSIVE CLAY WITH OCCASIONALLY IRREGULAR FRACTURE ON MORE INDURATED CUTTINGS; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, LOCALLY OCCASIONALLY SILTY; THICK BEDDED GRADING TO AND INTERBEDDED WTHIN SILTSTONE; NON TO POSSIBLY SLIGHTLY CALCAREOUS. EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 4285' SAND = WHITE TRANSLIGHTLY TO TRANSP; 100% UNCONSLIGHTLY AND IMBEDDED IN SOFT CLAYEY CUTTINGS; PREDOMINANTLY UNDIFFERENTIATED CHERT AND QUARTZ GRAINSWITH OCCASIONALLY LITHIC FRAGMENTS OF VARYING HUES; LOWER VERY FINE TO SILT; WELL SORTED; SUBANGULAR TO SUBROUNDED ON LARGER GRAINS; HIGH TO MODERATE SPHEROIDAL SPHERICITY OVERALL; LOOSE VERY THIN INTERBEDS AND BIT-FREED GRAINS FROM SILTSTONE INFERRED; NO DISCERNIBLE SAMPLE FLUORESCENCE OR CUT. 4340' SILTSTONE = MEDIUM GRAY TO BROWNISH GRAY; SOFT TO SLIGHTLY FIRM, OCCASIONALLY MODERATELY FIRM; CRUMBLY TO SUBCRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; MASSIVE CUTTINGS HABIT; DULL LUSTER; SILTY TO SLIGHTLY GRITTY TEXTURE; INTERBEDDED WITH / AND GRADATIONAL TO CLAYSTONE; NON-TO VERY SLIGHTLY CALCAREOUS. 4380' CLAYSTONE = LIGHT BROWNISH GRAY TO OLIVE GRAY; VERY SOFT TO SOFT; MODERATELY COHESIVE; HIGH TO MODERATE ADHESIVE; LOW SOLUBLE; CURDY TO CLOTTED CONSISTENCY; PREDOMINANTLY AMORPHOUS MASSIVE CLAY WITH OCCASIONALLY IRREGULAR FRACTURE ON MORE INDURATED CUTTINGS; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, LOCALLY OCCASIONALLY SILTY; THICK 4420' TUFF = WHITE TO VERY LIGHT GRAY TO YELLOWISH GRAY; SOFT TO SLIGHTLY FIRM, OCCASIONALLY MODERATELY FIRM; CRUMBLY; SUBBLOCKY FRACTURE; SUBTABULAR CUTTINGS HABIT; WAXY TO DULL LUSTER; SMOOTH TEXTURE; THIN, INTERBEDDED WITH CLAYSTONE AND SILTSTONE. 4455' SILTSTONE = MEDIUM GRAY TO BROWNISH GRAY; SOFT TO SLIGHTLY FIRM, OCCASIONALLY MODERATELY FIRM; CRUMBLY TO SUBCRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; MASSIVE CUTTINGS HABIT; DULL LUSTER; SILTY TO SLIGHTLY GRITTY TEXTURE; INTERBEDDED WITH AND GRADATIONAL TO CLAYSTONE; NON-TO VERY SLIGHTLY CALCAREOUS. 4495' CLAYSTONE = LIGHT BROWNISH GRAY TO OLIVE GRAY; VERY SOFT TO SOFT; MODERATELY COHESIVE; HIGH TO MODERATE ADHESIVE; LOW SOLUBLE; CURDY TO CLOTTED CONSISTENCY; PREDOMINANTLY AMORPHOUS MASSIVE CLAY WITH OCCASIONALLY IRREGULAR FRACTURE ON MORE INDURATED CUTTINGS; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, LOCALLY OCCASIONALLY SILTY. EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 4535' CARBONACEOUS MATERIAL = VERY DUSKY RED TO BROWNISH GRAY; SOFT; PASTY TO MUSHY; GREASY TO WAXY LUSTER; SMOOTH TEXTURE IN PART, FIBROUS AND WOODY IN PART; SOME MATERIAL VERY THIN LAMINAE LOOSE FROM CARBONACEOUS SHALE CUTTINGS, OTHER FRACTION THICKER AND OCCASIONALLY APPF_ARS SUBBITUMINOUS, O/W MOST MATERIAL APPEARS WOODY AND/OR FIBROUS. 4585' SILTSTONE = MEDIUM GRAY TO BROWNISH GRAY; SOFT TO SLIGHTLY FIRM, OCCASIONALLY MODERATELY FIRM; CRUMBLY TO SUBCRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; MASSIVE CUTTINGS HABIT; DULL LUSTER; SILTY TO SLIGHTLY GRITTY TEXTURE; INTERBEDDED WITH AND GRADATIONAL TO CLAYSTONE; ABUNDANT CARBON-ACEOUS FLECKS AND PARTICLES IN PART; NON-TO VERY SLIGHTLY CALCAREOUS; NO HYDROCARBON INDICATORS. 4630' CARBONACEOUS SHALE = BROWNISH GRAY TO MEDIUM GRAY; SLIGHTLY FIRM TO MODERATELY FIRM, OCCASIONALLY SOFT; CRUMBLY TO SUBBRITTLE; SUBBLOCKY FRACTURE; WEDGELIKE TO SUBTABULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TEXTURE, OCCASIONALLY SILTY; SPARSE TO MODERATE ABUNDANT VERY THIN LAMINATIONS OF CARBONACEOUS MATERIAL; PREDOMINANTLY SUBFISSILE; VERY SLIGHTLY CALCAREOUS. 4675' SANDSTONE = VERY LIGHT GRAY TO MEDIUM LIGHT GRAY, OCCASIONALLY MEDIUM GRAY; FRIABLE TO FIRM FRIABLE; LOWER VERY FINE TO SILT, OCCASIONALLY UPPER VERY FINE; WELL SORTED; SUBANGULAR TO ANGULAR, OCCASIONALLY SUBROUNDED; HIGH SPHEROIDAL SPHERICITY; MATRIX SUPPORTED AND CEMENTED; 50-60% CHERT 30-40% QUARTZ, REMAINDER VARIOUS UNDIF LITH FRAGMENTS; VERY POOR VISIBLE ESTIMATED POROSITY; TRACE MEDIUMYELLOW SAMPLE FLUORESCENCE- POSSIBLY FROM UPHOLE SANDSTONE; PREDOMINANTLY NO SAMPLE FLUORESCENCE OR CUT. 4735' CLAYSTONE = MEDIUM LIGHT GRAY TO LIGHT BROWNISH GRAY; MODERATELY FIRM TO SLIGHTLY FIRM, OCCASIONALLY SOFT; CRUMBLY; BLOCKY TO SUBPLANAR FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; THICK BEDDED GRADING TO AND INTERBEDDED WITH SILTSTONE. 4775' SILTSTONE = MEDIUM GRAY TO OLIVE GRAY; VERY FIRM TO SLIGHTLY HARD, OCCASIONALLY LESS INDURATED; SUBBRITTLE TO BRITTLE; BLOCKY TO IRREGULAR FRACTURE WEDGELIKE CUTTINGS HABIT; SILTY TEXTURE, EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 LOCALLY GRITTY; VERY SLIGHTLY CALCAREOUS; NO HYDROCARBON INDICATORS. 4840' CLAYSTONE = MEDIUM LIGHT GRAY TO LIGHT BROWNISH GRAY; MODERATELY FIRM TO SLIGHTLY FIRM, OCCASIONALLY SOFT; CRUMBLY; BLOCKY TO SUBPLANAR FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; DISSEMINATED CARBONACEOUS MATERIAL; NON-TO SLIGHTLY CALCAREOUS. 4875' SANDSTONE = MEDIUM GRAY TO OLIVE GRAY; FRIABLE; LOWER FINE GRADING TO SILT; WELL TO FAIR SORTING; SUBANGULAR TO SUBROUNDED; MODERATE TO HIGH SPHEROIDAL SPHERICITY; CLAY MATRIX SUPPORTED WITH SOME GRAIN SUPPORT; MODERATE TRACE DISSEMINATED CARBONACEOUS MATERIAL; 50-70% QUARTZ, 30-50% CHERT, TRACE OTHER LITHIC FRAGMENTS; POOR VISIBLE ESTIMATED POROSITY; VERY FAINT DULL YELLOW SAMPLE FLUORESCENCE WITH NO DISCERNIBLE CUT; NO OTHER HYDROCARBON INDICATORS. 4935' SILTSTONE = MEDIUM GRAY TO OLIVE GRAY; FIRM TO VERY FIRM, OCCASIONALLY SOFT; SUBBRITTLE TO CRUMBLY; BLOCKY TO IRREGULAR FRACTURE; WEDGELIKE CUTTINGS HABIT; SILTY TO GRITTY TEXTURE; LOCALLY INTERBEDDED WITH AND GRADING TO CLAYSTONE; VERY SLIGHTLY CALCAREOUS; NO HYDROCARBON INDICATORS. 4975' CLAYSTONE = MEDIUM LIGHT GRAY TO LIGHT BROWNISH GRAY; MODERATELY FIRM TO SLIGHTLY FIRM, OCCASIONALLY SOFT; CRUMBLY; BLOCKY TO SUBPLANAR FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; THICK BEDDED GRADING TO AND INTERBEDDED WITH SILTSTONE. 5015' TUFF = WHITE TO VERY LIGHT GRAY; VERY SOFT; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT APPEARS PARTIALLY BLENDED WITH CLAYSTONE IN SAMPLE, NO CONSOLIDATED CUTTINGS DETECTED; WAXY LUSTER; SMOOTH TO CLAYEY TEXTURE; NO DISCERNIBLE STRUCTURE. 5050' CLAYSTONE = LIGHT BROWNISH GRAY TO MEDIUM LIGHT GRAY; SLIGHTLY FIRM TO SOFT, OCCASIONALLY MODERATELY FIRM; MODERATE TO HIGH COHESION; MODERATE ADHESION; PASTY TO MUSHY; FIRMER CUTTINGS CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT, OCCASIONALLY MASS; DULL TO EARTHY LUSTER; SMOOTH EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 TO SILTY TEXTURE; THICK BEDDED GRADING TO AND INTERBEDDED WITH SILTSTONE. 5100' SILTSTONE = MEDIUM GRAY TO OLIVE GRAY; FIRM TO VERY FIRM, OCCASIONALLY SOFT; SUBBRITTLE TO CRUMBLY; BLOCKY TO IRREGULAR FRACTURE; WEDGELIKE CUTTINGS HABIT; SILTY TO GRITTY TEXTURE; LOCALLY INTERBEDDED WITH AND GRADING TO CLAYSTONE; VERY SLIGHTLY CALCAREOUS; NO HYDROCARBON INDICATORS. 5140' CARBONACEOUS SHALE = BROWNISH GRAY TO MEDIUM GRAY; SLIGHTLY FIRM TO MODERATELY FIRM, OCCASIONALLY SOFT; CRUMBLY TO SUBBRITTLE; SUBBLOCKY FRACTURE; WEDGELIKE TO SUBTABULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TEXTURE, OCCASIONALLY SILTY; ABUNDANT DISSEMINATED FLECKS OF CARBONACEOUS MATERIAL; SUBFISSILE; NON-CALCAREOUS. 5185' SANDSTONE = MEDIUM GRAY TO OLIVE GRAY; FRIABLE; LOWER FINE GRADING TO SILT; WELL TO FAIR SORTING; SUBANGULAR TO SUBROUNDED; MODERATE TO HIGH SPHEROIDAL SPHERICITY; CLAY MATRIX SUPPORTED WITH SOME GRAIN SUPPORT; MODERATE TRACE DISSEMINATED CARBONACEOUS MATERIAL; 50-70% QUARTZ, 30-50% CHERT, TRACE OTHER LITHIC FRAGMENTS; POOR VISIBLE ESTIMATED POROSITY; FAINT DULL YELLOW SAMPLE FLUOR-ESCENCE WITH SLOW PALE BLUE-WHITE MULTISTREAMING CUT; PALE YELLOW RESIDUAL FLUORESCENCE. 5250' CLAYSTONE = LIGHT BROWNISH GRAY TO MEDIUM LIGHT GRAY; SLIGHTLY FIRM TO SOFT, OCCASIONALLY MODERATELY FIRM; MODERATE TO HIGH COHESION; MODERATE ADHESION; PASTY TO MUSHY; FIRMER CUTTINGS CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT, OCCASIONALLY MASS; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; THICK BEDDED INTERBEDDED WITH SILTSTONE AND THIN SANDSTONE. 5300' CARBONACEOUS SHALE = BROWNISH GRAY TO MEDIUM GRAY; SLIGHTLY FIRM TO MODERATELY FIRM, OCCASIONALLY SOFT; CRUMBLY TO SUBBRITTLE; SUBBLOCKY FRACTURE; WEDGELIKE TO SUBTABULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TEXTURE, OCCASIONALLY SILTY; ABUNDANT DISSEMINATED FLECKS OF CARBONACEOUS MATERIAL; SUBFISSILE; NON-CALCAREOUS. EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 5345' SILTSTONE = MEDIUM GRAY TO OLIVE GRAY; FIRM TO VERY FIRM, OCCASIONALLY SOFT; SUBBRITTLE TO CRUMBLY; BLOCKY TO IRREGULAR FRACTURE; WEDGELIKE CUTTINGS HABIT; SILTY TO GRITTY TEXTURE; LOCALLY INTERBEDDED WITH AND GRADING TO CLAYSTONE, INTERBEDDED WITH AND POSSIBLY GRADING TO SANDSTONE; NON CALCAREOUS; FAINT PALE GREENISH YELLOW SAMPLE FLUORESCENCE WITH NO DISCERNIBLE CUT. 5395' SANDSTONE = MEDIUM LIGHT GRAY TO LIGHT OLIVE GRAY TO LIGHT BROWNISH GRAY OVERALL WITH INDIVIDUAL GRAINS WHITE TRANSLIGHTLY TO TRANSP, OCCASIONALLY LIGHT BROWN TO BROWNISH BLACK; FRIABLE TO FIRM FRIABLE; UPPER VERY FINE TO LOWER VERY FINE, OCCASIONALLY LOWER FINE; WELL SORTED; SUBANGULAR TO ANGULAR, RARE SUBROUNDED; MODERATE TO HIGH SPHEROIDAL SPHERICITY, OCCASIONALLY LOW TO MODERATE DISCOIDAL SPHERICITY; WEAK CALCAREOUS CEMENT WITH CLAY MATRIX SUPPORT, OCCASIONALLY GRAIN SUPPORT; ABUNDANT SUBBITUMINOUS TO BITUMINOUS COAL FRAGMENTS AND OTHER CARBONACEOUS MATERIAL WITHIN SANDSTONE CUTTINGS; POOR TO FAIR VISIBLE ESTIMATED POROSITY; PALE GREEN TO DULL YELLOW SAMPLE FLUORESCENCE WITH VERY SLOW TO SLOW MILKY WHITE MULTISTREAMING CUT; PALE STRAW VISIBLE CUT; FAINT BLUE-WHITE RESIDUAL FLUORESCENCE; NO LIVE POPS IN MUD SAMPLE. 5495' CARBONACEOUS SHALE = BROWNISH GRAY TO MEDIUM GRAY; SLIGHTLY FIRM TO MODERATELY FIRM, OCCASIONALLY SOFT; CRUMBLY TO SUBBRITTLE; SUBBLOCKY FRACTURE; WEDGELIKE TO SUBTABULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TEXTURE, OCCASIONALLY SILTY; ABUNDANT DISSEMINATED FLECKS OF CARBONACEOUS MATERIAL; SUBFISSILE; NON-CALCAREOUS. 5540' GRAY OVERALL WITH INDIVIDUAL GRAINS TRANSPARENT TOWHITE TRANSLUCENT, OCCASIONALLY LIGHT GREENISH GRAY, LIGHT BLUISH GRAY, RARE PINKISH GRAY; PREDOMINANTLY FIRM FRIABLE TO FRIABLE, OCCASIONALLY MODERATE HARD; LOWER VERY FINE TO UPPER VERY FINE, OCCASIONALLY LOWER FINE; ABUNDANT SILT; WELL SORTED; SUBANGULAR TO SUBROUNDED; HIGH TO MODERATE SPHEROIDAL SPHERICITY; HIGH CLAY/SILT PACKED MATRIX WITH SOME GRAIN SUPPORT; WEAK TO MODERATE CALCAREOUS CEMENT; 60-70% QUARTZ, 20-30% CHERT, 10% METALITHIC FRAGMENTS, TRACE CARBONACEOUS FRAGMENTS; POOR VISIBLE ESTIMATED POROSITY; PALE DULL GREENISH YELLOW SAMPLE FLUORESCENCE WITH VERY SLOW MILKY WHITE MULTISTREAMING CUT; NO VISIBLE LIGHT CUT; VERY WEAK MILKY BLUE-WHITE RESIDUAL FLUORESCENCE; NO MUD POPS; NO PETROLEUM ODOR IN SAMPLE. EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 5635' SANDSTONE = LIGHT BROWNISH GRAY TO OLIVE GRAY OVERALL WITH INDIVIDUAL GRAINS TRANSPARENT TOWHITE TRANSLUCENT, OCCASIONALLY LIGHT GREENISH GRAY, LIGHT BLUISH GRAY, RARE PINKISH GRAY; PREDOMINANTLY FIRM FRIABLE TO FRIABLE, OCCASIONALLY MODERATE HARD; UPPER VERY FINE TO LOWER FINE, OCCASIONALLY UPPER FINE; ABUNDANT SILT; WELL SORTED; SUBANGULAR TO SUBROUNDED; HIGH TO MODERATE SPHEROIDAL SPHER-IClTY; HIGH CLAY/SILT PACKED MATRIX WITH SOME GRAIN SUPPORT; WEAK TO MODERATE CALCAREOUS CEMENT; 70-80% QUARTZ, 10-20% CHERT, 10-20% VARIOUS METALITHIC FRAGMENTS; TRACE CARBONACEOUS FRAGMENTS; POOR VISIBLE ESTIMATED POROSITY; PALE DULL GREENISH GRAY TO YELLOWISH GRAY SAMPLE FLUORESCENCE WITH VERY SLOW MILKY WHITE MULTISTREAMING CUT; NO VISIBLE LIGHT CUT; VERY WEAK MILKY BLUE- WHITE RESIDUAL FLUORESCENCE; NO MUD POPS. 5735' CARBONACEOUS SHALE = BROWNISH GRAY TO MEDIUM GRAY; SLIGHTLY FIRM TO MODERATELY FIRM, OCCASIONALLY SOFT; CRUMBLY TO SUBBRITTLE; SUBBLOCKY FRACTURE; WEDGELIKE TO SUBTABULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TEXTURE, OCCASIONALLY SILTY; ABUNDANT DISSEMINATED FLECKS OF CARBONACEOUS MATERIAL; SUBFISSlLE; NON-CALCAREOUS. 5780' SiLTSTONE = MEDIUM GRAY TO OLIVE GRAY; FIRM TO VERY FIRM, OCCASIONALLY SOFT; SUBBRITTLE TO CRUMBLY; BLOCKY TO IRREGULAR FRACTURE; WEDGELIKE CUTTINGS HABIT; SILTY TO GRITTY TEXTURE; LOCALLY INTERBEDDED WITH AND GRADING TO CLAYSTO.NE, INTERBEDDED WITH AND POSSIBLY GRADING TO SANDSTONE; NON CALCAREOUS; FAINT PALE GREENISH YELLOW SAMPLE FLUORESCENCE WITH NO DISCERNIBLE CUT. 5830' CLAYSTONE = LIGHT BROWNISH GRAY TO MEDIUM LIGHT GRAY; SLIGHTLY FIRM TO SOFT, OCCASIONALLY MODERATELY FIRM; MODERATE TO HIGH COHESION; MODERATE ADHESION; PASTY TO MUSHY; FIRMER CUTTINGS CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT, OCCASIONALLY MASS; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; THICK BEDDED INTERBEDDED WITH SILTSTONE. 