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Home My WebLink About206-019Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. p~ ©~Q - ~ ~ Well History File Identifier Organizing (aone> ~wo-sided III IIIIII II III II III ^ Rescan Needed III II'lll II II III III RES AN DIGITAL DATA Color Items: ~iskettes, No. ^ Greyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~I v ~ lsl Project Proofing BY: Date: P iiiuiuuii~iiiii mP /V Scanning Preparation ~ x 30 = ~~ + _~~ =TOTAL PAGES ~b ~ (Count does not include cover sheet) BY: _Maria Date: ~/~ ~~ /s/ ~. ® --T Production Scanning III IIIIII IIIII II III Stage 1 Page Count from Scanned File: S~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: _~YES NO BY: Maria Date: ~ a.,, D ~ lsl ,~ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO f BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II'I II I (III IIIII ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIII III II'I III 10/6/2005 Well History File Cover Page.doc ~'~ ~'" '~~ 4~ .~ ~« ~~~~ ~~ a~.~ x .. ~~~~~~ ~ r MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm Marker.doc a~ -~., DATA SUBMITTAL COMPLIANCE REPORT 6/17/2008 Permit to Drill 2060190 Well Name/No. ANTIGUA 1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23299-00-00 MD 6850 TVD 6850 Completion Date 4/21/2006 Completion Status P&A Current Status P&A UIC N REQUIRED INFORMATION ~/ Mud Log Yes Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/RES, Dens/Neu (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / iyp iweairrmi rvumue~ Name acme meaia No start Stop c1i Received comments D D Asc Directional Survey 0 6850 Open 6/15/2006 C Pds 13977~8'ee Notes 2 6700 6808 Open 7/13/2006 Mechanical Sidewall Coring Tool 13-Apr-2006 D C Pds 13977 Dip 1 4044 6780 Open 7/12/2006 Dipole Sonic Imager, P&S and Lower Dipole 12-Apr- 2006 l~cr 13898 Sample Col 2 6620 6700 Open 5/10/2006 Mechanical Sidewall Coring Tool 13-Apr-2006 C Pds 13898 ~mple 2 6620 6700 Open 5/10/2006 Mechanical Sidewall Coring Tool 13-Apr-2006 g 13898 Sonic 2 Blu 1 1011 6780 Open 5/10/2006 DSI P&S and Lower Dipole 12-Apr-2006 _ / ' / ~B C Pds 13898 ~Onic 2 1 1011 6780 Open 5!10/2006 DSI P&S and Lower Dipole 12-Apr-2006 „Log 13952 Neutron 5 Col 1-2 100 6850 Open 6/15/2006 DGR, CTN, ALD 26-Mar- 2006 og 13952 Induction/Resistivity 5 Col 1-2 100 6850 Open 6/15/2006 ROP, DGR, EWR 26-Mar- 2006 C Lis ~~ 13952 'Qnduction/Resistivity 1-2 100 6850 Open 6/15/2006 CTN, ALD, ROP, DGR, EWR 26-Mar-2006 Plus Graphics X99' Sonic 2 Blu 1 4044 6780 Open 5/10/2006 DSI P&S and Lower Dipole 12-Apr-2006 **REVISED** ~ED C Pds 13977 Dip 1 4044 6780 Open 5/10/2006 DSI P&S and Lower Dipole 12-Apr-2006 **REVISED** _-! ;QED C Lis 13977 ~iduction/Resistivity 3982 6790 Open 7/12/2006 Final Antigua LDWG r~ ~J DATA SUBMITTAL COMPLIANCE REPORT 6/17/2008 Permit to Drill 2060190 Well Name/No. ANTIGUA 1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23299-00-00 MD 6850 TVD 6850 Completion Date 4/21/2006 Completion Status P&A Current Status P&A UIC N pt 14120 Report: Final Well R 0 0 Open 9/5/2006 End of Well Report w/Graphics General Well Info, Daily Sum, Bit Report, Hole Sum, Mud Reports, Survey Report, Days vs. Depth, Morning Reports, Show Reports, Logs/Data CD Log 14120 See Notes 2 Col 100 4053 Open 9/5/2006 MD Gas Ratio Show Log 2":100' 11-Apr-2006 og 14120 See Notes 2 Col 100 6850 Open 9/5/2006 billing Dynamics 2":100' 11-Apr-2006 Log 14120 Mud Log 2 Col 100 6850 Open 9/5/2006 MD Formation Mud Log 2": 100' 11-Apr-2006 Log 14120 See Notes 2 Col 100 6850 Open 9/5/2006 MD LWD Formation Log 2":100' 11-Apr-2006 pt 14179 Sample 0 0 Open 10/16/2006 Petrographic Analysis of Kuparuk Sandstones, CPAI Antigua #1. October 2006 w/Word Copy C Wrd 14179 /Sample 0 0 Open 10/16/2006 Petrographic Analysis of Kuparuk Sandstones, CPAI Antigua #1. October 2006 w/Word Copy ~D C Exc 14118 'ample 0 0 Open 9/5/2006 Grain Size and Point Count Data j~ C Exc 14119 SSample 0 0 Open 9/5/2006 Core Labs Core Analysis (XLS), RSWC Analysis and Photos (PDF) ~D C Las 14120 Report: Final Well R 0 0 Open 9/5/2006 End of Well Report w/Graphics General Well Info, Daily Sum, Bit Report, Hole Sum, Mud Reports, Survey Report, Days vs. Depth, Morning Reports, Show Reports, Logs/Data CD Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Cuttings 0 6850 4/18/2006 1202 Cores and/or Samples are required to be~ • DATA SUBMITTAL COMPLIANCE REPORT 6/17/2008 Permit to Drill 2060190 Well Name/No. ANTIGUA 1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23299-00-00 MD 6850 TVD 6850 Completion Date 4/21/2006 Completion Status P&A Current Status P&A UIC N submitted. This record automatically created from Permit to Drill Module on: 2/8/2006. ADDITIONAL INFORMATION Well Cored? ~ / N S~ C M ~ Daily History Received? [V N Chips Received? ~-F~AI. Formation Tops (J' N Analysis ~Y / N Received? Comments: Compliance Reviewed By: ~.____-.____ Date: __- -__. ,~ TR~IV~i1~ITT~L COJVF/DEnITI~tL fJ~l TA FR014i: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7`h Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Antigua 1 Permit: 206-019 DATE: 10/11 /2006 el Antigua 1 500292329900 Report and CDROM Petrographic Analysis of Kuparuk Sandstone, CPAI Antigua #1, James L. Hickey, Applied Reservoir Petrology, LLC; October 2006. !=}~Ga3'.: G3'~,'.,iC O{i Cc1Ci~ 1tc;iii ;:S ?~•~ S;tVLi7. ~~7(i"iNtl ~' 5i~jil ~3 f;u i'~~fuf~', Ti"iC ii ,i Cl,•ii!llIi:`3, I iv :C.u~u:s:i Ri t.fi7':E. i To all daia recipients ~ AI/data is confidential until ,State o~~i/a~ka de.~ianated A DGCC r~Iease dais GC: Andy Andreou, CPAI Geologist Receipt: L, _ d _ Date: ~ ~ ....:_ .