5880' SANDSTONE = LIGHT BROWNISH GRAY TO OLIVE GRAY OVERALL WITH INDIVIDUAL GRAINS TRANSPARENT TOWHITE TRANSLUCENT, OCCASIONALLY LIGHT GREENISH GRAY, LIGHT BLUISH GRAY, RARE PINKISH GRAY; PREDOMINANTLY FIRM FRIABLE TO FRIABLE, OCCASIONALLY MODERATE HARD; UPPER VERY FINE TO LOWER FINE, OCCASIONALLY UPPER FINE; EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 ABUNDANT SILT; WELL SORTED; SUBANGULAR TO SUBROUNDED; HIGH TO MODERATE SPHEROIDAL SPHERICITY; HIGH CLAY/SILT PACKED MATRIX WITH SOME GRAIN SUPPORT; WEAK TO MODERATE CALCAREOUS CEMENT; 70-80% QUARTZ, 10-20% CHERT, 10-20% VARIOUS METALITHIC FRAGMENTS; TRACE CARBONACEOUS FRAGMENTS; POOR VISIBLE ESTIMATED POROSITY; PALE DULL GREENISH GRAY TO YELLOWISH GRAY SAMPLE FLUORESCENCE WITH MODERATE FAST MILKY LIGHT YELLOW CUT; OCCASIONALLY MEDIUM/DARK GRAY, THIN, RESISTANT BANDS OF U MEDIUM GRAINED,SILICA-CEMENTED SANDSTONE INTERFINGERS ASSOC WITH MEDIUM GRAINED BLACK CARBONACEOUS FRAGMENTS; 5980' SILTSTONE = MEDIUM GRAY TO OLIVE GRAY; FIRM TO VERY FIRM, OCCASIONALLY SOFT; SUBBRITTLE TO CRUMBLY; BLOCKY TO IRREGULAR FRACTURE; WEDGELIKE CUTTINGS HABIT; SILTY TO GRITTY TEXTURE; LOCALLY INTERBEDDED WITH AND GRADING TO CLAYSTONE, INTERBEDDED WITH AND POSSIBLY GRADING TO SANDSTONE; NON CALCAREOUS; FAINT PALE GREENISH YELLOW SAMPLE FLUORESCENCE WITH NO DISCERNIBLE CUT. 6030' TUFF = WHITE TO VERY LIGHT GRAY; SOFT TO SLIGHTLY FIRM, OCCASIONALLY MODERATELY FIRM; OCCASIONALLY CRUMBLY; ROUNDED MARGINS; GELATINOUS; WAXY TO DULL LUSTER; SMOOTH TEXTURE; THINLY INTERBEDDED WITHCLAYSTONE AND SILTSTONE; ORANGE, mm DIAMETER OXIDIZED PATCHES NOTED DISSEMINATED THROUGHOUT. 607O' CLAYSTONE = LIGHT BROWNISH GRAY TO MEDIUM LIGHT GRAY; SLIGHTLY FIRM TO SOFT, OCCASIONALLY MODERATELY FIRM; MODERATE TO HIGH COHESION; MODERATE ADHESION; PASTY TO MUSHY; FIRMER CUTTINGS CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT, OCCASIONALLY MASSIVE; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; INCR SHALEY CLVG DEFINED BY THIN, DARK GRAY WISPY LAMELLAE; INTERBEDDED BOTH WITH SILTSTONE AND SANDSTONE; OCCASIONALLY WEAK MILKY CUT FLUORESCENCE VERY THIN CLAY SEAMS NOTED WITHIN SILTSTONE 6130' SANDSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY; OVERALL WITH INDIVIDUAL GRAINS TRANSPARENT TOWHITE TRANSLUCENT, OCCASIONALLY LIGHT GREENISH GRAY, PREDOMINANTLY FIRM TO FRIABLE, OCCASIONALLY MODERATE HARD; UPPER VERY FINE TO UPPER FINE, OCCASIONALLY LOWER MED; ABUNDANT SILT; WELL SORTED; SUBANGULAR TO SUBROUNDED; HIGH TO MODERATE SPHEROIDAL SPHERICITY; HIGH CLAY/SILT PACKED MATRIX WITH DOMINANTLY GRAIN SUPPORT; WEAK TO MODERATE CALCAREOUS CEMENT; 70-80% QUARTZ, 10% CHERT, 10-20% VARIOUS METALITHIC EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 FRAGMENTS; 5% CARBONACEOUS FRAGMENTS; GRAINED VISIBLE ESTIMATED POROSITY; SPOTTY PALE BRITE GRAYISH YELLOW SAMPLE FLUORESCENCE WITH MODERATE FAST MILKY LIGHT YELLOW FLUORESCENCE AND LIGHT YELLOW STREAMING CUT 6210' SILTSTONE = MEDIUM GRAY TO OLIVE GRAY; FIRM TO VERY FIRM, OCCASIONALLY SOFT; SUBBRITTLE TO CRUMBLY; BLOCKY TO IRREGULAR FRACTURE; WEDGELIKE CUTTINGS HABIT; SILTY TO GRITTY TEXTURE; LOCALLY INTERBEDDED WITH AND GRADING TO CLAYSTONE, INTERBEDDED WITH SANDSTONE; WEAK MICROSPARKLES; NON CALCAREOUS; OCCASIONALLY WEAK PALE GREENISH YELLOW SAMPLE FLUORESCENCE WITH NO DISCERNIBLE CUT. 6260' TUFF = WHITE TO VERY LIGHT GRAY; SOFT TO SLIGHTLY FIRM, OCCASIONALLY MODERATELY FIRM; WEAKLY CALCAREOUS OCCASIONALLY CRUMBLY; ROUNDED MARGINS; GELATINOUS; WAXY TO DULL LUSTER; SMOOTH TEXTURE; THINLY INTERBEDDED WITHCLAYSTONE AND SILTSTONE; ORANGE, mm DIAMETER OXIDIZED PATCHES NOTED DISSEMINATED THROUGHOUT. 6310' SANDSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY; OVERALL WITH INDIVIDUAL GRAINS TRANSPARENT TOWHITE TRANSLUCENT, OCCASIONALLY LIGHT GREENISH GRAY, PREDOMINANTLY FIRM TO FRIABLE, OCCASIONALLY MODERATE HARD; UPPER VERY FINE TO UPPER FINE, OCCASIONALLY LOWER MEDIUM; ABUNDANT SILT; WELL SORTED; SUBANGULAR TO SUBROUNDED; HIGH TO MODERATE SPHEROIDAL SPHERICITY; HIGH CLAY/SILT PACKED MATRIX WITH DOMINANTLY GRAIN SUPPORT; WEAK TO MODERATE CALCAREOUS CEMENT; OIL TAR BLEBS NOTED TO mm DIAMETERSIZE DISSEMINATED 6350-6380' SAMPLES; 70-80% QUARTZ, 10% CHERT, 10-20% VARIOUS METALITHIC FRAGMENTS; 5% CARBONACEOUS FRAGMENTS; GOOD VISIBLE ESTIMATED POROSITY; ANGULAR QUARTZ GRAINS/CARBONACEOUS MATERIAL ORIENTATED ALONG BEDDING PLANES. 6395' CLAYSTONE = LIGHT BROWNISH GRAY TO MEDIUM LIGHT GRAY; SLIGHTLY FIRM TO SOFT, OCCASIONALLY MODERATELY FIRM; MODERATE TO HIGH COHESION; MODERATE ADHESION; PASTY TO MUSHY; FIRMER CUTTINGS CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT, OCCASIONALLY MASSIVE; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; OCCASIONALLY SHALEY CLVG DEFINED BY THIN, DARK GRAY WISPY LAMELLAE; INTERBEDDED BOTH WITH SlLTSTONE AND SANDSTONE; OCCASIONALLY WEAK MILKY CUT FLUORESCENCE VERY THIN CLAY SEAMS NOTED WITHIN SILTSTONE [:l EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS ~2 6455' SILTSTONE = MEDIUM GRAY TO OLIVE GRAY; FIRM TO VERY FIRM, OCCASIONALLY SOFT; SUBBRITTLE TO CRUMBLY; BLOCKY TO IRREGULAR FRACTURE; WEDGELIKE CUTTINGS HABIT; SILTY TO GRITTY TEXTURE; LOCALLY INTERBEDDED WITH AND GRADING TO CLAYSTONE, INTERBEDDED WITH SANDSTONE; WEAK MICROSPARKLES; NON CALCAREOUS; OCCASIONALLY WEAK PALE GREENISH YELLOW SAMPLE FLUORESCENCE WITH NO DISCERNIBLE CUT. 6530' SANDSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY; OVERALL WITH INDIVIDUAL GRAINS TRANSPARENT TO WHITE, TRANSLUCENT, OCCASIONALLY LIGHT GREENISH GRAY, DOMINANTLY FIRM TO FRIABLE, OCCASIONALLY MODERATE HARD; UPPER VERY FINE TO UPPER FINE, RRLY LOWER MED; ABUNDANT SILT; WELL SORTED; SUBANGULAR TO SUBROUNDED; HIGH TO MODERATE SPHERICITY; HIGH CLAY/SILT PACKED MATRIX WITH DOMINANTLY GRAIN SUPPORT; OCCASIONALLY WEAK CALCAREOUS CEMENT; 70-80% QUARTZ, 10% CHERT, 10-20% VARIOUS METALITHIC FRAGMENTS; 2-3% CARBONACEOUS FRAGMENTS; GRAINED VISIBLE ESTIMATED POROSITY; ANGULAR QUARTZ GRAINS / CARBONACEOUS MATERIAL ORIENTATED ALONG BEDDING PLANES. 6615' SILTSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY, OCCASIONALLY BROWNISH GRAY; MODERATELY FIRM TO VERY FIRM CRUMBLY TO BRITTLE; IRREGULAR TO BLOCKY FRACTURE WEGELIKE TO TABULAR CUTTINGS HABIT; DULL LUSTER; SILTY TO GRITTY TEXTURE; CUTTINGS GRADE TO SANDSTONE IN PART; VERY FAINT DULL GREENISH GRAY SAMPLE FLUORESCENCE WITH NO DISCERNIBLE CUT; NO OTHER HYDROCARBON INDICATORS. 6665' SANDSTONE = MEDIUM LIGHT GRAY TO LIGHT BLUISH GRAY TO GREENISH GRAY, OCCASIONALLY MEDIUM BLUISH GRAY; FIRM FRIABLE TO FRIABLE; OCCASIONALLY EASY FRIABLE; LOWER VERY FINE TO SILTY, OCCASIONALLY UPPER VERY FINE; WELL SORTED; SUBROUNDED TO SUBANGULAR; HIGH TO VERY HIGH SPHEROIDAL SPHERICITY; SLIGHTLY TO MODERATE CALCITE CEMENTED; PREDOMINANTLY GRAIN-SUPPORTED WITH ABUNDANT CLAY/SILT MATRIX, OCCASIONALLY TUFF PACKED; INDIVIDUAL GRAINS PREDOMINANTLY TRANSPARENT TO WHITE TRANSLUCENT, OCCASIONALLY LIGHT BROWNISH GRAY; GREENISH GRAY; 80+% QUARTZ, 10%CHERT, TRACE METALITHIC FRAGMENTS, RARE TRACE CARBONACEOUS MATERIAL; DULL PALE YELLOW TO GREENISH GRAY SAMPLE FLUORESCENCE; SLOW TO VERY SLOW MULTISTREAMING MILKY WHITE CUT; MODERATE TO WEAK CRUSH CUT. 6750' SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY; MODERATELY FIRM TO SLIGHTLY HARD; SUBBRITTLE TO BRITTLE; BLOCKY TO PLANAR FRACTURE; EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS ~2 PLATY CUTTINGS HABIT; EARTHY TO DULL LUSTER; SMOOTH TO CLAYEY TEXTURE; SUBFISSlLE; SLIGHTLY CALCAREOUS. 678O' SILTSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY, OCCASIONALLY BROWNISH GRAY; MODERATELY FIRM TO VERY FIRM CRUMBLY TO BRITTLE; IRREGULAR TO BLOCKY FRACTURE WEGELIKE TO TABULAR CUTTINGS HABIT; DULL LUSTER; SILTY TO GRITTY TEXTURE; CUTTINGS GRADE TO SANDSTONE IN PART; VERY FAINT DULL GREENISH GRAY SAMPLE FLUORESCENCE WITH NO DISCERNIBLE CUT; NO OTHER HYDROCARBON INDICATORS. 6830' SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY; MODERATELY FIRM TO SLIGHTLY HARD; SUBBRITTLE TO BRITTLE; BLOCKY TO PLANAR FRACTURE; PLATY CUTTINGS HABIT; EARTHY TO DULL LUSTER; SMOOTH TO CLAYEY TEXTURE; SUBFISSILE; LOCALLY ABUNDANT WOODY FIBROUS MATERIAL, OCCASIONALLY COALY LAMINAE, SLIGHTLY CALCAREOUS. 6870' SANDSTONE = MEDIUM LIGHT GRAY TO LIGHT BLUISH GRAY TO GREENISH GRAY, OCCASIONALLY MEDIUM BLUISH GRAY; FIRM FRIABLE TO FRIABLE; OCCASIONALLY EASY FRIABLE; LOWER VERY FINE TO SILT, OCCASIONALLY UPPER VERY FINE; WELL SORTED; SUBROUNDED TO SUBANGULAR; HIGH TO VERY HIGH SPHEROIDAL SPHERICITY; SLIGHTLY TO MODERATE CALCITE CEMENTED; PREDOMINANTLY GRAIN-SUPPORTED WITH ABUNDANT CLAY/SILT MATRIX, OCCASIONALLY TUFF PACKED; INDIVIDUAL GRAINS PREDTRANSPARENT TOWHITE TRANSLUCENT, OCCASIONALLY LIGHT BROWNISH GRAY; GREENISH GRAY; 80+% QUARTZ, 10% CHERT, TRACE METALITHIC FRAGMENTS, RARE TRACE CARBONACEOUS MATERIAL; DULL PALE YELLOW TO GREENISH GRAY SAMPLE FLUORESCENCE; SLOW TO VERY SLOW MILKY WHITE CUT; MODERATE TO WEAK CRUSH CUT. 6955' CLAYSTONE = LIGHT BROWNISH GRAY TO MEDIUM GRAY; SLIGHTLY FIRM TO SOFT, OCCASIONALLY MODERATELY FIRM; MODERATE TO HIGH COHESION; MODERATE ADHESION; PASTY TO MUSHY; FIRMER CUTTINGS CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT, OCCASIONALLY MASSIVE; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; GRADES TO CLAY-RICH SHALE; OCCASIONALLY DARK GRAY CARBONACEOUS MATERIAL; INTERBEDDED BOTH WITH SILTSTONE AND SANDSTONE; OCCASIONALLY WEAK MILKY CUT FLUOR 7010' SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY; MODERATELY FIRM TO SLIGHTLY HARD; SUBBRITTLE TO BRITTLE; BLOCKY TO PLANAR FRACTURE; PLATY CUTTINGS HABIT; EARTHY TO DULL LUSTER; SMOOTH TO CLAYEY TEXTURE; SUBFISSILE; RARE WOODY MATERIAL, OCCASIONALLY DARK GRAY EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 CRBNAC BANDS; CLAY-RICH SECTIONS ARE LESS RESISTANT. ABUNDANT MICROSPARKLES EVENLY DISSEMINATED; COMMONLY SANDWICHES CLAY/CLAYSTONE. 7060' SILTSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY, OCCASIONALLY BROWNISH GRAY; MODERATELY FIRM TO VERY FIRM CRUMBLY TO BRITTLE; IRREGULAR TO BLOCKY FRACTURE WEGELIKE TO TABULAR CUTTINGS HABIT; DULL LUSTER; SILTY TO GRITTY TEXTURE; CUTTINGS GRADE TO SANDSTONE IN PART; VERY FAINT DULL GREENISH GRAY SAMPLE FLUORESCENCE WITH NO DISCERNIBLE CUT; NO VISIBLE OIL. 7105' GRAY; FIRM FRIABLE TO FRIABLE; OCCASIONALLY EASY FRIABLE; LOWER VERY FINE TO SILT, OCCASIONALLY UPPER VERY FINE; WELL SORTED; SUBROUNDED TO SUBANGULAR; GOOD SPHERICITY; SLIGHTLY TO MODERATE CALCITE CEMENTED; DOMINANTLY GRAIN SUPPORTED WITH ABUNDANT CLAY/SILT MATRIX, OCCASIONALLY TUFF PACKED; INDIVIDUAL GRAINS DOMINANTLYTRANSPARENT TOWHITE TRANSLUCENT, OCCASIONALLY LIGHT BROWNISH GRAY; 80+% QUARTZ, 10% CHERT, TRACE METALITHIC FRAGMENTS, 2-3% CARBONACEOUS MATERIAL; PALE YELLOW TO GREENISH SAMPLE FLUORESCENCE; INSTANT LIGHT YELLOW STREAMING FLUOR; MODERATE RESIDUAL CUT FLUORESCENCE 7180' CLAYSTONE = LIGHT BROWNISH GRAY TO MEDIUM GRAY; SLIGHTLY FIRM TO SOFT, OCCASIONALLY MODERATELY FIRM; MODERATE TO HIGH COHESION; MODERATE ADHESION; PASTY TO MUSHY; FIRMER CUTTINGS CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT, OCCASIONALLY MASSIVE; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; GRADES TO CLAY-RICH SHALE; OCCASIONALLY DARK GRAY CARBONACEOUS MATERIAL; INTERBEDDED BOTH WITH SILTSTONE AND SANDSTONE; OCCASIONALLY MILKY CUT FLUORESCENCE 7235' SHALE = MEDIUM DARK GRAY TO DARK GRAY; MODERATELY FIRM TO SLIGHTLY HARD; SUBBRITTLE TO BRITTLE; BLOCKY TO PLANAR FRACTURE; PLATY CUTTINGS HABIT; EARTHY TO DULL LUSTER; SMOOTH TO CLAYEY TEXTURE; SUBFISSILE; OCCASIONALLY DARK GRAY CARBONACEOUS BANDS; CLAY-RICH SECTIONS ARE LESS RESISTANT; ABUNDANT MICROSPARKLES EVENLY DISSEMINATED; COMMONLY SANDWICHES CLAY/CLAYSTONE. 7285' SILTSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY, OCCASIONALLY BROWNISH HUES; MODERATELY FIRM TO VERY FIRM CRUMBLY TO BRITTLE; IRREGULAR TO BLOCKY FRACTURE WEGELIKE TO TABULAR CUTTINGS HABIT; DULL LUSTER; SILTY TO GRITTY TEXTURE; CUTTINGS GRADE TO SANDSTONE EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 IN PART; OCCASIONALLY DULL GREEN SAMPLE FLUORESCENCE WITH MODERATE MILKY CUT FLUORESCENCE. 7330' SANDSTONE = MEDIUM LIGHT GRAY TO MEDIUM DARK GRAY; FIRM FRIABLE TO FRIABLE; OCCASIONALLY EASY FRIABLE; LOWER VERY FINE TO SILT, OCCASIONALLY UPPER VERY FINE; WELL SORTED; SUBROUNDED TO SUBANGULAR; GOOD SPHERICITY; SLIGHTLY TO MODERATE CALCITE CEMENTED; DOMINANTLY GRAIN SUPPORTED WITH ABUNDANT CLAY/SILT MATRIX, TRACE CHALCOPYRITE OCCASIONALLY TUFF PACKED; INDIVIDUAL GRAINS DOMINANTLYTRANSPARENT TOWHITE TRANSLUCENT, OCCASIONALLY LIGHT BROWNISH GRAY; 80+% QUARTZ, 10% CHERT, TRACE METALITHIC FRAGMENTS, 2-3% CARBONACEOUS MATERIAL; PALE YELLOW TO GREENISH SAMPLE FLUORESCENCE; INSTANT LIGHT YELLOW STREAMING FLUOR; MODERATE SPOTTY RESIDUAL CUT FLUORESCENCE. 7420' SHALE = GRAYISH BLACK TO BROWNISH BLACK; MODERATELY FIRM TO SLIGHTLY HARD; SUBBRITTLE TO BRITTLE; DOMINANTLYPLANAR FRACTURE; PLATY CUTTINGS HABIT; EARTHY TO DULL LUSTER; SMOOTH TO CLAYEY TEXTURE; HARDENS WITH DEPTH; OCCASIONALLY DARK GRAY CARBONACEOUS BANDS; CLAY-RICH SECTIONS ARE LESS RESISTANT; ABUNDANT MICROSPARKLES DISSEMINATED THROUGHOUT; PALE YELLOW TO GREENISH SAMPLE FLUORESCENCE; SLOW LIGHT YELLOW STREAMING FLUOR; MODERATE SPOTTY RESIDUAL CUT FLUORESCENCE. 7480' SILTSTONE = BROWNISH GRAY TO DARK GRAY, OCCASIONALLY MEDIUM DARK GRAY; MODERATELY FIRM TO VERY FIRM CRUMBLY TO BRITTLE; IRREGULAR TO BLOCKY FRACTURE WEGELIKE TO TABULAR CUTTINGS HABIT; DULL LUSTER; SILTY TO GRITTY TEXTURE; OCCASIONALLY DULL GREEN SAMPLE FLUORESCENCE WITH WEAK LIGHT YELLOW CUT FLUORESCENCE. 7520' LIMESTONE = GRAYISH RED; MASSIVE TO CRYPTO-CRYSTALLINE; HARD; BRITTLE; REACTS QUICKLY WITH DILUTE HCI; SHARP EDGED SHARDS TO BLOCKY CUTTINGS; VITREOUS, SMOOTH APPEARANCE; 7550' SILTSTONE = BROWNISH GRAY TO BROWNISH BLACK, MODERATELY FIRM TO VERY FIRM CRUMBLY TO BRITTLE; IRREGULAR TO BLOCKY FRACTURE WEDGELIKE TO TABULAR CUTTINGS HABIT; DULL LUSTER; SILTY TO GRITTY TEXTURE; OCCASIONALLY DULL GREEN SAMPLE FLUORESCENCE WITH VERY SLOW, SPOTTY, LIGHT YELLOW CUT FLUORESCENCE. EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 7590' SHALE = BROWNISH GRAY TO BROWNISH BLACK; MODERATELY FIRM TO SLIGHTLY HARD; SUBBRITTLE TO BRITTLE; PLANAR FRACTURE; PLATY CUTTINGS HABIT; SMOOTH APPEARANCE; VERY THIN BDD; HARDENING WITH DEPTH; SILKY "METAMORPHOSED" LUSTER; ABUNDANT MICROSPARKLES DISSEMINATED THROUGHOUT; PALE YELLOW TO GREENISH SAMPLE FLUORESCENCE; SLOW LIGHT YELLOW STREAMING FLUOR; MODERATE SPOTTY RESIDUAL CUT FLUORESCENCE. 7680' SILTSTONE = PALE BROWN TO LIGHT BROWNISH GRAY TO BROWNISH GRAY; MODERATELY FIRM TO VERY FIRM, OCCASIONALLY SOFT; CRUMBLY TO SUBBRITTLE; IRREGULAR TO SUBBLOCKY FRACTURE; WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; INTERBEDDED WITHTHIN WELL INDURATED SHALE, RARE CLAYSTONE; LOCALLY INFUSED WITH LOWER VERY FINE SAND; MODERATE TRACE PYRITE AGGREGATE; RARE TRACE SIDERITE IN GENERAL SAMPLE; NO SAMPLE FLUORESCENCE; NO CUT DISCERNIBLE BEYOND MUD ADDITIVE. 7745' SHALE = MEDIUM DARK GRAY TO DARK GRAY; HARD TO VERY FIRM; BRITTLE TO SUBBRITTLE; PLANAR TO CONCHOIDAL FRAC, OCCASIONALLY SPLINTERY PLATY TO ELONGATED FLAKY CUTTINGS HABIT; DULL LUSTER; SMOOTH TO CLAYEY TEXTURE; SUBFISSILE, OCCASIONALLY FISSILE; THIN INTERBEDDED WITH SILTSTONE; NON CALCAREOUS. 7785' CLAYSTONE = LIGHT BROWNISH GRAY TO MEDIUM LIGHT GRAY; SLIGHTLY FIRM TO SOFT, OCCASIONALLY MODERATELY FIRM; MODERATE TO HIGH COHESION; MODERATE ADHESION; PASTY TO MUSHY; FIRMER CUTTINGS CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT, OCCASIONALLY MASS; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; SLIGHTLY TO MODERATE CALCAREOUS. 783O' SILTSTONE = PALE BROWN TO LIGHT BROWNISH GRAY TO BROWNISH GRAY; MODERATELY FIRM TO VERY FIRM, OCCASIONALLY SOFT; CRUMBLY TO SUBBRITTLE; IRREGULAR TO SUBBLOCKY FRACTURE; WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; INTERBEDDED WITHIN WELL INDURATED SHALE, RARE CLAYSTONE; LOCALLY INFUSED WITH LOWER VERY FINE SAND; MODERATE TRACE PYRITE AGGREGATE; RARE TRACE SIDERITE IN GENERAL SAMPLE; NO SAMPLE FLUORESCENCE; NO DISCERNIBLE CUT OVER SOLTEX. 7895' SHALE = MEDIUM LIGHT GRAY TO LIGHT BROWNISH GRAY TO BROWNISH GRAY; MODERATELY FIRM TO SLIGHTLY HARD; CRUMBLY TO BRITTLE; PLANAR EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 TO BLOCKY FRACTURE; PLATY TO SUBTABULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; LOCALLY MICROMICACEOUS; SUBFISSILE; GRADING TO SILTSTONE IN PART; NON-CALCAREOUS; LOCALLY SLIGHTLY CARBONACEOUS. 7940' CLAYSTONE = LIGHT BROWNISH GRAY TO MEDIUM LIGHT GRAY; SLIGHTLY FIRM TO SOFT, OCCASIONALLY MODERATELY FIRM; MODERATE TO HIGH COHESION; MODERATE ADHESION; PASTY TO MUSHY; FIRMER CUTTINGS CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT, OCCASIONALLY MASS; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; SLIGHTLY TO NON CALCAREOUS. 7985' SILTSTONE = PALE BROWN TO LIGHT BROWNISH GRAY TO BROWNISH GRAY; MODERATELY FIRM TO VERY FIRM, OCCASIONALLY SOFT; CRUMBLY TO SUBBRITTLE; IRREGULAR TO SUBBLOCKY FRACTURE; WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TEXTURE, OCCASIONALLY GRITTY WHERE LOCALLY INFUSED WITH LOWER VERY FINE SAND; SLIGHTLY TRACE PYRITE AGGREGATE; NO SAMPLE FLUORESCENCE NO DISCERNIBLE CUT OVER SOLTEX CONTAMINATION. 8040' CLAYSTONE = LIGHT BROWNISH GRAY TO MEDIUM LIGHT GRAY; SLIGHTLY FIRM TO SOFT, OCCASIONALLY MODERATELY FIRM; MODERATE TO HIGH COHESION; MODERATE ADHESION; PASTY TO MUSHY; FIRMER CUTTINGS CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT, OCCASIONALLY MASS; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; SLIGHTLY TO NON CALCAREOUS. 8085' TUFF = WHITE TO VERY LIGHT GRAY TO YELLOWISH GRAY; SOFT TO SLIGHTLY FIRM, OCCASIONALLY MODERATELY FIRM; CRUMBLY; SUBBLOCKY FRACTURE; SUBTABULAR CUTTINGS HABIT; WAXY TO DULL LUSTER; SMOOTH TEXTURE; THIN INTERBEDDED WITH CLAYSTONE AND SlLTSTONE; FINELY BANDED IN PART. 8120' SHALE = MEDIUM LIGHT GRAY TO LIGHT BROWNISH GRAY, OCCASIONALLY MEDIUM GRAY; MODERATELY FIRM TO SLIGHTLY HARD; CRUMBLY TO BRITTLE; PLANAR TO BLOCKY FRACTURE; PLATY TO SUBTABULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; MICROMICACEOUS; INTERBEDDED WITHIN SILTSTONE AND CLAYSTONE, RARE TUFF NON-CALCAREOUS; OCCASIONALLY SLIGHTLY CARBONACEOUS. EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 8165' TUFFACEOUS SANDSTONE/SILTSTONE = YELLOWISH GRAY TO VERY LIGHT GRAY TO LIGHT GRAY WITH BRILLIANT TO MODERATE GREEN GRAINSOF GLAUCONITE DISSEMINATED FINELY; EASILY HYDRATED; INCORPORATES VERY FINE GRAINED SANDSTONE AND SILTSTONE GRAINS; DOMINANTLYSOFT AND MUSHY WITH RARE FIRM TO CRUNCHY PARTICLES; NON- REACTIVE WITH DILUTE HCl; NO SAMPLE FLUORESCENCE OVER SOLTEX CONTAMINATION. 8215' SILTSTONE = PALE BROWN TO LIGHT BROWNISH GRAY TO BROWNISH GRAY; MODERATELY FIRM TO VERY FIRM, OCCASIONALLY SOFT; CRUMBLY TO SUBBRITTLE; IRREGULAR TO SUBBLOCKY FRACTURE; WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TEXTURE, OCCASIONALLY GRITTY WHERE LOCALLY INFUSED WITH LOWER VERY FINE SAND; SLIGHTLY TRACE PYRITE AGGREGATE; NO SAMPLE FLUORESCENCE NO DISCERNIBLE CUT OVER SOLTEX CONTAMINATION; SILTSTONE PROXIMAL TO LOWER VERY FINE GRAINED SANDSTONE GRAIN SIZE BOUNDARY. NOTE: SEE PHILLIPS GEOLOGIST CORE DESCRIPTION FOR LITHOLOGY OVER CORED INTERVAL. 8410' SANDSTONE = LIGHT BROWNISH GRAY TO LIGHT OLIVE GRAY; VERY FINE UPPER TO VERY FINE LOWER, OCCASIONALLY FINE LOWER; FIRM FRIABLE TO FRIABLE; WELL SORTED; SBANG TO SBRND; HIGH TO MODERATELYSPHEROIDAL SPHERICITY; GRAIN SUPPORT WITH SLIGHTLY TO MODERATELY SILICEOUS CEMENT; 95+% QUARTZ 5% OR LESS FINE UPPER TO MED LOWER GRAINED GLAUCONITE DECREASING WITH DEPTH; FAIR VISUAL ESTIMATED POROSITY; BRIGHT PALE YELLOW SAMPLE FLUORESCENCE WITH MODERATELY BRIGHT PALE YELLOW VERY SLOW STREAMING CUT. 8470' SILTSTONE = MED DARK GRAY TO OLIVE GRAY; MODERATELY FIRM TO VERY FIRM; CRUMBLY TO SUB-BRITTLE; IRREGULAR TO BLOCKY FRACTURE; WEDGELIKE TO TABULAR CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; THICK BEDDED WITH LOCAL SANDINESS; NONE TO RARE VERY FAINT DULL YELLOW SAMPLE FLUORESCENCE WITH NO DISCERNIBLE CUT. 8515' SHALE = MED DARK GRAY TO DARK GRAY; HARD TO VERY FIRM; BRITTLE TO SUBBRITTLE; PLANAR TO CONCHOIDAL FRAC, OCCASIONALLYSPLINTERY PLATY TO ELONGATED FLAKY CUTTINGS HABIT; DULL LUSTER; SMOOTH TO CLAYEY TEXTURE; SUBFISSILE, OCCASIONALLY FISSILE; THIN INTERBEDDED WITH SlLTSTONE; NON CALCAREOUS. EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 8555' TUFFACEOUS SILTSTONE = YELLOWISH GRAY TO LIGHT BROWNISH GRAY; VERY SOFT TO SOFT, OCCASIONALLY SLIGHTLY FIRM; MODERATELY COHESIVE; LOW ADHESION; MUSHY TO PASTY CONSISTENCY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; WAXY LUSTER; SILTY TEXTURE; THIN BEDDED. 8590' SILTSTONE = MEDIUM DARK GRAY TO OLIVE GRAY; MODERATELY FIRM TO VERY FIRM; CRUMBLY TO SUB-BRITTLE; IRREGULAR TO BLOCKY FRACTURE; WEDGELIKE TO TABULAR CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; THICK BEDDED WITH LOCAL SANDINESS; NO SAMPLE FLUORESCENCE; NO CUT. EPOCH ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 SURVEY RECORD Measured TVD Inclination Azimuth Coordinates Dog Leg Depth Feet Feet Decjrees Degrees E(+) W(-) N(+) S(-) Degrees/30' 0,00 0,00 0,00 0,00 0,00 0,00 Tie-in 108,00 108,00 0.00 0.00 0,00 0,00 0,00 355.56 355,56 0,53 89,32 1,13 0,01 0,21 530.19 530.18 0,48 98.93 2,66 -0.09 0,05 720,01 719,99 0,43 71,36 4,12 0,01 0,12 905,38 905.36 0,34 66,18 5,28 0,45 0,05 1368,08 1368,05 0,43 305,91 5,10 2,02 0,14 1840,75 1840,70 0,78 305,21 1,02 4.93 0,07 2306.43 2306,35 0,48 255,93 -3,48 6,29 0,13 2607,43 2607,34 0,50 272,20. -6,02 6.03 0.05 2759,15 2759,05 0.50 296,40 -7,27 6,35 0,14 2852,37 2852.27 0,50 291,25 -8,01 6,67 0.05 3321.00 3320.88 0.72 283.49 -12.76 8.09 0,05 3792,84 3792.70 1,00 119,37 -12,04 6.76 0,36 4265,94 4265,73 0,87 104,22 -4,95 3,85 0,06 4733,74 4733,51 0,17 32,10 -1,13 3,58 0,18 5199,48 5199.25 0,12 126,32 -0,35 3,88 0,05 5670,83 5670,60 0,06 33.46 0,20 3,79 0,03 6140,89 6140,66 .12 180,28 0,34 3,50 0,04 6610,75 6610.51 - 0,61 62,26 2,54 4,16 0,14 7081,14 7080,59 3,27 56,87 16,01 12,66 0.57 7551,65 7550.55 2,24 51,86 34,50 25,69 0,22 8017,67 8016.33 1,44 34,09 44,95 36,16 0,21 8485,54 8484,08 1,10 21,47 49,89 45,21 0,09 8557.88 8556,41 1.09 19,48 50,37 46,50 0,06 EPOCH PHILLIPS ALASKA, INC. RENDEZVOUS #2 MUD RECORD Date ~)epth Den. Vis PV YP Gels APl Fil. Cake Solids Oil/water Sand pH Cl Ca 04/08/01 600 10.8 70 23 35 10/22 3.8 2/0 12.1 0.5/86.0 0.5 8.8 26000 100 04/09/01 2005 10.0' 62 17 31 11/22 5.0 2/0 8.4 0.5/90.0 0.5 8.4 20000 300 04/10/01 2680 10.0' 60 16 31 12/25 5.6 2/0 7.2 1.5/90.0 0.4 9.5 23500 400 04/11/01 2680 9.7 43 10 10 3/8 9.0 2/0 5.6 1.0/92.0 0.1 8.0 26000 240 04/12/01 3405 9.5 47 10 19 6/14 6.0 2/0 5.1 1.5/92.0 0.1 10.0 26000 100 04/13/01 4819 9.8 44 10 17 5/14 6.0 2/0 6.6 1.0/93.0 0.1 10.0 25500 100 04/14/01 6600 10.6 47 15 17 5/22 4.9 2/2 9.6 2.0,/,87.0 0.2 9.0 27000 160 04/15/01 7266 11.2 45 18 19 5/22 5.0 2/3 11.7 2.0~87.0 0.2 8.9 26000 160 04/16/01 8310 11.2 49 23 17 5/22 3.0 1/2 10.3 2.0~86.0 0.2 9.1 32000 160 04/17/01 8310 11.0 58 32 20 4/20 3.8 2/3 10.1 2.0/86.3 0.25 9. t 30500 208 04/18/01 8369 11.0 58 17 12 2/11 4.6 2/3 10.9 1.5/86.0 0.5 8.2 31000 240 04)19/01 8650 '11.0 52 17 11 2/15 4.4 2/3 10.9 t.5/86.0 0.2 9.1 30000 172 d , [:1 EPOr'H PHILLIPS ALASKA, INC. RENDEZVOUS #2 BIT RECORD Bit Grading I O D L B G O R N U U O E A T E N T L C A U H A E E L A R G E S R R T I E R O C I N N R R H O G C O O A N $ H P W W R A U S S R L L E D Bit Size Make Type SIN Jets Depth Depth DrilleDDd Hours Ave Ave Ave Ave Out Ft/Hr WOB rpm psi 1 12.25 HTC MXC1 D50JM 1x12,3x24 170 2680 2510 32.5 2 8.50 HYC DS70FINE 200346 6x12 2680 4819 2139 14.9 2R1 8.50 HYC DS70FINE 200346 3x13,3x14 4819 6600 1781 17.9 2R2 8.50 HYC Ds70FINE 200346 3x13,3x14 6600 8309 1709 N/A 3 8.5 HC ARC425 4508263 1.000 8309 8369 60 1.5 2R3 8.5 HYCA DS70FINEPV 200346 3x13/3/14 8369 8650 281 N/A ~PHILLIPS ALASKA, INC. RENDEZVOUS #2 DAILY ACTIVITY SUMMARY April 9, 2001 Pick up drill pipe and BHA, drill to 300'. Pull out of hole, pick up Sperry tools. Run into hole. Resume drilling. April 10, 2001 Drill to 1600'. Short trip. Run into hole. Drill ahead. April 11, 2001 Drill 2192-2680'. Drill ahead, to 1600'. Short trip. Run into hole. Resume drilling ahead to 1680' Circulate high viscosity sweep (20 bbls). Short trip to 1567'. Circulate bottoms up. 40 bbl high viscosity sweep. Continue circulate and condition for 9 5/8" hole. Pull out of hole from 2680'. Download MWD. Run casing. April 12, 2001 Run 9 5/8" casing to 2672' Circulate and condition mud. Cement. Bumped plug to 2000 psi. Check float equipment. Install wellhead equipment. TESTIMATED BOPE 250/2500 (10 minutes each). April 13, 2001 Remove BOP. TESTIMATED plug. Pick up BHA; adjust motor bit, STAB etc. Trip in, pick up singles. Tag @ 2585'. Drill cement. Drill ahead. April 14, 2001 Trip in to 2650'. Pulse test MWD. Trip in to 4729'. Wash last stand to bottom. Drill 4819 - 6600'MD. Pull out of hole to repair MWD/LWD. April 15, 2001 Tripped in to 2650'. Pulse test MWD. RIH. Drill 4819- 6601'md. POOH, Repair MWD/LWD. RIH. April 16, 2001 Drill to 8278'. Lose returns. Circulate bottoms up. Drill to 8309'. Wash/ream 8292-8309' (lost 70 bbls total). Circulate. Pooh to 6890'. Pump