~. :,_ ,..._,°,. ,~ (JS`i-IC..;rtr'1".7: Ja~tr /','~,f...'r i " r,!r ~s1 r.' Sri rl i"r rr- E .y ~~..~':,:i~i ; s~C%,s/,.ti}1i;ro..,..~5 u>u,. tr~.rv:~ r..~..>.,.e , 1~1 . Ji~:._is s.G•.:: t.• Sandra.L~.,LemkeC~Conocophiilios c~om 0 C T ~ ~~ 2006 1'. 3. ~' ~.' Z ;•~I~S~~a .;.~ ~t 1~~~ ~;er€i~. ~u~e:~is~i~g ~~:~iCi~4 ~~~ ~~ ~~ Zee-flr9 • RECEIVED OCT 1 6 2006 Petrographic Analysis of Kuparuk sandst~~~~ c~ CPAI Antigua #1, Kuparuk River area, North Slope, AK ~. ~x .,? ~~ ; ~r ~~ ,~~ ~ ~~:g :~~ ~''~' a .{ ,S ,, ` 4 ~~` ~{5 ~ ~ ,~ '~_ ,~ ~, ;q ;- ._ ~~ ~~ ~ ~{ w ~ ~ ~ ~"c ~ Y James J. Hickey Applied Reservoir Petrology, LLC October, 2006 p~a~~c~p (~op~J • SUMMARY Twenty-six rotary sidewall cores from the Kuparuk River Formation (A, B, C, and D intervals) in the Antigua # 1 have been studied petrographically as part of the effort to understand the results of the well. The main reservoir interval, the Kuparuk C Sand, consists mostly of fine to medium-grained quartzose sandstones with common glauconitic clay pellets. These sandstones underwent considerable early (near-surface) diagenetis, and in most cases have been pervasively cemented by pore-filling siderite. As a result, reservoir quality is generally quite poor. The C Sand interval exhibits a number of characteristics typical of very proximal depositional conditions: oxidized glauconite pellets and shale rip-up clasts, reworked biogenic carbonate crusts and concretions, oolitic phosphatic rims, phosphatic pellets, and patchy phosphatic cement, and widespread radially-extincting siderite cement. Such facies are well-developed locally within KRU proper, as well as in some of the western PBU satellite fields and in wildcats further to the west. Proximal facies of the C-4 maybe thicker than average, with more extensive siderite cement, but are adjacent to facies with much higher reservoir quality -coarse-grained sands with less oxidation, less radial siderite, more leaching of early cement, and more remnant intergranular pores. The stratigraphic distribution of the changes in glauconite and siderite character in this well suggest that such higher-quality facies are likely to be present and more fully developed near the Antigua location. Samples from the Kuparuk A and B zones are thinly interbedded (millimeter-scale), very fine silty quartz sandstones and shale with sparse small unlined sand-filled burrows. The shallowest B sample, 6635', appears to be from immediately below the LCU, with large Glossifungites burrows filled with coarse glauconitic sand and widespread authigenic kaolinite in the silty sand laminations. Reservoir quality is minimal due to very fine grain size, high clay content, and thin bedding. In some of the thicker sand beds, there are a number ofwell-connected but very small intergranular pores, only partially occluded by light quartz overgrowth cement. The vertical sequence of compositional and diagenetic features in the Kuparuk C follow a stratigraphy typical of the proximal C-4: a basal zone with some chert, cemented by rhombic siderite with evidence of bioturbation increasing upwards; sudden onset of radial siderite accompanied by some kaolinite and abundant glauconite pellets, which grade upwards into increasingly oxidized clay pellets with associated carbonate and oxidized shale rip-ups in a chert-free sand; the interval is capped with a siderite ironstone and overlain by sandy glauconitic shale with scattered chert grains. Tentative lithostratigraphic interpretation identifies the basal interval with rhombic siderite as the C-4a, the overlying interval cemented by extensive radial siderite as the C-4b, and the sandy glauconitic shale as the Kuparuk D. Siderite cementation tends to be lightest at the onset of a new set of depositional and diagenetic conditions (e.g., base of the C-4a and C- ob zones). Such facies are thin in this well, but may well be much better developed (at the expense of the tight oxidized sands) very nearby, in a slightly less proximal location. Some of the radial siderite cement is prone to leaching in a less proximal location as well. 2 • • TABLE OF CONTENTS SUMMARY ........................................................................................................................ 2 INTRODUCTION .............................................................................................................. 4 KUPARUK C ...................................................................................................................... 6 KUPARUK A, B ............................................................................................................... 12 DISCUSSION ................................................................................................................... 14 Stratigraphy ................................................................................................................... 14 Reservoir Quality .......................................................................................................... 19 APPENDIX ....................................................................................................................... 20 Files on CD ................................................................................................................... 20 Photomicrographs ......................................................................................................... 21 LIST OF FIGURES Figure 1. Location of map of Antigua #1, immediately southeast of KRU ....................... 5 Figure 2. Selected photomicrographs, Kuparuk C Sand, Antigua #1 .............................. .. 8 Figure 3. Selected photomicrographs, Kuparuk C Sand, Antigua #1 .............................. .. 9 Figure 4. Schematic petrographic log, Kuparuk Formation, Antigua #1 ......................... 11 Figure 5. Selected photomicrographs, Kuparuk A and B Sands, Antigua #1 .................. 13 Figure 6. Depth profiles of matrix content and framework mean grain size (Fw MGS) 14 Figure 7. Grain size distributions for individual samples, Antigua #1 ........................... 15 Figure 8. Depth profile of total glauconite content, Antigua #1 ...................................... 15 Figure 9. Kuparuk C-4 schematic fades cross-section .................................................... 17 Figure 10. Petrofacies, compositional and diagenetic fades, Antigua #1 C-4 ................ 18 Figure 11. Poroperm crossplot, grouped by petrographic zones ..................................... 19 LIST OF TABLES Table 1. Summary of selected point-count data, Kuparuk sandstones, Antigua #1 ........ 10 Table 2. List of photomicrographs: sample depth, file name, horizontal field of view (mm), description ...................................................................................................... 21 Table 3. List of photomicrographs (continued): sample depth, file name, field of view, description ................................................................................................................. 22 Table 4. List of photomicrographs (continued): sample depth, file name, field of view, description ................................................................................................................. 23 3 • ~ INTRODUCTION The Antigua # 1 is an exploration wildcat well drilled in winter 2006 by ConocoPhillips Alaska, immediately southeast of the Kuparuk River Field (Figure 1). The main target horizon was the Kuparuk C Sand, one of the major reservoirs in the nearby field. This report is a summary of a petrographic study of 26 rotary sidewall cores recovered from in and near the Kuparuk C horizon. Of the 26 samples, thirteen are from the C Sand, and range in depth from 6621' to 6634'. One core (6620') is definitely from the overlying Kuparuk D Shale. Nine samples, 6635' through 6672', are from the underlying Kuparuk B, and two others (6693-6694') are from the Kuparuk A. The deepest sample, 6697.5', is also nominally from the Kuparuk A, but may be mislabeled or contaminated, as it appears very clearly to be from the Kuparuk D in composition and texture. The emphasis of the petrographic study has been on the Kuparuk C sandstones, but samples from the Kuparuk B and A (mostly thinly interbedded, very fine silty sandstones and shales) have also been described and documented. Routine core analyses, including porosity, Klinkenberg permeability, and grain density, are available for most of the cores (some were not suitable for such measurements due to poor recovery). Standard thin sections were prepared for each of the rotary cores. Dr. Mike Wilson performed point counts and grain-size measurements on the samples„ which were then forwarded to Applied Reservoir Petrology for description and interpretation. The point-count and grain-size data files from Mike Wilson are included on the CD accompanying this report. Sample descriptions are documented by three to four digital photomicrographs for each thin section, also included on the CD and listed and briefly described in a series of tables in the appendix to this report. 4 • • ~-.... I j"/. SANG ~/F~F~ ~.,~ ~/ ~'. 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W S}+k_~ "!0 67!781 tsJ~e~ ~' 7 ti+'S`F3k"1' ?t ,1 t r _ - ,~, S zAfo,2-Ct ~ + B.p Iup~ I -, -11-~'T' g ~ :. t~. •~ KOOkPJN 1 ~~ -fi 3+ -~ k ~{, .g1 -530! !K~ Yr~~p'; 2U 1p._,~, 12f r ~'~yr •Daet + _a11j0 EGE :~-Vt C C '~Pl. 7 -17 _ S~-~ _lats7 `~ ~oRM-7s -6d~aW 5-°'B~7L-D, -~osj~y~~~lbp-- i. -6, 6.,=HISS 2R~6rg'G~z -w257.'_5~ ~~~.,I ~Ti~'-ais7.6 + - ~~tlr'• ~-01 -a3f5s ~-5~~! a e9 0 ~~4D 11+.5au w sAk is 5:Il6?t35Ta1 ~#-ao-os _ ,J"YkK-rLOUR f + DBE RON 1 1:T S1K C i} '+ W SAK 3• pJ _.-B 6 .~' "•.-03 ~.. -6:31 ~ 2G-17 -61N5=% ~ -99+6 NCMI SPP 57 I C ~ I- ~ } -~sl ,KRU $TAiC 1 ~9u $rAT~e~s -5851 ~ l- -7sza _:-~ ~z3r-' -63n INtER iRAIL~a `r' "ra..iaA,%, ~11 KRU 27-10_8 i„` C1 7 ', -+0150 /I + _ _ '-F ! W $~y ~-10-3~INT[R TRAILS 7 j I'Ir Z •~ •.~ 4. -6326 ' ._ ~E- JT3 I -7s 16 -3861 4) - ~ W SAK 13 WINK l7 19A1LS 3N 71GUA 1 . ~ [) A 6sI4 HE4I 57 3-D9-11 =W SAk;~'-~~ -L65S AT I~~~ 1 -_ 3 _:993 '' ;~ -36D6 W $AK ''<6 _ Q 7 ~~T" - _ ~ 3 -6973'- + S ~~ - ""71.0 -] 131 ~~d p I ~ riINTER TRAILS 2 OJC 3 + i~ J ~t4NS{'S HQT ICE i - -3+a5 I 9 ~S6 RlVlk S7ATE I ~-~ u A + RUBY ST 2 ERP 763~tR 3 i0D1,"(K •'S: _~AS M~TL ~} RUBV SLATE 1 -sasz ~} esBs 4EL7WA fN 1 ~, -3.6s -C'?