dry job, blow down top drive. Pull out of hole. April 17, 200t. Coring from 8309-8369'. Pull out of hole to 8260'. Spot 25 bbl LCM pill. Pooh to 7400'. April 18, 2001. Continue out of hole with core barrel. Recover core. Change BHA. Run into hole. EPOCH Phillips Alaska, Inc. Exploration Rendezvous #2 REPORT FOR Ken Helmold DATE Apr 09, 2001 TIME 03:27:23 CASING INFORMATION SURVEY DATA BIT INFORMATION NO. SIZE TYPE I 12 1/4" HTC mxcl DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10.8 VIS FC 2/0 SOL MWD SUMMARY INTERVAL TO TOOLS 7O 12.1 DAILY WELLSITE REPORT DEPTH 787 YESTERDAY 201 24 Hour Footage 586 DEPTH INCLINATION AZIMUTH ii INTERVAL S/N JETS IN OUT FOOTAGE HOURS D50JM 1X12/3X24 150 640.2 5.77 EPOCH HIGH LOW AVERAGE 282.1 @ 726 19.1 @ 217 139.6 4572 @ 716 12 @ 216 2998.1 13 @ 415 1 @ 313 6.3 82 @ 697 -29 @ 216 67.1 1660 @ 705 69 @ 216 1059.8 DEPTH: PV 23 YP 35 FL Gels 10/22 SD .5 OIL .5186.0 MBL 8.0 pH 8.8 GAS SUMMARY(units) HIGH DITCH GAS 41 @ CU'I-rlNG GAS 0 @ METHANE(C-I) 4094 ETHANE(C-2) 0 PROPANE(C-3) 0 BUTANE(C-4) 0 PENTANE(C.5) 0 HYDROCARBON SHOWS LOW AVERAGE 724 7 @ 787 12.6 787 0 @ 787 0.0 CHROMATOGRAPHY(ppm) 724 21 @ 787 645.0 787 0 @ 787 0.0 787 0 @ 787 0.0 787 0 @ 787 0.0 787 0 @ 787 0.0 i ,, PRESENT OPERATION= Drill Ahead INTERVAL LITHOLOGY/REMARKS I_'ITHOLOGY sand, sandstone, volcanic tuff, c~lcite, chert, clay, claystone, silt~tone PRESENT LITHOLOGY volcanic tuff, sandstone, sand, clay, siltstone DAILY ACTIVITY SUMMARY Pick up drill pipe and BHA, drill to 300', pull out, pick up tools, RIH, resume drilling. VERTICAL DEPTH CONDITION REASON T/B/C PULLED CURRENT AVG 55.7 ft/hr 2968.9 amps 6.9 Klbs 82 RPM 1587 psi CL- 26000 Ca+ 100 CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 16.5 GAS DESCRIPTION Epoch Personel On Board= 4 Daily Cost $2420.00 Report by: Bob Nichol PHILLIPS ALASKA EXPLORATION Rendezvous #2 REPORT FOR Dead Gladden, Danny Symonton DATE Apr 10, 2001 TIME 04:00 CASING INFORMATION SURVEY DATA DEPTH DAILY WELLSITE REPORT EPOCH DEPTH 2425 YESTERDAY 787 24 Hour Footage 1638 PRESENT OPERATION= DRILL AHEAD iNCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE S/N 1 12.25 MXC1 D50JM INTERVAL JETS IN OUT FOOTAGE 1'12/3'24 150 2322 HOURS 20.99 CONDITION REASON T/B/C PULLED DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10.0 FC 210 MVVD SUMMARY INTERVAL TO TOOLS ViS 62 PV SOL 8.4 SD GAS SUMMARY(units) HIGH DITCH GAS 182 CU'FI'ING GAS 0 @ METHANE(C-I) 33402 ETHANE(C-2) 148 PROPANE(C-3) 21 BUTANE(C-4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL HIGH LOW 832.1 @ 1024 2.5 @ 1629 99999 @ 998 275 @ 1442 23 @ 1387 0 @ 2380 999 @ 998 -7 @ 1067 9999 @ 998 579 @ 1629 DEPTH: 17 YP 31 FL .5 OIL 0.5/90.0 MBL LOW AVERAGE 1963 7 @ 787 72.8 2425 0 @ 2425 0.0 CHROMATOGRAPHY(ppm) 1963 21 @ 787 12140.8 2421 1 @ 2097 6.3 2423 1 @ 2409 0,3 2425 0 @ 2425 0,0 2425 0 @ 2425 0.0 LITHOLOGY/REMARKS iii LITHOLOGY SAND, SANDSTONE, CLAYSTONE, TUFF, SILTSTONE PRESENT LITHOLOGY SILTSTONE, CLAYSTONE, TUFF DAILY ACTIVITY SUMMARY Drill to 1600'. Short trip, RIH. Drill ahead to depth AVERAGE 134.4 3659.2 10.8 75.8 1649.2 Gels 12,5 pH GAS CURRENT AVG 140.9 fi/hr 4728.2 amps 16.8 KIbs 75 RPM 1887 psi 11/22 CL- 20000 8.4 Ca+ 300 CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 36.8 DESCRIPTION Epoch Personel On Board= 4 Daily Cost 2420 Report by: Bob Nichol ~any ~epon - -e, ..... PHILLIPS ALASKA EXPLORATION RENDEZVOUS #2 REPORT FOR DATE Apr 10, 2001 TIME 04:00:23 CASING INFORMATION SURVEY DATA DAILY WELLSITE REPORT EPOCH DEPTH 2680 YESTERDAY 2425 24 Hour Footage 255 PRESENT OPERATION= SET CASING, CEMENT DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE S/N INTERVAL CONDITION JETS IN OUT FOOTAGE HOURS T/B/C REASON PULLED DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10.0 VIS FC 2/0 SOL MVVD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) 60 7.2 HIGH LOW AVERAGE CURRENT AVG 200.9 @ 2595 17.7 @ 2553 97.5 67.6 ftJhr 8271 @ 2600 1018 @ 2473 4375.4 .3392.9 amps 27 @ 2473 0 @ 2611 11.6 16.9 Klbs 80 @ 2474 3 @ 2473 75.9 72 RPM 2001 @ 2605 867 @ 2473 1824.5 1799 psi DEPTH: PV 16 YP 31 FL Gels 12/25 CL- 23500 SD ,4 OIL 1,5/90,0 MBL 15,0 pH 9.5 Ca+ 400 CCI HIGH LOW AVERAGE 118 @ 2425 13 @ 2673 49.5 TRIP GAS= 0 @ 2680 0 @ 2680 0,0 WIPER GAS= 270 CHROMATOGRAPHY(ppm) SURVEY= 21400 @ 2425 1044 @ 2458 8765.1 CONNECTION GAS HIGH= 29 122 @ 2425 5 @ 2458 44.0 AVG= 27 20 @ 2425 1 @ 2487 8.4 CURRENT 0 @ 2680 0 @ 2680 0.0 CURRENT BACKGROUND/AVG 0 @ 2680 0 @ 2680 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND, SANDSTONE, CLAYSTONE, SILTSTONE, VOLCANIC TUFF, PRESENT LITHOLOGY CLAYSTONE, SILTSTONE, VOLCANIC TUFF , DAILY ACTIVITY SUMMARY Drill 2192-2680'. Circ hi-vis sweep (20bbls). Short trip to 1567'. Circ btms up, Sweep, condition. POOH Download MWD, Run casing. Epoch Personel On Board= 4 Daily Cost 2420 Report by: Bob Nichol file ://C :\WINDOWS\Desktop\20010411 .htm 5/24/01 PHILLIPS ALASKA EXPLORATION RENDEZVOUS ~2 REPORT FOR Ralph Bowie, Ray Skinner DATE Apr 12, 2001 TiME 04:00:23 CASING INFORMATION SURVEY DATA DAILY WELLSITE REPORT EPOCH DEPTH 2680 YESTERDAY 2680 24 Hour Footage 0 DEPTH INCLINATION PRESENT OPERATION= Test BOPE, Stand up pipe AZIMUTH VERTICAL DEPTH 43 PV 5.6 SD BIT INFORMATION NO. SIZE TYPE 2 8.5 DS70FNPV DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.7 VIS FC 2/0 SOL MVVD SUMMARY INTERVAL TO TOOLS SIN 200346 INTERVAL JETS IN OUT FOOTAGE HOURS 6X12 HIGH LOW AVERAGE @ 2680 @ 2680 @ 2680 @ 2680 @ 2680 @ 2680 @ 2680 ~ 2680 @ 2680 @ 2680 DEPTH: 10 YP 10 FL Gels .1 OIL 1.0/92.0 MBL 10.0 pH GAS SUMMARY(units) HIGH LOW DITCH GAS @ 2680 @ 2680 CUTTING GAS 0 @ 2680 0 @ 2680 CHROMATOGRAPHY(ppm) METHANE(C-I) @ 2680 5143 @ 2680 ETHANE(C-2) @ 2680 31 @ 2680 PROPANE(C-3) 8 @ 2680 8 @ 2680 BUTANE(C-4) 0 @ 2680 0 @ 2680 PENTANE(C-5) 0 @ 2680 0 @ 2680 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS AVERAGE CONDITION T/B/C REASON PULLED CURRENT AVG 3/8 CL- 8.0 Ca+ 260OO 24O fi/hr amps Klbs RPM psi CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG GAS DESCRIPTION LITHOLOGy SILTSTONE, SANDSTONE, CLAYSTONE, SAND, LIMESTONE, VOLCANIC TUFF PRESENT LITHOLOGY DAILY ACTIVI'Pf suM~RY Run 0-5/8 easing to 2672'. Clrc and condx mud. Cement. Bumped plug to 2000 psi. Chk float. Install welll~ead eqpt. Test BOPE. Epoch Personel On Board= 4 Daily Cost 2420 Report by: Bob Nichol PHILLIPS ALASKA EXPLORATION RENDEZVOUS #2 REPORT FOR Ralph Bowie, Ray Skinner DATE Apr 15, 2001 TIME 04:00:00 DAILY WELLSITE REPORT EPOCH DEPTH 6601 YESTERDAY 4819 PRESENT OPERATION= POOH, Repair MWD CASING INFORMATION SURVEY DATA 24 Hour Footage 1782 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE 2R1 8.5 DS70FNPV DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10,6 VIS FC 2/2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS 47 PV 9.6 SD METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL 6315 - 6382 LITHoLOGY 200346 INTERVAL JETS IN OUT FOOTAGE 3X13/3/14 150 3921.29 HIGH LOW 276.1 @ 5011 11.9 @ 5025 6702 @ 6420 -33 @ 4819 29 @ 5945 0 @ 6597 100 ~ 4942 -32 @ 4819 9999 (~ 5186 -606 (~ 5297 DEPTH: 15 YP 17 FL .2 OIL 2.0/87.0 MBL HOURS 32.78 AVERAGE 139.7 4479.8 5.4 60.4 2829.4 CONDITION T/B/C CURRENT AVG Gels 5/22 CL- 27000 10.0 pH 9.0 Ca+ 160 REASON PULLED fi/hr amps Klbs RPM psi CCI HIGH LOW AVERAGE 919 @ 5656 4 @ 4821 151.4 0 @ 6601 0 @ 6601 0.0 CHROMATOGRAPHY(ppm) 218986 @ 6410 679 @ 4821 28820.2 22626 @ 6410 43 @ 4821 3074.4 8114 @ 6410 10 @ 4821 1238.4 2849 @ 6411 1 @ 4935 492.0 1681 @ 6410 I @ 5192 225.7 WK- MOD SHOVVING , 6315-6382', 6397.6450 LITHOLOGY/REMARKS GAS DESCRIPTION TRIP GAS= VVIPER GAS= SURVEY= CONNECTION GAS HIGH= 119 AVG= 103.4 CURRENT N/A CURRENT BACKGROUND/AVG SANDSTONE, SILTSTONE, 109- OIL SIGN ON SHAKER TABLE NOTED. TAR BLEBS DISSEM WITHIN SDST, FAIR-GOOD CLAYSTONE 882u POROSITY, CLAST-SUPTD, LFN TO UPR FN SDST DOMINATES SECTION SANDSTONE, SILTSTONE, CLAYSTONE, VOLCANIC TUFF PRESENT LITHOLOGY SANDSTONE, SILTSTONE, CLAYSTONE DAILY ACTIVITY SUMMARY Trip int ro 2650'. Puse tes MWD, RIH. Dril14819-~601'md., POOH, Repair MWD/L~. Epoch Personel On Board= 4 Daily Cost 2420 Report by: Bob Nichol PHILLIPS ALASKA EXPLORATION RENDEZVOUS ~Y2 REPORT FOR Ralph Bowie, Ray Skinner DATE Apr 16, 2001 TIME 04:01:29 CASING INFORMATION DEPTH SURVEY DATA BIT INFORMATION NO. SIZE TYPE S/N 2R1 8.5 DS70FNPV 200346 DALLY WELLSITE REPORT DEPTH 7489 YESTERDAY 6601 24 Hour Footage 888 EPOCH PRESENT OPERATION= DRILL AHEAD INCLINATION AZIMUTH VERTICAL DEPTH INTERVAL CONDITION REASON JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3X13/3X14 150 4894 44.18 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 11.2 VIS FC 2/3 SOL MVVD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL 6855 - 6955 LITHOLOGY HIGH LOW AVERAGE 251.1 @ 6888 9.9 @ 7198 113.7 7272 (~ 6890 16 ~ 7177 4528.9 41 @ 7454 0 @ 7216 6.3 89 @ 7361 -32 (~ 7233 72.2 500 @ 6601 500 @ 7489 500.6 DEPTH: 45 PV 18 YP 19 FL Gels 5/22 CL- 26000 11.7 SD .2 OIL 2.0/87.0 MBL 10.0 pH 8.9 Ca+ 160 CURRENT AVG 60.3 fi/hr 2583.2 amps 3.7 Klbs 73 RPM 500 psi CCI HIGH LOW AVERAGE 553 @ 6900 27 @ 7213 195.5 TRIP GAS= 0 @ 7489 0 @ 7489 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 98160 @ 6900 4052 @ 7213 32771.9 CONNECTION GAS HIGH= 85 11600 @ 6900 406 @ 7213 3494.6 AVG= 53.8 5160 @ 6900 225 @ 7213 1549.0 CURRENT 72 1802 @ 7117 121 @ 7213 612.7 CURRENT BACKGROUND/AVG 82 693 @ 6982 60 @ 7436 248.1 WEAK-MOD GAS SHOWINGS RELATED TO SANDSTONE INTERVALS MTHOLOGYIREMARKS GAS DESCRIPTION SANDSTONE, SILTSTONE, 96.75 - SUSTAINED HIGH GAS THRU A SECTION OF L FGD TO FGD SANDSTONE MUDSTONE, SHALE 553.27 BEDS WITHIN SILTSTONE AND SHALE HOST SANDSTONE, SHALE, SILTSTONE, MUDSTONE, VOLCANIC TUFF PRESENT LITHOLOGY SHALE, SlLTSTONE, VOLCANIC TUFF DALLY ACTIVITY Ciculate, pump slug. Tdp out to BHA, download MWD. Trip in to 3500, pulse test MWD. Trip in to 6400, wash and ream to 6600'. SUMMARY Ddll ahead. Epoch Personel On Board= 4 Daily Cost 2420 Report by: Bob Nichol PHILLIPS ALASKA EXPLORATION RENDEZVOUS ~ REPORT FOR Ralph Bowie, Ray Skinner DATE Apdl 18, 2001 TIME 04:00:00 CASING INFORMATION SURVEY DATA BIT INFORMATION NO. SIZE TYPE 3 8.5 ARC425 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 11.2 ~S FC 1/2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS ~N 4508263 DEPTH 49 PV 10.3 SD HIGH o @ o @ METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL DAILY WELLSITE REPORT DEPTH 8369 YESTERDAY 8307 24 Hour Footage 62 46.4 5239 26 63 1614 INCLINATION INTERVAL JETS IN 1.000 8309 HIGH @ 8309 @ 8309 @ 8308 @ 8312 @ 8312 DEPTH: 23 YP .2 OIL OUT FOOTAGE 60 AZIMUTH LOW 19.4 1394 @ 4 @ -2 @ 5oo @ 8311 8307 8312 8307 8309 EPOCH PRESENT OPERATION= CIRCULATE HOURS 2.9 AVERAGE 3.0 413.1 1.2 4.2 101.4 VERTICAL DEPTH CONDITION T/B/C CURRENT AVG 17 FL Gels 5/22 CL- 32000 2.0/86.0 MBL 8.0 pH 9.1 Ca+ 180 LOW AVERAGE 8369 0 @ 8369 0.0 8369 0 @ 8369 0.0 CHROMATOGRAPHY(ppm) 8369 0 @ 8369 0.0 8369 0 @ 8369 0.0 8369 0 @ 8369 0.0 8369 0 @ 8369 0.0 8369 0 @ 8369 0.0 LITHOLOGY/REMARKS REASON PULLED LITHOLOGY SANDSTONE, SAND, SHALE, TUFF, SILTSTONE PRESENT LITHOLOGY SAND, SANDSTONE, SHALE DAI'LY ACTIVITY SUMMARY Coring from 8309 - 8369'. Pool~ to 8260', spot 25 bbl LCM pill. POOH to 7400. fi/hr amps Klbs RPM psi CCI TRIP GAS= N/A WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG GAS DESCRIPTION Epoch Personel On Board= 4 Daily Cost 2420 Report by: Bob Nichol PHILLIPS ALASKA EXPLORATION RENDEZVOUS ~2 REPORT FOR Ralph Bowie, Ray Skinner DATE Apr 19, 2001 TIME 05:45:27 CASING INFORMATION SURVEY DATA DAILY WELLSITE REPORT EPOCH DEPTH 8369 YESTERDAY 8369 24 Hour Footage 0 PRESENT OPERATION= RUN INTO HOLE DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE 2R3 8.5 DS70FNPV INTERVAL S/N JETS IN OUT 200346 3X13/3X14 8369 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 11.0 VIS FC 2/3 SOL MVVD SUMMARY INTERVAL TO TOOLS HIGH LOW 10.2 @ 8369 10.2 5420 @ 8369 5420 5 @ 8369 5 63 @ 8369 63 1816 @ 8369 1816 DEPTH: 58 PV 17 YP 12 10.9 SD .5 OIL 1.5/86.0 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0 (~ 8369 0 @ 8369 -1.$ CU'I-I'ING GAS 0 (~ 8369 0 @ 8369 -1.$ CHROMATOGRAPHY(ppm) METHANE(C-I) 0 (~ 8369 0 @ 8369 -1.$ ETHANE(C-2) 0 @ 8369 0 @ 8369 -1.$ PROPANE(C-3) 0 (~ 8369 0 (~ 8369 -1.$ BUTANE(C-4) 0 ~ 8369 0 @ 8369 -1.$ PENTANE(C-5) 0 (~ 8369 0 (~ 8369 -1.$ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS FOOTAGE 0 CONDITION REASON HOURS T/B/C PULLED AVERAGE CURRENTAVG 8369 1.$ 10.2 fi/hr 8369 1.$ 5420.1 amps 8369 1.$ 5.3 ~bs 8369 1.$ 63 RPM 8369 1.