_~f ~ f Figure 1. Location of map of Antigua #1, immediately southeast of KRU 5 • • KUPARUK C The nature of the Kuparuk C interval in the Antigua #1 is evident from 13 rotary cores, spaced about a foot apart, supplemented by one (possibly two) cores in the overlying Kuparuk D Shale. The Kuparuk C in this well exhibits a vertical facies and diagenetic sequence typical of a depositionally proximal location on the margins of the KRU basin. Sand detrital composition is dominated by quartz, with minor alkali feldspar and chert, mixed with a variety of intrabasinal grains, particularly glauconitic pellets. The glauconitic pellets include the usual "fresh" green glauconite, as well as slightly to strongly oxidized pellets (light brown to very dark orange-brown), and non-glauconitized clay pellets. These grains were all originally fecal pellets introduced by burrowing organisms. The pellets then experienced a range ofnear-surface diagenetic changes that led to the incorporation of reduced or oxidized iron into the clay-rich grains, resulting ultimately in the different types of glauconitic and non-glauconitized pellets. In some cases the pellets have been altered to cryptocrystalline phosphate (cellophane) rather than glauconite. Note that, in the point-count results, Dr. Mike Wilson has interpreted the brown-colored glauconite pellets to be oil-stained rather than oxidized. While it is true that oil staining of glauconite can mask the original color, the actual invasion of oil into the microporous pellets is quite difficult from a capillary pressure point of view, and rarely occurs as a uniform staining of the entire pellet. Particularly in sandstones that have undergone pervasive early siderite cementation, I prefer to interpret color changes in the clay pellets in terms of redox differences during early diagenetic rather than overprinting by later oil charging. Other intrabasinal grain types present include carbonate rock fragments (interpreted to be reworked fragments ofearly-formed carbonate crusts and concretions), and oxidized shale rip-up clasts. Chert is present, often as outsized grains, in a few samples near the base and the top of the C Sand (as well as in the overlying D Shale). Diagenesis of the Kuparuk C sandstones in the Antigua #1 is dominated by early, pervasive siderite cementation. Siderite (FeC03) is an unusual carbonate phase whose development under diagenetic conditions is closely linked to the activity of iron-reducing anaerobic bacteria (which are also involved in generating iron for the glauconitization of fecal pellets). The crystal morphology, trace element chemistry, and stable isotope signature of siderite are controlled by the water chemistry (especially the distinction between meteoric freshwater and sea water) of the sand's pore fluids. In a coastal aquifer setting, where there is a large flux of fresh water in nearshore sands, siderite cement forms as a coarse pore-filling sparry baroque (radially-extincting) phase, usually in very high volumes and before any significant compaction of very ductile pellets. In a more offshore setting, where pore fluids are consistently fully marine and total fluid flux tends to be much lower, siderite typically occurs as small pore-lining euhedral rhombic crystals. In offshore sandstones with high volumes of siderite cement (e.g., due to slow burial and long residence times in the siderite-forming zone), the pore-lining rhombs coalesce into anhedral to drusy masses ofpore-filling siderite. In the basal part of the C Sand in Antigua 1, the oldest sandstone (6634') exhibits very sparse pore-lining siderite rhombs with considerable remnant intergranular porosity. Immediately above this, 6 • • micrite-filled burrows, extensive drusypnre-filling siderite and poor sorting combine to limit reservoir quality to low levels until the onset of radial siderite cement at 6631'. As with the question of oxidized glauconite pellets, my interpretation of siderite morphology differs slightly in detail from that used in Dr. Wilson's point counts - I recognize a much wider distribution of radial siderite than is evident in the point-count data, where such siderite is classified as coarse rhombs in several samples. Given the association of other early diagenetic features and visual confirmation of siderite crystal size and extinction patterns, I am confident that the classifications used in this report are accurate and consistent. Among these associated early diagenetic features (in addition to the glauconitization or oxidation of clay pellets) are the precipitation of pyrite (pre-siderite) and authigenic kaolinite in a few samples, and the development of oolitic phosphate rims on clay pellets in an unusually large number of samples. Phosphate precipitation is a geochemically rare occurrence, given the strong drive to recycle scarce phosphate by marine fauna. In the Antigua #1, phosphatic rims or phosphatized pellets occur in over half the samples. This relative abundance of phosphate (although not amounting in absolute terms to more than 1-2% in any given sample) is a reflection of the high organic activity, high physical energy, low sediment accumulation rates, and long near-surface residence times of these sands. Features of Kuparuk C sandstones in the Antigua 1 are illustrated with selected photomicrographs in Figure 2 and Figure 3. Other photomicrographs are available on the accompanying CD. Table 1 presents a summary of point count and quantitative grain size information for all the Antigua 1 samples. Figure 4 is a schematic log, based on thin-section descriptions, that documents the stratigraphic distribution of important petrographic parameters. Note in particular the relationships among the type of glauconite (fresh vs. oxidized), the type of siderite (radial vs. rhombic), chert, carbonate rock fragments (CRF), oxidized shale rip-ups (RB sh), grain size, and biogenic matrix. The vertical sequence of petrographic features in the Antigua 1 Kuparuk C interval is very typical of the C Sand in depositionally proximal locations all around the Kuparuk River Field. It is reasonable to expect similar lateral fades relationships and local heterogeneities as well; these ideas are discussed further below in the Stratigraphy section of this report. 7 • • rt ~ _ ~ . '. ... ry J~~ ~~ 6627': open framework, pyrite-lined quartz 6628': oxidized and fresh glauc~nitc iloatinb in pervasive siderite cement in multi-stage pore-filling siderite cement Horizontal field of view approx. 2.5 mm Horizontal field of view approx. 0.65 mm Figure 2. Selected photomicrographs, Kuparuk C Sand, Antigua #1 8 • • i [ ' ~ ; ,0. ,.a z ~~"~. .Y~ S ~ ~ ~ ~ ys7r ~ qp..,~ a J'" ~ 1p]~`~~~fyir~~ r ~ ty ~ I M. ` : 7 - i ~ ~~ j,-+ i . :v. .1 ~.. • ~ ~q. 6631': meniscus siderite cement Horizontal field of view approx. 0.65 mm ;,~ . . 6633': micrite-filled burrows, fracture- filling ankerite (dark blue stain) Horizontal field of view approx. 5 mm 4- y ~~ ~ ~.,~ 6632': bimodal close-packed sand Horizontal field of view approx. 5 mm J , y.~ 9 -.. ~ ' -? ~ ~. ~1~ . - ~1 6634': pore-lining siderite rhombs, intergranular pores in glauconitic sand Horizontal field of view approx. 0.65 mm Figure 3. Selected photomicrographs, Kuparuk C Sand, Antigua #1 9 • DEPTH UNIT HePor HPERM GD FwMGS MTX CHERT GLAUC CARB POR 6620.0 D --- --- --- 0.314 63.3 0.7 12.7 0.0 1.3 6621.0 C 5.06 0.0001 3.220 0.230 0.0 0.0 10.0 .76.3 0.0 6622.0 C 15.64 2.97 3.198 0.235 0.3 0.0 37.7 51.3 1.0 6624.0 C 12.17 0.003 3.281 0.259 0.0 0.0 48.3 45.0 0.7 6625.0 C 10.43 0.044 3.247 0.222 0.0 0.0 32.7 54.0 3.0 6626.0 C 18.2 0.247 3.254 0.232 0.0 0.0 26.7 54.0 0.7 6627.0 C 16.58 0.012 3.312 0.231 0.0 0.0 41.7 59.7 1.7 6628.0 C 5.81 --- 3.299 0.236 0.0 0.0 31.0 59.3 0.7 6629.0 C 9.67 1.98 3.214 0.227 0.0 0.0 20.0 53.0 1.0 6630.0 C 34.21 4240 3.109 0.246 0.0 0.0 24.7 47.3 7.3 6631.0 C 28.18 19.0 2..945 0.275 0.0 0.0 23.7 29.3 10.0 6632.0 C 13.86 0.508 3.000 0.260 0.7 0.3 15.0 40.7 1.3 6633.0 C 17.36 2.71 3.010 0.248 1.7 0.7 11.7 45.0 0.3 6634.0 C 28.75 41.9 2.771 0.287 0.7 10.0 15.7 25.0 7.0 6635.0 B 10.79 0.154 2.693 0.130 49.7 1.0 0.7 1.0 0.0 6637.0 B 13.19 0.476 2.682 0.108 29.3 1.7 0.0 0.3 2.3 6639.0 B 11.73 0.339 2.642 0.101 25.0 1.7 0.0 5.7 1.3 6640.0 B 18.40 0.378 2.765 0.077 25.7 1.0 0.0 2.3 2.7 6641.0 B 13.16 0.514 2.653 0.084 32.0 0.0 0.0 2.3 3.3 6642.0 B 13.91 0.257 2.837 0.096 41.3 1.7 0.0 40.0 1.3 6672.0 B 12.31 0.179 2.648 0.071 67.7 0.7 0.0 2.0 0.3 6675.0 B 12.33 0.049 2.716 0.092 68.7 1.0 0.0 1.0 0.0 6693.0 A 14.38 1.31 2.696 0.092 36.3 1.7 0.0 1.3 3.0 6694.0 A 12.98 0.021 2.676 0.049 39.0 0.3 0.0 4.0 0.3 Table 1. Summary of selected point-count data, Kuparuk sandstones, Antigua #1 Summary of measured data for point-count samples: stratigraphic unit; helium porosity (%BV); horizontal permeability (md); grain density (g/cc); mean framework grain size (mm); total matrix (clay and micritic siderite); chert, glauconitic pellets (including oxidized and non-glauconitic clay pellets); carbonate cement (nearly all siderite in the Kuparuk C, ankerite in the older units); and visible macroporosity. 10 Antigua 1 GRAIN SIZE PELLETS S IDE RITE Phos ACC ESSORIES UNIT DEPTH Mtx VF F M C VC GLAUC Clay ~ ~ Ank Kaol Rim Chert Lms CRF RB sh AF 0 6620.0 ~°~.~ 6621.0 -~: 6622.0 : X 6624.0 _ 6625.0 ~ 6626.0 U 6627.0 6628.0 6629.0 6630.0 X 6631.0 _ XX ~ 6632.0 ~ 6633.0 ~ ~~~ n ~, , U 6634.0 , 6635.0 " "'~ XXX X 6637.0 X X 6639.0 X 6640.0 m 6641.0 6642.0 6660.5 6672.0 6675.0 6693.0 Q 6694.0 D? 6697.5 ~ X Clay matrix Glauconite Fracture-filling Phosphatic Sideritic matrix Oxidized lauconite Figure 4. Schematic petrographic log, Kuparuk Formation, Antigua #1 11 • • • ~ KUPARUK A, B Nine samples (6635-75') from the Kuparuk B, and two (6693-94') from the Kuparuk A have been studied in thin section. A third sample nominally from the Kuparuk A (6697.5') is a burrowed sandy glauconitic shale with arenaceous foraminifera, large chert clasts, and a mixture of glauconitic and non-glauconitic clay pellets. This sample is definitely from the Kuparuk D Shale, probably from a stratigraphically younger part of the unit than the D Shale sample from 6620', based on vertical sequences observed in KRU proper. The source of the confusion over the sample's stratigraphic position is not clear; it is possible that a fragment of uphole shale was incorporated into the mudcake and recovered by the rotary core from 6697.5'. Most of the A and B samples consist of thinly interbedded sandstone and shale. Laminations are on the scale of a millimeter or less, and are usually very sharply bounded. Sand beds may be lenticular, representing starved ripple deposition. The sandstone is generally very fine-grained to silty, quartzose in composition, and cemented by quartz overgrowths (with one example of widespread ankerite cement). Planar and ripple laminations are evident in some beds. The shale is dark brown, silty, predominantly illitic in composition, with minor pyrite and lignitic organic material. Small burrows are sparse to common in the shale beds, usually unlined and sand-filled, although some clay-filled burrows (Helminthopsis?) are present. A summary of sample texture and diagenesis for samples from the Kuparuk A and B is presented in Figure 4. Selected photomicrographs from these samples are displayed in Figure 5. Based on point count data (Table 1), mean framework grain size is usually on the order of 70-100 microns, whereas as clay matrix content ranges from about 25 to 70%. Visible porosity is between 0 and 3% in most cases. Reservoir quality of the thin sand laminations is usually poor due to the very fine grain size, compaction, patchy clay matrix, and quartz cementation. In a few of the thicker clean sand beds, small intergranular pores (<20 microns apparent diameter in thin section) are common and widespread, suggesting awell-connected pore network and respectable absolute permeabilities within the bed itself. In sandstones near the top of the B Sand, intergranular pores are