$ 1816 psi FL Gels 2/11 CL- 31000 MBL 8.0 pH 8.2 Ca+ 240 CCI TRIP GAS= 300 WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUNDIAVG GAS DESCRIPTION LITHOLOGY SAND, SANDSTONE, SILTSTONE, SHALE, TUFF PRESENT LITHOLOGY SAND, SANDSTONE, SHALE, TUFF : DAILY ACTIVITY SUMMARY CONTINUE OUT OF HOLE WITH CORE BARREL. RECOVER CORE. CHANGE BHA, RUN INTO HOLE Epoch Personel On Board= 4 Daily Cost 2420 Report by: Bob Nichol PHILLIPS ALASKA EXPLORATION RENDEZVOUS ~2 REPORT FOR Ralph Bowie, Ray Skinner DATE Apdl 20, 2001 TIME 04:00:00 CASING INFORMATION DALLY WELLSITE REPORT EPOCH DEPTH 8651 YESTERDAY 8369 24 Hour Footage 282 PRESENT OPERATION= Prepare for cementing SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE 3 8.5 HYCA DS70FNPV 200346 8369 282.5 DRILLING PARAMETERS HIGH LOW RATE OF PENETRATION 144.9 @ 8492 10.2 @ 8369 SURFACE TORQUE 7537 @ 8392 2416 @ 8385 WEIGHT ON BIT 12 @ 8491 3 @ 8385 ROTARY RPM 81 (~ 8439 31 @ 8392 PUMP PRESSURE 2830 @ 8396 1816 @ 8369 DRILLING MUD REPORT DEPTH: MW 11.0 VIS 52 PV 17 YP 11 FL FC 2/3 SOL 10.9 SD .2 OIL 1.5/86.0 MBL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 334 (~ 8384 21 @ 8482 53.6 CU'I-I'ING GAS 0 @ 8651 0 @ 8651 0.0 CHROMATOGRAPHY(ppm) METHANE(C-I) 41774 @ 8384 1975 @ 8477 6286.2 ETHANE(C-2) 6850 @ 8384 372 @ 8477 1070.4 PROPANE(C-3) 3099 @ 8384 214 @ 8482 585.8 BUTANE(C-4) 952 @ 8384 92 (~ 8482 231.5 PENTANE(C-5) 377 @ 8384 51 @ 8482 128.4 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY SILTSTONE, TUFFACEOUS CLAYSTONE, SHALE PRESENT LITHOLOGY SILTSTONE, TUFFACEOUS CLAYSTONE, SHALE DAILY ACTIVITY SUMMARY HOURS 7.45 AVERAGE 62.7 4633.8 6.4 79.2 2572.2 CONDITION T/B/C CURRENTAVG Gels 2/15 CL- 30000 5.0 pH 9.1 Ca+ 172 REASON PULLED ft/hr amps Kdbs RPM psi CCI TRIP GAS= 485 WIPER GAS= 673 SURVEY= CONNECTION GAS HIGH-- 353 AVG= 173.3 CURRENT CURRENT BACKGROUND/AVG GAS DESCRIPTION RIH to 8000'. Bk circulation, lost 38bbls. Pooh to 7920'. Wash/ream f/7920-8309'. Drill 8369-8650'. Pump sweep, short trip 8650- 8200'. POOH @ 8650'. Epoch Personel On Board= 4 Daily Cost 2420 Repod by: Bob Nichol ~KA OIL AND GAS CONSERVA~ION COPI~ISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27~7542 Paul Mazzolini Exploration/Cook Inlet Team Leader Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Rendezvous #2 Exploratory Phillips Alaska, Inc. Permit No: 201-007 Sur. Loc. 1707'FNL, 2523'FWL, Sec. 6, TgN, R2E, UM Btmhole Loc. 1633'FNL, 2523' FWL, Sec. 6, T9N, R2E, UM Dear Mr. Mazzolini: Enclosed is the approved applicatiOn for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission' s internal USC. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that 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, subsequent LOT data following setting production casing, and any CQLs must be submitted to the Commission on form 10-403 prior to the approval of disposal operations. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are f'n'st caught and 10' sample intervals through target zones. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (Rendezvous #2 PH) and API number (50-103-20363-70) from records, data and logs acquired for well Rendezvous #2 (API number 50-103-20363-00). In your application, it is indicated that it may be necessary to stimulate the productive intervals in the well. If stimulation is determined necessary, a Sundry Application (Form 403) detailing the planned stimulation(s) should be submitted for approval. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the diverter function test and BOPE tests must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. 'Commissioner BY ORDER OF THE COMMISSION DATED this /~_ ~t ~ day of March, 2001 dlf/Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~'r' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work:: Drill ['~ Reddll r"] I lb. Type of well. Exploratory ~] Stratigraphic Test [~ Development Oil r"] Re-entry 0 Deepen OI Service O Development Gas O single Zone ~1 Multiple Zone ~l 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. GL 115 & 35' RKB feet 3. Address 6. Property Designation Exploration P.O. Box 100360 Anchorage, AK 99510-0360 AA-81781 / 5126 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AA¢ 25.0251) 1707' FNL, 2523' FWL, Sec. 6, TDN, R2E, UM Exploration NPRA Statewide At top of productive interval 8. Well number Number 1633' FNL, 2523' FWL, Sec. 6, TDN, R2E, UM Rendezvous #2 #59-52-180 At total depth 9. Approximate spud date Amount 1633' FNL, 2523' FWL, Sec. 6, TDN, R2E, UM January 26, 2001 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1633' @ TD feet N/A, feet 5720 8784' MD / 8780' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth: N/A MD Maximum hole angle N/A° Maximum surface 3003 psig At total depth (TVD) psig 18. Casing program Setting Depth size Specifications Top Bottom Quant~ of Cement Hole Caslnc, I Wei~lht Grade couplin~l Len~h MD TVD MD TVD (include sta~le data) 24" 16" 63# B PEB 80' Surface Surf. 115' 115' 280 sx AS I 12.25" 9.625" 40# L-80 BTC 2967' Surf. Surf. 2835' 2835' 410 sx AS III Lite & 90 sx Class G 8.5" 7" 26# L-80 BTCM 8967' Surf. Surf. 8284' 8280' 190 sx Class G 6.125" 4.5" 12.6# L-80 8rdEUE 650' 8134' 8130' 8784' 8780' 130 sx Class G 19. To be completed for Redrlll, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) tree vertical feet Effective Depth: measured feet Junk (measured) tree vertical feet Casing Length Size cemented Measured depth True Vertical depth Conductor SurfaceRECEIVED Production DEC 1 1 ?Otlr) Perforation depth: measured Naska 0ti & Gas Cons. C°mmiosi°n 0~'~ IGINAL Anchorage tree vertical 20. Attachments Filing fee r~ Property Plat D BOP Sketch [~] Diverter Sketch r~ Drilling program [~] Drilling fluid program ~] Time vs depth plot r~Refraction analysis r"] Seabed report [~ 20 AAC 25.050 requirements [~] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call William L/oyd265-655 Signed ~"~~ ~'~~ Title:orillinaTeamLeac/er Date IZ'/I/~0¢)0 Paul Mazzo/in/ Pret)ared bv Sharon AIIsuD-Dral(~ Commission Use Onl) Permit Number .,7..Z~/,_.~j~,,~,-~ I APl number I Approval date ISee cover letter ~,~.~3 "~.~'"~ J.--'/~ ~ / I/or other requirements so-/O~" "'" .... ~ "' ' '"'"' Conditions of approval Samples required [~1 Yes O No Mud log required r~ Yes F~ No Hydrogen sulfide measures r'~ Yes D No Directional survey required [] Yes D No O2M; O 3M; ~~ D 10M:O O Required working pressu re for DOPE Other: 'J*"IGIIV/~J- ~;~(3~'q[2[) ~3 ¥' by order of D Taylor Searr~ount Approved by , Comm,ss,oner the corem,ss,on Date / Form 10-401 Rev. 12/1/85 · Submit in triplicate Phillips Alaska, Inc. i' Drill and Case Plan for Rendezvous #2 General Procedure: 1. MIRU Nabors 19e over pre-installed 16" conductor casing. Weld landing ring on conductor. 2. Install diverter & function test same. 3. Spud well and drill 12 1/4" hole to the surface casing point at 2835' MD/2835' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. · Employ lightweight permafrost cement lead slurry and Dowell LiteCrete high compressive, lightweight tail slurry to assure cement returns to the surface in a one-stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test 7. Make up 8 1/2" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 8. Drill float equipment and approximately 20' of new hole · Perform LOT (or FIT, if 16 ppg gradient is achieved) · Record results and fax to town 9. Drill 81/2'' pilot hole wellbore to +8780' MD/+8780' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 10. TOOH and LD BHA. RIH and set abandonment plug(s) as required by applicable regulations. If additional geologic evaluation is required (cores), RIH w/OE drill pipe and set sidetrack plug to 6000' MD / 6000' TVD. 11. After setting sidetrack plug, WOC. RTH with 81/2'' drilling assembly and twin well to top of .]4/UCU. Run MWD / LWD logging tools in drill string as required for directional monitoring and to properly identify objective top. 12. Run 7" intermediate string to isolate potentially sensitive shales located just above the objective (est.@ 8284' MD / 8281' TVD). Cement casing to bring cement +800' above 7" shoe. 13. Make up 6 1/8" mill tooth bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 14. Drill float equipment, CCM, displace to coring fluid and TOOH. (LOT is not planned for this casing string - see attached explanation). 15. PU core barrel, RIH and core at least one 60' core. TOOH, LD core barrel and PU 6-1/8" bit and drilling assembly and -FIH. 16. Drill twinned wellbore to +8784' MD / +8780' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 17. 18. 19. · Condition hole and mud for e-line logs. Log 6-1/8" wellbore as necessary. Run and cement 4 1/2" 12.6# L80 EUE Liner Make a cleanout run with bit and scrapers · Displace to filtered seawater · Pressure test well to 3000 psi for 30 minutes RECEIVED DEC I 1 2000 Ai~,sk~ Oil & G~s Cons. Commission Anchorage ,. Phillips Alaska, Inc. "Ii' · Record results and fax to town 20. Run and land 4 1/2" tubing with gas lift completion 2:L. Nipple down BOP's. ]:nstall production tree and pressure test same to 5000 psi. 22. Secure well, release rig. 23. IVl]: well testing equipment and surface test tanks. Perform production tests as required. Produced fluids will be either reinjected into the formation or trucked to Kuparuk or Alpine production facilities. 24. Upon completion of testing or if the well is not completed, plug and abandon the well per applicable regulations. Thoroughly clean location and block off further ice road access to location. Phillips Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Rendezvous #2 Drillinq Fluid Pro Density PV YP Funnel Vis Tnitial Gel 10 Minute Gel APl Filtrate pH % Solids )erties: Spud to surface casing point 9.5 - 10.2 ppg 16 - 26 25 - 35 50- 100 10 - 20 15 - 40 7- 15 9.5 - 10 J= 10% Drill out I Twinned Hole to TD (pilot & I (Intermediate shoe to Intermediate hole)I TD) 9.5- 11.0 ppg 9.1 -9.4 ppg 6 - 20 5 - 20 35 - 50 2-6 14 - 20 < 6 below 7000' 910- 10 < 11% 8- 12 12 - 20 40 - 50 8- 12 12- 16 <10 9.0- 10.0 < 8% Drillinq Fluid System: 2 - Triple Derrick Shale Shakers Derrick 20 cone Desilter/Mud Cleaner Derrick Centrifuqe Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Swaco Degasser Fluid Agitators Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033, Maximum Anticipated Surface Pressure and Casing Design: The following information is used for calculation of the maximum anticipated surface pressures for the planned well' Pore Casing Casing Fracture Pressure Pore Size Setting Depth Gradient Gradient Pressure HASP Drilling 16" 115' MD / 115' TVD 11.0 ppg 11.0 52 NA 9-5/8" 2835' MD / 2835'/VD 14.8 ppg 8.33 1204 53 psi 7" 8284' MD / 8280'/VD 17.6 ppg 8.7 ppg 3740 1870 psi 4-1/2" 8784' MD / 8780'/VD 17.6 ppg 8.7 ppg 3970 3003 psi Expected Maximum Mud Weights: 12-1/4" surface hole to 2835' MD / 2835'/VD: 10.2 ppg 8-1/2" pilot hole to 8780' MD / 8780'/VD: 11.0 ppg (for stabilization of shales) 8-1/2" Intermediate Twinned hole to 8284' MD / 8280'/VD: 11.0 ppg (for shale stabilization) 6-1/8" Production Hole to 8784' MD / 8780'/VD: 9.1 ppg Procedure for Calculating Maximum Anticipated Surface Pressure: HASP 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: Phillips Alaska, Inc. 1) HASP = [(FG x 0.052) - 0.11] x D Where: HASP = Maximum Anticipated Surface Pressure FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion factor from lb/gal to psi/ff 0.11 = Gas Gradient in psi/ftc (above 10,000' TVD) D = True vertical depth to casing seat in ft from RKB OR 2) MASP: FPP- (0.11 x D) Where: FPP = Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 16" Conductor Casing HASP = [(FG x 0.052) - 0.11] x D = [(11.0 x 0.052) - 0.11] x 115 = 53 psi OR MASP = FPP- (0.11x D) = 1204 - (0.11 x 2835) = 892 psi 2. Drilling below 9-5/8" Surface Casing HASP = [(FG x 0.052) - 0.11] x D MASP= [(14,8 x 0.052) - 0.11] x 2835 HASP = 1870 psi OR MASP = FPP- (0.11x D) = 3740 - (0.11 x 8230) = 2834 psi 3. Drilling below 8-1/2" Intermediate Casing MASP= [(FG x 0.052) - 0.11] x D MASP= [(17.6 x 0.052) - 0.11] x 8230 MASP = 6626 psi OR MASP = FPP- (0.11x D) = 3970 - (0.11 x 8780) = 3003 psi Casing Design Performance Properties Internal Tensile Strength Size Weight Grade Connection Yield Collapse 16" 63 ppf B PEB Conductor Casing Joint Body 9-5/8" 40 ppf L-80 BTC 5750 psi 3090 979 M 916 M 7" 26 ppf L-80 BTC-M 7240 psi 5410 667 M 519 M 4-1/2" 12.6 ppf L-80 BTC 8430 psi 7500 psi 304 M 267 M Casing Setting Depth Rational: 16" @ 115' MD RKB 9-5/8" @ 2835' MD RKB 7" @ 8234' MD RKB Well Proximity Risks: None Drillinq Area Risks: Phillips Alaska, Inc. Conductor casing to provide sufficient anchor and fracture gradient for diverter system. Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling pilot hole and twinned wellbore into reservoir. Tntermediate casing is set strictly to provide isolation of potentially troublesome shales. Because the objective interval will be pre-drilled in the pilot hole at a higher mud weight than what is targeted below the 7", a leak off test will not be done below this shoe. The shoe of this casing will be set immediately into the top of the objective with a planned core to be taken immediately below the 7" shoe. A LOT would require 20' of additional hole to be drilled and would jeopardize targeted core recovery. Shallow Hazards: Refer to "Pre-Drill Seismic Pore Pressure Prediction for NPRA Proposed Wells: Hunter 1, Outlook 1, Oxbow 1, Rendezvous 1, Rendezvous 2, Spark 2, Spark 3, Spark 4, Spark 5, Lookout A' dated November 29, 2000, submitted under separate cover. Drilling Risks: Drilling risks in the Rendezvous #2 area are surface interval clays, intermediate interval sloughing shales, and lost circulation/breathing potential through the reservoir. Surface clay problems will be counteracted with fluid chemistry and rheology. Shale stability will be controlled while drilling with fluid chemistry, rheology, hydraulics and fluid density. Lost circulation will be addressed with lost circulation material (LCM) and managed flowrates. Annular Pumpin,_q Operations: [ncidental fluids developed from drilling operations will be hauled to the nearest permitted Class disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The Rendezvous #2 surface/intermediate casing annulus will be filled with diesel after setting intermediate casing and prior to the drilling rig moving off of the well. Tf isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. Geoloav: Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows: FORMATION DEPTH (ss) UNCERTAINTY POSSIBLE FLUID EST. PORE TYPE PRESSURE~ psi Permafrost 760' K3 2785' 200' Oil or Gas 1204 Sequence 97 3355' 200' 1451 Sequence 95 3675' 200' 1589 Sequence 93t 4675' 200' 2022 Base Ponded Turbidites 6135' 200' 2760 Pebble Shale / Dist. Zone 7300' 200' 3285 LCU 7515' 200' Oil or Gas 3381 34/U3U 8130' 200' 3740 Base 34 8380' 200' 3854 TD 8630' 200' 3970 i" Phillips Alaska, Inc. Formation Evaluation.' Anticipated logging, coring and testing for this well is as follows: I. Logging Surface Interval (0 - Surface Casing setting depth) LWD: GE/Res. II. III. IV. 8-1/2" Pilot Hole (Surface Casing setting depth to TD) LWD: GR/Res/FDC-CNL/Dipole Sonic 8-1/2" Twinned Well (Top HRZ- Top ]4/U]U) LWD: GR/Resistivity-at-bit (RAB) 6-1/8" Twinned Well (7" Shoe to TD) LWD: GR/Res Wireline: GR/Res/FDC-CNL/Dipole Sonic/CMR (Contingency: RFT/RSWC) Coring Full Diameter 2.5" Core in Upper ]urassic (1 - 2, 60' cores) Potential Rotary Sidewall Cores (wireline conveyed) in the event full core operations are unsuccessful Mudlogging IVludlogging service should be in operation from the base of the surface conductor casing to TD. Service most likely will include ROP on 5' intervals, lithology, total' gas, sample collection, gas analysis of cuttings, gas chromatography, and H2S detection Sixty-foot (60') wet and dry samples will be collected from surface to 4500' subsea Thirty-foot (30') wet and dry samples will be collected from 4500' subsea to well TD (pilot and twin) and ten-foot (10') wet and dry samples, or continuous, collected across the Kuparuk and Jurassic intervals. Flow Testing Flow testing and pressure build-up tests will be used to determine formation properties and estimate the commerciality of this exploratory well. Flow testing for any particular interval will consist of an initial unstimulated flow period followed by an appropriate pressure build-up. The flow period will be determined on-site in response to analysis of initial flow period, PBU and fluid properties. The well will be flowed to temporary surface production facilities consisting of gas separation and fluid storage tanks. Produced fluids will either be trucked to an existing production facility or reinjected into the formation following completion of the flow testing operations. Based upon pressure and flow characteristics during the unstimulated flow period, a reservoir stimulation may be performed in the form of an acid or frac treatment followed by a second flow test and pressure build-up. Additional prospective intervals may be tested as described above or may be commingled with the previously tested intervals. If commingling is chosen, production logging will be performed during the flow test to determine the productivity of the individual zones. 400 400 800 1200 1600 2OOO 2400 2800 3200 3600 4000 4400 _ 4800 - 5200- - 5600- 6000 - 6400 - 6800 - 7200 - 7600 8000 8400 88OO 92OO 800 Phillips Alaska, Inc. Structure : Rendezvous //2 Well : Rndvs2 RKB Elevotion: 135' Field : Exploration Location : North Slope, Alaska!~;;;;'~';T';:;'j;;;;; ............................. ~';;~:'i""~'"~i;~;~'! ....................................................................................................................................................... J Dote p~ottea: 16-Nov-2OOO { , Permafrost z~,L 9 5/8 Casing ** K-5 , Seq97 , Seq95 , Seqg3t KOP - Sdtrk Pt 3.00DLS: 3.00 deg per 100 ft 6.00 9.00 End Build 8.00 Begin Drop 6.00 4.00DLS: 2.00 dog per 100 ft 2.00 End of Drop Distrbed Zone LCU ~o4/uJu 7 coslng TOT- Top Bose J4 ~,.~D 5 1/2 Cosing 600O 6150 6300 6450 6600 6750 69OO 7050 7200 7350 7500 7650 7800 795O 8100 8250 8400 855O 8700 8850 [ [ i t i ] [ [ ~ 400 0 400 800 Vertical Section (feet) -> Azimuth 0.00 with reference 0.00 S, 0.00 E from slot #1 Plot Reference is RendezvousJ2 Vets. 1~2. i Coordinates ore in feet reference ~lot ~1. l! TTrue Vertlcol Oep hi are relerence RK~ (Nobori lgE).ll ~ ............................. ~?a~ .......................... ~ KOP - Sdtrk Pt 3.00 ~ D~S: 3.00 de~ per ~00 ft 6.00 B/ Ponded Turb. 9.00 B/ Ponded Turb. End Build Begin Drop 8.00 Dist, Zone LCU ~. J4/UJU + Bose J4 6.00 4.00 2.00 DLS: 2.00 deg per 100 ft End of Drop Distrbed Zone LCU U4/UJU - 7 CsgPt TGT- Top Bose J4 TD 5 1/2 Casing i , i i t i i i i ~ t i ] 450 300 150 0 150 300 450 Vertical Section (feet) -> Azimuth 0.00 with reference 0.00 S, 0.00 E from slot #1 Creeled by jones Dote plotted: 16-Nov-2000 Plot Relerence is Rendezvous~2 PH1 Vets,t2. Coordinates (]re in feet reference slot tl. iTrue Verlicol Depths ore relerence RKE~ (Nabors Phillips Alaska, Inc. StrUcture : Rendezvous //2 Well : Rndvs2 Field : Exploration Location : North Slope, Alaskai PROFILE COMMENT DATA Point MD Inc Dir TVD North East V. Sect Deg/1 O0 Permafrost 910.00 9 5,/8 Casing Pt 0.00 0.00 910.00 0.00 0.00 0.00 0.00 2855.00 0.00 0.00 2855.00 0.00 0.00 0.00 0.00 2955.00 0.00 0.00 2955.00 0.00 0.00 0.00 0.00 Seq97 ,3505.00 0.00 0.00 5505.00 0.00 0.00 0.00 0.00 Seq95 3825.00 0.00 0.00 3825.00 0.00 0.00 0.00 0.00 Seq95t 4825.00 B/ Ponded Turb. 6285.00 0.00 0.00 4825.00 0.00 0.00 0.00 0.00 0.00 0.00 6285.00 0.00 0.00 0.00 0.00 Dist. Zone 7450.00 0.00 0.00 7450.00 0.00 0.00 0.00 0.00 LCU 7665.00 0.00 0.00 7665.00 0.00 0.00 0.00 0.00 J4*/UJU Base J4 8280.00 0.00 0.00 8280.00 0.00 0.00 0.00 0.00 85,30.00 0.00 0.00 8530,00 0.00 0.00 0.00 0.00 ,..T_~ ............................................... 8_Z_8_ o ._ _o_o_ .......... _o.=_o_o ......... o .__0_o _o_ __~8Z so.po .... 9.._0__o_ .................... ._o....:..~)._0 ...................................... O...:..(~.g ............................... 9.:.(?.0.. ic,~°te~ ~r ~°"~ For: B Lloydi I)oto p~H~d: 15-1~ov-2000 Plol Relerence is Rende~ous~2 Vets. ~2. C~r~notes ore ~n feet relerence slot !1. [True Ve~l~ol Depths ore ~elerence RKB (~bors Phillips Alaska, Inc. Structure : Rendezvous #2 Well : Rndvs2 Field : Exploration i Location : North Slope, Alaskai Ih~EQ P OF-ILE CO ENT DATA Point MD Inc Dir TVD North East V. Sect Deg/1 O0 KOP - Sdtrk Pt 6000.00 0.00 360.00 6000.00 0.00 0.00 0.00 0.00 B/ Ponded Turb. 6286.07 8.58 360.00 6285.00 21.38 0.00 21.38 3.00 End Build 6515.93 9.42 360.00 6512.52 25.74 0.00 25.74 5.00 Begin Drop 6578.97 9.42 560.00 6576.68 36.59 0.00 56.39 0.00 End of Drop 6849.87 0.00 0.00 6845.46 75.00 0.00 75.00 2.00 Distrbed Zone 7454.41 0.00 0.00 7450.00 75.00 0.00 75.00 0.00 LCU 7669.41 0.00 0.00 7665.00 75.00 0.00 75.00 0.00 U4/UJU - 7 CsgPt 8284.41 0.00 0.00 8280.00 75.00 0.00 75.00 0.00 TOT - Top 8514.41 0.00 0.00 8510.00 75.00 0.00 75.00 0.00 Base J4 8554.41 0.00 0.00 8550.00 75.00 0.00 75.00 0.00 TD 8784.41 0.00 0.00 8780.00 75.00 0.00 75.00 o_.o,o , FIT 12.0 J 1000 2OOO 30OO 40OO 5000 6000 7000 8OOO 9OOO 10000 DRILLING TIME AND MUD WEIGHT CURVE I-~-Depth PAl Spark #1 l=~=~'~ Mud Weight _~l" ~.__1~ _ J`l .... J-----I----M--J- [ I I I .... J----J----[---J- I I I I ----'--'----'----'--------'--'----'----' 1 I I I I I I I .... I~__ J-----l---- L I I I .... 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I , , INU~l~l yl ,, 0 5 10 15 20 25 30- 35 40 45 50 55 60 65 70 75 80 85 90 95 TIME TO DRILL (DAYS) 9/99 Completed Rendezvous #2 FMC Gen V 9-5/8 x 7 x 41/2 Base of permafrost at 910' MD / 910' TVD 12-1/4" Hole 9-5/8" 40 ppf L-80 BTC-Mod Surf. Csg. 2,835' MD / 2,835' TVD 81/2" Hole 4Y2" 12.6 ppf L-80 8rd EUE tubing w/12' seal bore extension tied into top of liner 7" 26 ppf L-80 BTC Intermediate. Csg. 8,284' MD / 8,281' TVD Baker 5" x 7" ZXP LTP and tieback sleeve and HMC Liner Hanger. TOL @ 8032' MD/8032' TVD LI I I :i:i:i: I I :.:.:., · :.:.:, :.:.: · :.:.: :.:.: :::::: ~ ~;;:;'.. :::::: ,.... ':::: · :.:.: :.:.: i:i:!:t ::::: · :.:.:. ::.~ ::::::: :: ,:.: ::::::: ,~ ~ ::::::: :.:.:.:. :;:;::: ~:~ ~ :::::::: · . ...... · :.:.. -.:.:. [ .:.:.. .:.:. :.:.:.: .:.:.: · .'." .:.:.: .:.:.:. :::::: '::::: 6-1/8" Hole 3.813" CAMCO X nipple for SCSSV at 500' + MD 4 - Camco 41/2" x 1" KBG-2" side pocket GLM CAMCO 3.712" 16" Conductor Casing at 135' MD / RKB Base of permafrost 910' MD Rendezvous #2 WELLBORE SCHEMATIC and CEMENT DESIGN Top of West Sak 2,935' MD Base of West Sak 3,505' MD 9-5/8" Surface Casing at 2,835' MD Top of Cement at 7,400' MD 7~ Intermediate Casing at 8,284' MD 4-1/2" Production Liner @ 8,134' MD to 8,784' MD 8.1/2" Hole 6-1/8" Hole Conductor Casing Size / Hole Size 20" in 24' hole Depth: 135' MDRKB Top of Cement Surface Excess Calculated: 100% Volume Calculations: (135 If) (0.9599 cf/Io (2.00) = 259 cf (259 cf) /(0.93 cf/sx) = 280 sx Slurry Volume: 259 cf or Arctic Set I 280 ss Slurry Weight 15.7 ppg roundeO Slurr~ Yield 0.93 cf/sx , Surface Casing excess 9-5/8" In 12-1/4" hole Stage 1: Volume (910 If) (0.3132 cf/If) (2.50) = 997 cf (1,775 If) (0.3132 cf/If) (1.45) = 806 cf Lead (1,804 cf) /(4.44 cf/sx) = 406 sx Tail (150 If) (0.3132 cf/If) (1.45) = 68 cf shoe joint vol 34 cf + (68 cf)/(1.17 cf/sx)= 87 sx System: Lead (Arctic Set 3 Lite cement + 9% D44 (NaCl) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCI2) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (LiteCrete @ 12.0 ppg) Lead Slurry Volume:1,804 cf or 410 sx Slurry Weight 10.7 ppg Arctic Set 3 Lite Slurry Yield 4.44 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume:68 cf or 90 sx Slurry Weight 12.0 ppg Class G Slurry Yield 1.17 cf/sx Thickening Time 3.5 - 4.5 hours Intermediate CasingSize / Hole Size 7" in 8-1/2" hole Depth: 8,284' Top of Cement 7,400' Excess Calculated: 75% BHT (Static): 160~ F 130~ F BHT (Circ): excess Volume around 7 (884 If) (0.1268 cf/If) (1.75) = 196 cf shoe joint vol 17 cf + (196 cf) /(1.17 cf/sx)= 182 sx System: (Class G cement + 1% D800 + 0.2% D46 + 0.3% D65 Slurry Volume: 213 cf or 190 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.17 cf/sx Thickenin~l Time 3.5 - 4.5 hours Production Casing Size/Hole Size 4-1/2" in 6-1/8" hole Depth: 8,784' Top of Cement 8,050' Excess Calculated: 50% BHT (Static): 160; F 130; F BHT (Circ): excess Volume around 4-1/2" (500 if) (0.0942 cf/If) (1.50) = 71 cf Vol. Between liner & Int. = 20 sx shoe joint vol 7 cf +(71 cf)/(1.20 cf/sx) = 65 sx Volume of 200' above liner 40 sx System: (Class G cement w/Gasblok + 0.1 gps D47 (defoam.) + 3% D53 (Gyp) + 0.75% D65 (disp) + 1 gps D135 + 2 gps D600 + 0.1% D800 (ret.) Slurry Volume: 129 cf or 130 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.20 cf/sx Thickenin~ Time 3.5 - 4.5 hours RECEIVED JAN 3 0 2001 Alaska Oil & Gas Cons. Commission Anchorage 1/26/0 1 Rendezvous #2(, Proposed Casing & Completion Schematic Topset Base Case 16" 65# H-40 @ +/- 80' MD Depths are based on Nabors 19E RKB Surface csg. 9-5/8" 40.0# L-80 BTC (+/- 2835' MD / 2835' TVD) PHI"-LIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY 4-1/2" FMC Gen V Tubing Hanger, 4-1/2" L-80 EUE8RD pin down 4-1/2" 12.6# L-80 EUE 8RD Spaceout Pups as Required 4-1/2" 12.6# L-80 EUE 8RD Tubing to Surface 4-1//2" Camco 'X' nipple w/3.813" Profile set at +/- 500' MD. 4-1/2" x 6' L-80 EUE8RD pup installed above and below nipple. 