prone to be filled with microcrystalline authigenic kaolinite, resulting in a significant loss of permeability. The shallowest sample from the Kuparuk B, at 6635', appears to be very close to the LCU. The sample is a typical thin-bedded silty sandstone and shale, like others from the B and the A, but there are several large unlined burrows filled with sand that is significantly coarser than sand in the surrounding matrix, and of very different composition. The burrow-filling sand is quite glauconitic, and strongly compacted as a result of the high ductile content and lack of cement. Sandstone laminations in the surrounding matrix contain widespread pore-filling authigenic kaolinite. The burrows filled with glauconitic sand are interpreted to be part of a Glossifungites firmground assemblage associated with the LCU, in which younger glauconitic sand of Kuparuk C age has passively filled open burrows developed at a erosional surface at the top of the B. The authigenic kaolinite in sands near the top of the B may be pedogenic in origin. 12 • • ~~ ~s v ~ ~ ~ ' ~ ~ . ~~'S ~h~-__." f.'~~i` i~~-. ~''^- te~i s. t+ -cam '~"~ ~s`' .~ ~~ ti. ..h~. ., 7 ~a } ,'+~°~ •y~."'4 ? ~ ud pr :.r 3 ar.°"~, I ~ ~Y~ 'fit ~ .., # j~ . r 6642' : sand-filled burrow in laminated 6660' : clay-filled burrows in silty shale sandstone/shale Horizontal field of view approx. 2.5 mm Horizontal field of view approx. 5 mm _'- ~ ' ~, vM`~y~ , _ , l}1- ..,,. - ~",~ «-„j:• • F0. ,or' - .. t .. . . , - r~ Vii= ya+ ~ir• ... ~ ` w { ~n ,. .- Sr ~ •a~ { a~ ~ ity ~ `, ~~. s r 6672': isolated silty ripple in shale 6693': thinly interbedded silty sand and shale Horizontal field of view approx. 5 mm Horizontal field of view approx. 5 mm Figure 5. Selected photomicrographs, Kuparuk A and B Sands, Antigua # 1 13 • DISCUSSION Stratigraphy • As is generally the case, the contact between the Kuparuk B and overlying Kuparuk C is marked by a very sharp increase in sand grain size and decrease in detrital clay matrix (Figure 6). The clay in the A and B samples consists primarily of shale laminations, while the little matrix that is to be found in the C sands is a dispersed, intergranular burrow-related clay (or sideritized clay). The shallowest sample, 6620', is a bioturbated sandy glauconitic shale of the Kuparuk D, very different in fabric and composition from the thin laminations of silty claystone in the A and B intervals. 80 `''_ J,~-~.: Antigua 1 ~o ..,_ .. u so .2 v; yy X~) ~ d~ > -o-Matrix "~~~~ ~ o ~ m ~ 0 --< Fw_MGS `~ 30 ~ 20 10 0.05 C B A o 6620 6640 6660 6680 6700 Figure 6. Depth profiles of matrix content and framework mean grain size (Fw_MGS) Differences in mean framework grain size and grain size distribution (Figure 7) within the C Sand are also similar to that found in most other proximal wells, with the basal few feet being a bit coarser and poorly (or bimodally) sorted. Above these basal sands (and coinciding with the appearance of radial siderite), the grain size trends define a series of stacked upwards-fining sequences that are ultimately capped by the D Shale. In many proximal locations, including Antigua 1, with a relatively thin and telescoped section of the C Sand, it can be difficult to correlate the observed vertical changes with the standard Stratigraphy in the main part of the field (where the C Sand may be subdivided into a number of smaller units, from the basal C-1 up through the C-4b immediately beneath the D Shale). Total glauconite content generally increases upwards within the C Sand Q in the Antigua 1 section, before dropping significantly at the top of the sand due to extensive sideritization and the onlap of the D Shale. 14 • • 80 x-6620 0 -X6621 0 . . ANTIGUA 1 ~-6622.0 -+-6624.0 7p -~-6625 0 x'6626 0 . . `^' - ~ 6627.0 -o--6628.0 60 6629.0 -~-6630.0 --~-6631.0 -[~-6632.0 -~-6633.0 -fl-6634.0 50 -~- 6635.0 ~ 6637.0 -C~ 6639.0 ~- 6640.0 40 ~ 6641.0 -~-- 6642.0 ~ 6672.0 ._T _ 6675.0 30 - -9- 6693 0 -~- 6694 0 . . 20 10 - i,. p CLAY SILT V FINE FINE MED CRS VCRS+ Figure 7. Grain size distributions for individual samples, Antigua #1 Frequency distribution by grain size class, based on 200 measurements per sample (M. Wilson). Samples from the Kuparuk C are illustrated with greens and blues; other colors represent samples from the Kuparuk B and A. 60 Antigua 1 50 a ~, 40 a 30 0 env 20 0 10 0 6620 6640 6660 6680 6700 Figure 8. Depth profile of total glauconite content, Antigua #1 15 • • The preferred interpretation based on the petrographic observations is illustrated in the schematic log (Figure 4). The basal, relatively coarse, bimodal sandstones (6631-6634') are identified as "C-4a". This interval is characterized by rhombic siderite, fresh microporous glauconite, above-average chert content, micritic siderite-filled burrows, common reworked phosphatic pellets, and rare to absent carbonate fragments and oxidized rip-ups. The C-1 interval of KRU shares many of these characteristics, but is difficult to correlate with much confidence to the margins of the field. The section above the thin basal transgressive deposits of the C-4a is a classic example of awell-developed proximal C-4b section, with widespread high-volume radial pore-filling siderite cement, chert-poor quartz sand, locally abundant oxidized glauconite pellets, and small but consistent amounts of carbonate fragments and oxidized shale rip-up clasts. The bottom few feet of the C-4b contain fresh glauconite only, but above this oxidized glauconite becomes quite abundant. One exception to the dominance of oxidized pellets occurs at 6626', splitting the oxidized