4-1/2" 12.6# L-80 EUE8RD tubing to landing nipple 4-1/2" x 1" Camco 'KBG-2' Mandrels w/DV's and RK latch', 6' L-80 handling pups installed above and below on GLM. Spaced out w/4-1/2" 12.6# L-80 EUE8RD tubing as needed Intermediate csg. 7" 26.0# L-80 BTCM (+/- 8284' MD / 8280' TVD) Production Liner 4-1/2" 12.6# L-80 8rd EUE (+/- 8784' MD / 8780' TVD) 4-1/2" x 1" Camco 'KBG-2' mandrel w/shear valve and latch pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. 1 jt 4-1/2" 12.6# L-80 EUE8RD tubing 4-1/2" Camco 'X' nipple w/3.725" No-Go profile. 4-1/2" x 6' L-80 EUE8RD handling pups installed above and below 1 jt 4-1/2" 12.6# L-80 EUE8RD tubing 5.125" x 4" Baker Iocator sub 4-1/2" Baker GBH-22 casing seal assembly w/12' stroke, 4-1/2" L-80 EUE8RD box up Liner Assembly (run on drillpipe), Baker 7" x 5" 'ZXP' Liner Top Isolation Packer with HR profile (TOL est 150' above 7" Intermediate shoe Baker 7" x 5" 'Flexlock' Liner Hanger Baker 20' Seal Bore Extension XO Sub, 5" Stub Acme box x 4-1/2" 8rd EUE pin 1 jt 4-1/2" 12.6# L-80 8rd EUE tubing 4-1/2" 12.6# L-80 EUE 8rd liner as needed 4-1/2" Baker Landing Collar 1 jt 4-1/2" 12.6# L-80 8rd EUE tubing 4-1/2" Baker Float Collar 1 jt 4-1/2" 12.6# L-80 8rd EUE tubing 4-1/2" Baker Float Shoe WBL, 11/2100, vl , NPR-A Exploration Drilling Rendezvous #2 1,000' 2,000' 3,000' 4,000' 5,000' 6,000' 7,000' 8,000' 9,000' 1011 1213141516171819202122232425262728293031323334353637383940 Days 12/8/00 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 29, 2000 Daniel .1. Seamount, 3r., Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 RECEIVED DEC 1 1 ZOO0 Alaska Oil & Gas Cons. Commission Anchorage Re: Application for Permit to Drill: Rendezvous #2 (Exploratory Test) Surface Location: 1707' FNL, 2523' FWL, Sec. 6, T9N-R2E Target Location' 1633' FNL, 2523' FWL, Sec. 6, T9N-R2E ~ ~(,oC)(~C~ ~ ~__. ~. Bottom Hole Location: 1633' FNL, 2523' FWL, Sec. 6, T9N-R2E Dear Commissioner Seamount, PHILLIPS Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory test well from the referenced location in the National Petroleum Reserve - Alaska. The well is designed to penetrate, evaluate and test the production potential of'the objective sands. As indicated in the attachments, the drilling program will entail drilling an 8-1/2" wellbore through the objective with a full LWD logging suite for evaluation. Based upon favorable log data, the Well will be plugged back and twinned to the top of the objective and a 7" intermediate casing will be run in order to case off potentially sensitive shales. At least one 60' core will be cut through the objective zone beginning immediately below the 7" shoe. The well will be drilled to TD and a 4-1/2" liner will be run and the well will be tested, post-rig. The proposed casing program will utilize a 9 5/8" surface casing string, a 7" intermediate casing, a 4-1/2" production liner and either 4-1/2" or 3-::[/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottom hole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Diagrams and descriptions of the BOP and diverter equipment to be used (Nabors 19e) as required by 20 AAC 25.035 (a) (1) and (b) are on file at the AOGCC office 5) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 6) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. Complete mudlogging operations such as type log generation and sample catching are planned. The following are PH1~LUP's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Greg Wilson, Geologist (20 AAC 25.071) 263-4748 The anticipated spud date for this well is .lanuary 8, 2001. If you have any questions or require further information, please contact Bill Lloyd at (907) 265-6531 or Paul Mazzolini at (907) 263-4603 S i n ce re .y~,.~/~__~:~~ CC: CONFIDENT]:AL - Rendez¥ous #2 Well File Paul IVlazzolini ATO-1570 Andy Bond ATO-1310 RECEIVED DEC 1 1 Alaska Oil & Gas Cons. Commission Anchorage To: From: S~bjeci: Date: Greg Wilson William Lloyd Wayne Campaign Shallow salinities in the NPRA area. March 2, 2001 ~s l~L~j?c~ A~aska This document will discuss the evaluation of shallow aquifers in selected North Slope well logs. In this evaluation, no shallow aquifers were found to exist. Purthermore~ this evaluation demonstrates that the planned casing program would protect any aquifer in this interval if they were present. Additional objectives are to identity' and map any potential aquifers for future references~ or to document the absence of such aquifers as is presently deemed to be the case. Several wells have been selected l~br this study. These wells have been picked base on the presence of sufficient shallow logs, and for ~eographic coverage over the area of Exploration interest to Phillips. The logs have been evaluated for water salinities using common techniques to the industry and specified in the EPA document, ARCO Colville River St, #1 Pem~afrost Pick One facet of this evaluation is unique to the arctic. The first step is to select the base of Permafrost. it seems the sands freeze while the shales do not, This m~es the shales conductive and the sands resistive. In the past, many have picked Permafrost based on a simple resistivity cutoff, usually 100 ~2m's. When possible, I have employed sonic inJSx'mation as well Ice consolidates these uncompacted sands and the sonic displays faster travel times. Below the frost level, the sands show travel times similar to the shales. This example from the ARCO Colville River State #1 illustrates this. Note that a simple resistivity cutoff would place Base Permafrost much higher. Keep in mind, this only represents a "Ice-down- to' pick. There must be sand present in the section for the pemaafrost to be detected by any means short of a stabilized temperature survey. In t:act, temperature data collected fkom Alpine suggests pennafi'ost to be significantly deeper than these techniques have implied. Frozen sands will present high resistivities for reasons other than Iow salinity. Calculations will be meaningless. PHILLIPS Alaska, Inc, A Subsidiary of PHILLIPS PETROLEUM cOrvlPANY Also, the sands would not flow anything and could not be considered aquifers. Similar meaningless results would occur with the presence of hydrates, though they can exist at temperatures above freezing and just below actual permafrost. These situations need to be identified and excluded from this work. Two methods are used in this evaluation. The "Rw Apparent" or Rwa technique re-writes the Archie equation: Ro = a*Rw/~'~ to solve for Rw. The assumptions are; the sand is 100% water bearing (that is the implication of the term Ro to represent the sand resistivity), and no excess conductivity (shale) in the system. Porosity (~) is derived from Neutron-Density crossplot when available, but more often from the sonic, as it is more common in the shallow sections. For sonic porosity, I use an adaptation of the "Hunt-Raymer" algorithm 2. · = 0.6* (AT-56)/AT Other assumptions include values for a and tn (cementation exponent). The EPA document uses the Humble formulation (a = 0.62 and tn = 2.15), and I have used that here. I use a temperature gradient of 2.1° F per 100 feet. I have also converted all water resistivities to 75° F for easier comparison, and calculated salinities to kppm Total Dissolved Solids. Rwa has also been calculated in the shales. Porosities will be overestimated and mineral conductivity will be a factor, but these are opposing effects and the result will still be at least a qualitative measure of the fluid properties. The second technique uses the Spontaneous Potential (SP) curve. This curve measures the electric potential created by salinity contrasts between invading mud filtrate and connate water. Bounding shales serve as semi-permeable membranes, which enhance the reaction. Other effects on the SP are shale content of the sand, sand permeability and thickness, invasion, and hydrocarbon content. Empirical charts are available that attempt to correct SP for these and other effects, but I have used the SP directly. Understand that overlooking shaliness will suppress SP and result in salinity too low in the case of fresh muds, thus providing a lower limit. One further issue with the SP is that it often will wander, especially in these shallow sections. To straighten, or "baseline" the SP curve is a standard procedure, though may be somewhat subjective in extreme cases. The fmal pages are a section on proof of techniques. We perform Rwa calculations where we have an analyzed water sample from the W. Sak 26. We verify the sonic porosity algorithm by comparison to density results in the more compacted case of W. Sak 26 and also in the shallow, unconsolidated portion of the Nechelik well. SP calculations are also performed in the W. Sak 26. Unfortunately, this well was drilled will salt mud and has a reversed SP. In this case, SP suppression causes salinity estimates too high. With the more common fresh muds, salinities will be too low. Continuous water resistivity curves have been calculated for those wells with sufficient data, to a depth of 4000'. Sands with maximum SP excursions have been calculated with the SP technique as a check. Other wells have been calculated with the data available and conclusions drawn. Mr. Wayne Campaign March 2, 2001 Page 3 Following are results for the wells in NPRA. The presentations are X-Y plots of Rwa corrected to 75°F, versus measured depth. Where possible, SP estimates have been included as spot checks. The colors represent the Volume shale as determined from standard log analysis. Als() included is a small discussion on each well. From this and other work, we conclude there are m) fresh water aquifers below planned casing point. Reference Raymer, LL., Hunt ER., & Gardner JS., "An Improved "Sonic Transit Time-to-Porosity Transform", Tra~saction,v of the SPWLA 2I''~ Annt~al Loggi;,g S?¥;o,dum (1980). RWA ~' DEPTH Cro~splot W~tl: AT~OARU_PT_I Atigaru Pt. #1 This well has two sands just under the permafrost (960' MD) that exhibit high travel times and high resistivities, raising suspicions of free gas though there are m) shows on the mudlogs. Bek)w 1200', raw resistivities and Rwa calculations indicate high salinities. Rwa averages 0.3 ~2m ibr a TDS value of 20 Kppm. Mr. Wayne Campaign March 2, 2001 Page 4 RWA / DEPTH Crossplot Color N. Inigok #1 This well has i~kw sands (blue dots) in the section that calculate salinities in the range of 15 Kppnq TDS. This would be a value of Rwa of 0.4 film @ 75°F. The shales show significant compaction on the Sonic and Neutron logs while the Density suffers from hole problems. There is also question on the sonic versus a checkshot in the well. For these reasons, I disconnt the value of the Rwa values through the shale sections and use the sand values. Mr, Wayne Campaign March 2, 2001 Page 5 RWA / DEPTH CrosspJot Inigok #1 Like N. Inigok, this well exhibits a resistive section above the casing point. The SP, however shows a very different result. The upper hole was drilled with l~esh mud and exhibits a standard SP profile (more negative in sands) while the lower hole was drilled with KC1 salt mud and has a reversed SP. Despite this, results ikom the 2 sections show a consistent trend in salinity. The hole was drilled with a 17 V2" bit and much of it is washed out beyond the reach of the caliper, casting even more doubt on the porosity data. In conclusion, the SP inibrmation is deemed more reliable and gives an average salinity in the sands of 17 Kppm TDS. Even to use the more pessimistic Rwa for the sands, minimum salinity' would be in the sand @ 2260' MD with 10.4 Kppm TDS. Mr. Wayne Campaign March 2, 2001 Page 6 RWA / DEPTH Crossptot Well: F~SH_CREEK_TEST_I ? RWA (OH~M) Fish Creek Test #l This is an old well that has only a SP and Short and Long Normal Resistivity curves with no porosity logs of any kind. The SP calculations yield an average salinity of 11 Kppm TDS. I present the Long Normal log to suggest the low absolute values of resistivity imply salinities to be much higher. Mr. Wayne Campaign March 2, 2001 Page 7 RWA t DEPTH Crossplot We~l: W_FISH_CREEK_I W. ~sh Creek #1 The sands at the top of this display are associated with cycle skips on the sonic and the Rwa is invalid. The sands below 2500' all have tight streaks in them. That is the reason the Rwa values string out to the left. Vahd numbers are in the range of 0.25 - 0.3 ~)m, for a TDS of 22 Kppm. Mr, Wayne Campaign March 2, 2001 Page 8 RWA I DEPTH Crossplot ~e~: CLOVE Clover A This well has porosity information only below 3400' with MWD GR/resistivity above that point. There are no sands in the section and Rwa ~r~ the shales suggest a salinity of 20 Kppm TDS. The resistivity from the upper section shows there to be no resistive flesh water zones in the section up to the base of permafirost. Mr. Wayne Campaign March 2, 2001 Page 9 o RWA (o H ~ ~) Spark lA This is the same situation as the Clover well, no sands but a Rwa in the shales of 0.35 ~lm for a TDS of 17 Kppm. The shallow MWD logs show no resistive fi'esh water sands nor suggest any change in salinity. Wayne Campaign Sr. Staff Petrophysicist Mr. Wayne Campaign March 2, 2001 Page 10 Proof Of Techni~ ue P These segments of 2 well logs are presented as proof of the techniques applied in the study. We have water samples recovered from throughout this section o£ the W. Sak 26 well. Lab analyses are included. The fl~llowing table presents this data. ~ ! deas. 3000('['127 335 t208 345 13 212 ] 31K ~292~~30K~+42 092~7~ 176K ~_3250z:': 177~[.