section into 2 intervals of about 3' each. This is the same pattern and vertical scale observed in much thicker oxidized intervals in the main field (e.g., 2E-17). The Antigua oxidized interval is (as usual) capped with a sideritic ironstone with scattered sand and fresh glauconite pellets (6621') immediately beneath the D Shale. This ironstone cap is quite widespread, and can be misleading in areas where the more proximal, oxidized, radial siderite-rich fades are not developed. One feature found in the C-4 in locations with extensive oxidized glauconite and radial siderite is dead oil (bitumen). No bitumen was noted in any of the Antigua samples. Although the aggressiveness of solvent extraction of residual oil from core plugs does very considerably from well to well, the bitumen in proximal C-4 wells is largely insoluble, and probably results from anaerobic biodegradation of the oil. The absence of dead oil at Antigua is a reasonably good indication that it will not be present in potentially better quality sands nearby, since the correlation with the oxidized diagenetic fades is pretty strong. Although the Kuparuk C units identified here are labeled "C-4a" and "C-4b", these terms are used in a lithostratigraphic sense only. It is certainly quite possible that the events recorded in these sediments represent a younger cycle ("C-5") than the similar sequence developed in KRU proper. Some independent line of evidence, such as biostratigraphy or seismic and well-log correlations, would be necessary to confirm the stratigraphic age of the C Sand in the Antigua 1 well. In terms of the depositional, compositional, and diagenetic fades defined for the C-4 Sand in earlier studies (Figure 9), the section at Antigua (Figure 10) contains a vertical sequence very typical of a proximal location. The basal few feet (6632-34') consist of Glauconitic and Shaly Glauconitic sandstone, of the Rhombic Siderite diagenetic fades and the Cherty compositional fades. Above this (6630-31'), the base of the C-4b is marked by a few feet of Glauconitic sandstone of the Radial Siderite diagenetic fades and Quartzose compositional fades (this part of the sequence is particularly well developed at Z-39). Overlying this is about 6' of Pelletal sandstone of the Oxidized diagenetic fades and Quartzose compositional fades. The oxidized features disappear abruptly at the ironstone cap at the top of the C Sand. 16 • PROXIMAL Pelletal Ss Glauconitic Ss Quartzose r~ LJ DISTAL Shaly Glauc Ss .~~~, Chert-bearing I Pyritic • ~ Radial Siderite Rhombic Siderite u~~..~ _ .. ~ ,~. a,_ _ . _ . , ~~.u, ~ .. _ 35 40 145 475 320 285 225 75 10 Figure 9. Kuparuk C-4 schematic fades cross-section Schematic proximal to distal cross-section, illustrating the downdip distribution of petrofacies (top), compositional fades (middle), and diagenetic fades (bottom). The interfingering, overlapping distribution of the different fades types leads to the dominance of a few fades combinations. Below the diagenetic fades, in red, are average permeability values corresponding to the relative dip location (and the fades combinations dominant there). Possible depositional settings are noted in italics, and along the base, in purple, are average grain density values (reflecting siderite abundance). Distally, decreasing grain size and increasing biogenic matrix content hurt reservoir quality. Proximally, pervasive siderite cement and high pellet abundance make for poor to spotty reservoir quality. The optimal depositional location for reservoir quality is an intermediate one. 17 • • Petro Compositional Diagenetic UNIT DEPTH Facies Facies Facies 0 6620.0 6621.0 6622.0 li,'~ ~~ ~' 6624.0 6625.0 ~ 6626.0 U 6627.0 6628.0 6629.0 6630.0 6631.0 ~ 6632.0 ~ 6633.0_ U 6634.0 '~~' Glauc Ss ~: Radial Shaly GI Ss Rhombic Pelletal Ss Oxidized Glauc Sh Ironston Pyritic Cherty Quartzose Figure 10. Petrofacies, compositional and dagenetic facies, Antigua #1 C-4 Generalized petrographic log for the Kuparuk C interval in Antigua # 1. The color-coded columns are: Petrofacies (Glauconitic Sandstone, Shaly Glauconitic Sandstone, Pelletal Sandstone, and Glauconitic Shale); Compositional facies (Cherty or Quartzose); and Diagenetic facies (Radial Siderite, Rhombic Siderite, Oxidized, Ironstone, and Pyritic). One common feature for wells in proximal locations such as Antigua #1 is a pronounced lateral heterogeneity in overall thickness and the extent of Siderite cementation. 18 • Reservoir Quality • Reservoir quality of Kuparuk C sandstones in Antigua # 1 is generally poor to moderate, due largely to extensive early siderite cementation. In a few samples (most often those at the base of a new fades interval), siderite cementation is significantly lighter; in such samples, compaction of abundant ductile glauconite pellets often proves to be a more important process in limiting effective porosity and permeability. In the Kuparuk A and B samples, reservoir quality is poor due to the interbedding of sand and shale on a millimeter scale, coupled with the very fine grain size, compaction and light quartz cementation (and in a few cases, extensive pore-filling authigenic kaolinite). 10000 1000 Antigua 1 ~' 100 ~ 10 W = 1 O • o c-4b (oX> 0 1 ~ 8 ^ C-4b (Rad) 4 C . 0 01 ~~ • - a oB . ~ ^A 001 0 . 