~4 --'" ~ ' --. ~ . ___.._._ L i2 i85. ~.~...__j . '-:":-'"-33K[~m--~:.... N~helik gl Il Sonic porosities are similar to density and the Rwa technique very dose to the water sample. Because of the reversed SP, suppression due shale content will over estimate salinity. Wkh fi'esh mud~ suppression of signal would underestimate salinity. CHEMICAL & GEOLOGICAL LABORATORIES OF AL.gSt(,A, INC. P.O. BOX 4-1276 Anchorage, Alaska 99509 TELEPHONE (907) 562-2343 ANCHORAGE INDUSTRIAL CENTER 5633 B Street WATER ANALYSIS REPORT OPERATOR Arco Alaska, Inc. WELL NO. West Sak 26 FIELD COUNTY STATE Alaska DATE February 24, 1985 .LAB NO. LOCATION FORMAT;ON /,,v' ~' .~ 7- INTERVAL ~ooo ' SAMPLE FROM Down Hole 7870-4 REMARKS & CONCLUSIONS: BARIUM (Ba), mg/1 0.29 STRONTIUM (Sr), mg/1 ........ 0.22 IRON (Fe), ms/1 ............. <0.10 A~fMONILq~ (NH4) ~ 41 SODIUM, measured, mg/].- ..... 1240 Cations mg/1 Sodium ............. 1273 Potassium ........... 80 Calcium ............. 12 Magnesium .......... 3.. Iron ................ Total Cations ......... m___eq/1 _ 55.41 2.05 0.60 0.29 58.35 A~'lions mg/1 Sulfate .............. 5.0 Chloride ............. 760 Carbonate ........... 0 Bicarbonate ......... 2245 Hydroxide ........... meo/1 0.10 21.43 36.82 Total Anions .......... 58.35 Total dissolved solids, mg/1 .......... 3237 NaC1 equivalent, mg/1 .............. 2737 Observed pH ....................... 8.0 Specific resistance @ 68° F.: Observed .......... Calculated ......... 2.3 2.4 ohm-meters ohm-meters Sample above described WATER ANALYSIS PATTERN Scale MEQ per Unit Na Ca Mg Fe C1 Na HCO' Ca SOa Mg CO' Fe Cl HCO' SO4 CO' (Na value in above graphs includes Na. K, and NOTE; Mgll = Milligrams per liter Meqll = Milligram equivalent per liter Sodium Chloride equivalent = by Dunlap & Hawthorne calculation from componentl CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, 1NC P.O. BOX 4-1276 TELEPHONE Anchorage. Alaska 99509 (907) 562-2343 , ANCHORAGE INDUSTRIAL CENTEF 5633 B Street WATER ANALYSIS REPORT OPERATOR WELL NO. FIELD. COUNTY STATE Arco Alaska, Inc. West Sak 26 DATE Februarv 24, 1985 LAB NO LOCATION 7870-3 FORMATION ~,,,, ~., 7- .f'¢ ,,¢' INTERVAL 3y2o-.f'O~ jy~/-,~d/ j ~z~- ?o SAMPLE FROM SWab 159 REMARKS & CONCLUSIONS: BARIUM (Ba), mg/1 0.28 STRONTIUM (Sr), mg/1 ..... 0.20 Il'ION (Fe), mg/1 dNO.lO .a2cIMONIUM (N~4) ,m~./1 .... 56 SODIUM, measured, mg/1---1375 Cations rog/1 Sodium ............. 1305 Potassium ........... 102 Calcium ............. 11 Magnesium .......... 3.1 Iron ................ -- Total Cations ......... meq/1 56.76 2.61 0.55 0.25 60.17 Anions mgll Sulfate .............. 5.0 Chloride ............. 820 Carbonate ........... 36 Bicarbonate ......... 2180 Hydroxide ........... -- Total Anions .......... meq/1 0.10 23.12 1.20 35.75 60.17 Total dissolved solids, mg/1 .......... NaC1 equivalent, mgll .............. Observed pH ....................... 3356 2870 8.4 Specific resistance @ 68° F.: Observed .. ........ 2.1 Calculated ......... 2.2 ohm-meters ohm-meters Na Ca Mg Se WATER ANALYSIS PATTERN Sample abo,v.e described Scale MEQ per Unit C1 Na HCO~ Ca SO' Mg COz Fe (Na value in above graphs includes Na. K, anO L1) NOTE: Mg!l = Milligrams per liter MeQtl = Milligram aQua,alan! per liter Sodium Chloride equivalent = by Ounlap & Hawthorne calculal~on from components C1 HCO~ SO' CO' PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P. ©. BOX 100360 AHCHORAGE, ALASKA 99510-0360 .January 10, 2001 Daniel .1. Seamount, ]r., Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 RE: Reference Document for NPR-A Exploration Drilling Program - 2000-2001 Dear Commissioner Seamount, Enclosed, please find the referenced document provided in consideration of AOGCC regulation 20 AAC 25.005 (C), parts 9 and 10, regulation 20 AAC 25.061 (a), and regulation 20 AAC 25.033 (f) i & 2 which state as follows: Before drilling or redrilling a we//or re-entering an abandoned we//, a person shall submit and obtain the commission's approval of an application for a Permit to Dr#/ (Form 10-,t01). 20 A. AC 2.5.005 (C) (9) for an exploratory or stratigraph/c test we//, a tabu/at/on setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(0; (10) for an exploratory or strat/graph/c test we//, a seismic refract/on or reflection analysis as required by 20 ~4C 25. 061(a); 20 A/IC 2S. 081 (a) For an exploratory or stratigraphic test we//, near surface strata to a depth of 2,000 feet in the vicinity of the well must be evaluated seismically by common depth point refract/on or retlection profile analysis, or by another method approved by the commission, to /dent/fy anomalous velocity variations indicative of potential shallow gas sources. Analysis results must be included with the application for the Permit to Dr/# (Form 10-401). 20 AAC 25.033 (f) Additional requirements that apply to exploratory and stratigraphic test we/Is are as fo/lows: (1) the operator shall include with an application for a Permit to Dr///a tabu/at/on that sets out the depths of predicted abnormally geo-pressured strata; (2) if the operator has geophysical data from the area, the operator shall include with an application for a Permit to Dr/# a seismic velocity analysis constrained by germane well data to predict the potential of encountering abnormally geo-pressured strata, with the analysis d/splayed by plotting interval transit t/me versus depth; as the commission considers necessary to evaluate the potential for a well control problem, the commission wi# require a review from the operator of the velocity analysis and of the p/at of interval transit t/me versus depth; It is requested the attached document be placed on file utilized as reference per these regulations for all applicable and identified exploration well Applications for Permit to Drill to be submitted by Phillips Alaska Inc. for the 2000/2001 Exploration Program. Should you have any questions, p~,e~se contact me at 265-6531. /! Sincerely, /~".,/~ /?' //) William B. LIo¢?-' ~',,-~/ [ Sr. Exploration Drilling ~ /nee RF__.CF_..%'VED GaS Cons. comraission Anchorage January 26, 2001 To: Tom Maunder- Alaska Oil & gas Conservation Commission From: Bill Lloyd - Phillips Alaska Inc RE: Additional Information for Rendezvous #2 and Lookout #1 Applications for Permit to Drill Tom: Per our conversation on 01/20, I've included the following diagrams and descriptions for the referenced permits: 1) dTiha~rDaimV:rtareer tahnedteBst(~Pngdip;go;;dmSuref~rpDerO~nurlr4elquOenstL.O (qk. out ~1. Included with these 2) The cement calculations ad design for Rendezvous #2 ~ ~...~,~ X If you need anything else, please call. 265-6531 .---. x ~,-~X- \q'~ .\ _ c,._ 244-5616 (cell) ~-, Ce~c~ ~:}~'"~ X..c~'~,.,..>,..~,~..~ RECEi'VED Alaska Oil & Gas Cons. Commission Anchorage Ri~ Floor I Kill Line 5 4 5000 psi BOP Doyen Rig 141 NPRA Exploration I Choke Line BeeP Stac~k Tes.~t r--2. CheI 1. Fill BcOktPh~ttaa~haor~dd.dmoawnnfO~dcreW[wthsaWr~etfeurilyretracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 5 minutes. Increase pressure to 5000 psi and hold for 10 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi for 5 minutes and 5000 psi for 10 minutes. Continue testing all valves, lines, and chokes with a 250 psi Iow for 5 minutes and 5000 psi high for 10 minutes. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi for 5 minutes and 5000 psi for 10 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi Iow for 5 minutes and 5000 psi high for 10 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 5000 psi for 10 minutes. 12. Test kelly cocks and inside BOP to 5000 psi for 10 minutes with BOP test pump. 13. Record test information on blowout preventer test form and on pressure chart. Sign and send to drilling engineer. 14. Perform BOPE test a) when initially installed, b) whenever any seal subject to test pressure is broken, c) following related repairs, and d) at 30 day intervals. Functionally operate BOPE daily. 15. Pit drills are to be conductled weekly for each drilling crew. 1. 16" Starting Head 2. 11" 5M psi Through Bore System Wellhead 3. 11" 5M x 13-5/8" 5M DSA 3. 13-5/8" 5M psi Hydril MPL Gate (pipe rams), 4-1/16" 5000 psi Side Outlets w/Manual Locks 4. 13-5/8" 5M psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5M psi Hydraulic gate and one 3" 5M psi Manual gate 2 Kill valves - one 3" 5M psi Hydraulic gate and one 3" 5M psi Manual gate 1 Check valve in Kill Line - 5M psi 5. 13-5/8" 5M psi Hydril Magnum Double Ram (pipe rams on top, blind on bottom), 4-1/16" 5M psi Side Outlets w/Manual Locks 6. 13-5/8" 5M psi Hydril Type GK Annular Preventer, Flange Connection RECEIVED JAN 3 0 Z001 Alaska Oil & Gas Cons. Commission Anchorage wbl Rev 01/22/10 2~'' ![ ~-1/4" DIVERTER SCH IvlATIC Doyon Rig 141 NPRA Exploration J 3 Open ! I Closed ~" ~" ! I I I · To Accumulator From Accumulator Closed Open Maintenance & Operation 1. Upon initial installation: - Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer/open the valve in the event that an influx of wellbore fluids or gas is detected. DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 16" Conductor 2. 16-3/4" 2000 psi Slip-on Weld Starting Head (Quick Connect) 3. 16-3/4" x 21-1/4" 2000 psi, Double-Studded Adapter Flange 4. 21-1/4" Diverter Spool with APl 21-1/4" 2000 psi Flanges 5. 21-1/4" x 13-5/8" 5000 psi, Double Studded Adapter Flange (Optional) 6. 21-1/4" Hydril MSP 2000 psi Annular Preventer 7. 16" Knife Valve. The valve opens automatically upon closure of annular preventer. 8. 16" Diverter Line RECEIVED JAN ,3 0 2001 Alaska Oil & Gas Cons. Commission Anchorage wbl, Rev. 01/15/01 American:ExPress' Cash' Ad~,ance Dz-a~'l= 3. 0 3. DOLLARS Issued by Integrated Payment STstem, Inc. En~lewood, Colorado NC:' F/~ALID FOR AMOUNT. OVER $ 1000 , Text for inclusion in permit approval cover letter: In accordance with 20 AAC 25.005 (f), all records, data and logs acquired for the original, pilot hole must be clearly differentiated in both name (Rendezvous #2 PH) and API number (50-103-20363-70) from all records, data and logs acquired for the subsequent twin well, which would be named Rendezvous #2 (AP1 number 50-103-20363-00). , , WELL PERMIT CHECKLIST FIELD & POOL ,,~ ,~ ADMINISTRATION .> ENGINEERI.I G COMPANY ,/'~'~ ,/'7~*~-~ WELL NAME '"~'2---c~' PROGRAM: exp INI~ CLASS '~?,~,/~ ~'/_~/~:>(--'/'-77'--O/~.'~BEOL AREA 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... ~,N 6. Well located proper distance from other wells .......... ~__'__.~' 7. Sufficient acreage available in drilling unit ............. 8. If deviated, is wellbore plat included ............... (,~. ~N 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ /~ N 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 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... ,,'"' dev redrll serv wellbore sag ann. disposal para req UNIT# ON/OFF SHORE 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 ................. ~ ' 31. Data presented on potential overpressure z~pes~ . . . . . . ' 32. Seismic analysis of shallow gas zones~ .... . . . . . AP~R DATE ~ 33. Seabed condition su~ey (if off-shore). ............ ~~~,~, ~ /' /~' C~( 34. Contact name/phone forweekly progress repo~s [explorato~ only]~N ~NNULAR DISPOSAL35. With proper cementing records, this plan . ~ ' ~ ' (A) will contain waste in a suitable receiving zone; . ...... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... (G) will not impair mechanical integrity of the well used for disposal; (~) will not damage producin~ formation or impair reco~e~ from a pool; and (E) will not circumvent 20 ~C 25.252 or 20 ~C 25.412. GEOLOCW: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 11/01fl00)