0 5 10 15 20 25 He Porosity 30 35 40 Figure 11. Poroperm crossplot, grouped by petrographic zones Core plug porosity (%BV) vs. horizontal permeability (md) for all Kuparuk rotary cores measured in the Antigua #1. Samples are grouped by stratigraphic interval: from base to top, these are the Kuparuk A, Kuparuk B, Kuparuk C-4a, the lower C-4b (in the Radial siderite diagenetic fades), and upper C-4b (in the oxidized diagenetic fades). Data for the one C-4b (Rad) sample with multi-darcy permeability is highly suspect due to the poorly-cemented, glauconite-rich nature and poor physical condition of the core; a permeability in the tens of millidarcies would be a conservative estimate. For the Kuparuk C, the best situation in terms of reservoir quality is to have limited siderite cement (which usually means rhombic rather than radial siderite) and only moderate glauconite content (to forestall compaction). This is the case for the basal C sandstone (6634'), but this particular fades was very short-lived at this location. Sandstones from the basal C-4b (labeled as C-4b (Rad) in Figure 11) have a poorly- developed "meniscus" style of radial siderite, and can exhibit good reservoir quality (10- 100 md) as well. This fades is also not well developed here. Immediately downdip depositionally, the basal C-4a and C-4b fades may thicken at the expense of the tight oxidized sands of the C-4b, and some of the siderite cement may be leached out. The overall C may not thicken appreciably, but there is good reason to expect reservoir quality to improve substantially close to the Antigua location. 19 • • APPENDIX Files on CD Antigua_Petrog.doc .....................................This report (Microsoft WORD format) Antigua_Petrog.pdf .........................................This report (Adobe Acrobat format) Antigua_Petrog.xls ...................Spreadsheet with petrographic, point count, photo data PHOTOS ..........................Folder with digital photomicrographs (JPG) of all samples ConocoPhillipsAlaskaAntigua_1KRUGrainSizeData7-06.x1s........Wilson grain size data ConocoPhillipsAlaskaAntigua_1KRUGrainSizeData8-14-06.x1s....Wilson grain size data ConocoPhillipsAlaskaAntigua 1KRUPointCountData7-06.x1s....Wilson point count data ConocoPhillipsAlaskaAntigua_1KRUPointCountData8-14-06.x1s...WiIson point count data The point counts and grain size measurements were done in two batches of samples -the first covering 21 samples, the second batch including the remaining five samples, scattered throughout the section. 20 • • Photomicrographs DEPTH FILE FoV NOTES 6620 0 Antigua6620a 2.5 Sandy glauconitic shale . (D) Antigua6620b 2 Glauconitic sandstone clast in shale Antigua6620c 0.65 Quartz, glauconite in shale 6621 Antigua6621 a 2.5 Chert pebble in ironstone (C-4b) Antigua6621b 2.5 Phosphatic patch in sandy ironstone Antigua6621 c 0.65 Phosphatic crust in ironstone Antigua6622a 2.5 Early radial cement, moldic pore 6622 Antigua6622b 2.5 Silty burrow-fill in sideritic sandstone (C-4b) Antigua6622c 0.65 Phosphatic rim, radial pore-filling siderite Antigua6622d 0.65 Carbonate RF, pore-filling siderite Antigua6624a 2.5 Open framework, radial siderite, oxid glauc 6624 Antigua6624b 5 Open framework, outsized grains (C-4b) Antigua6624c 0.65 Radial siderite, phosphatic rims Antigua6624d 0.5 Phosphatic rim, fibrous siderite rims Antigua6625a 2.5 Oxidized glauconite, radial siderite, CRF 6625 Antigua6625b 2.5 Fresh and sl. oxidized glauconite (C-4b) Antigua6625c 0.65 Oxidized and fresh glauconite; radial siderite Antigua6625d 0.65 Open framework, radial siderite, oxid glauc 6626 Antigua6626a 2.5 Open fw, radial siderite, fresh glauconite (C-4b) Antigua6626b 2.5 Carbonate RF, phosphatic rims Antigua6626c 0.65 Siderite rims, pore-filling radial siderite 6627 Antigua6627a 2.5 Radial siderite, CRF, pyrite 4b (C Antigua6627b 2.5 Radial siderite, mixed glauconite - ) Antigua6627c 0.65 Pyrite, siderite cements Antigua6628a 2.5 Oxidized glauconite, radial siderite, CRF 6628 Antigua6628b 5 Early siderite, sl. oxidized glauconite (C-4b) Antigua6628c 0.65 Oxidized and fresh glauconite; radial siderite Antigua6628d 0.65 Oxidized, rimmed glauconite Table 2. List of photomicrographs: sample depth, file name, horizontal field of view (mm), description File names in red are the photomicrographs used in the figures in this report. 21 • DEPTH FILE FoV NOTES Antigua6629a 2.5 Radial siderite, pyrite. nodules 6629 Antigua6629b 2.5 Radial siderite, sl. oxidized glauconite (C-4b) Antigua6629c 0.65 Pyrite nodules, pore-filling siderite Antigua6629d 0.65 Glauconite, pyrite, siderite Antigua6630a 2.5 Meniscus siderite, microporous glauconite 6630 Antigua6630b 2.5 Large microporous glauconite, compaction (C-4b) Antigua6630c 0.65 Early pyrite, pore-filling siderite Antigua6630d 5 Quartzose sand burrow fill Antigua6631 a 2.5 Meniscus siderite, compaction 6631 Antigua6631 b 2.5 Glauconite-rich, siderite-poor area (C-4b) Antigua6631 c 0.65 Glauconite, meniscus siderite Antigua6631 d 0.65 Drusy pore-filling siderite Antigua6632a 5 Outsized quartz in tite sandstone 6632 Antigua6632b 2.5 Micritic burrow-fill, phosphate rims (C-4a) Antigua6632c 0.65 Phosphatic rim, drusy siderite Antigua6632d 0.65 Patch of micritic siderite cement Antigua6633a 5 Ankerite fracture-fill, micritic burrow-fill 6633 Antigua6633b 2.5 Pervasive drusy siderite cement (C-4a) Antigua6633c 0.65 Carbonate RF, thin phos rims, drusy siderite Antigua6633d 0.65 Drusy pore-filling siderite Antigua6634a 5 Chert pebble in porous glauconitic sandstone 6634 Antigua6634b 2.5 Scattered pore-lining siderite rhombs (C-4a) Antigua6634c 0.65 Pore-lining siderite rhombs, intergran pores Antigua6634d 0.65 Pore-lining siderite rhombs, intergran pores 6635 Antigua6635a 2.5 Glauconitic sand burrow fill in shale B Antigua6635b 5 Bioturbated quartzose sand-shale ( ) Antigua6635c 0.65 Squashed glauconite, kaolinite in Glossifiang. 6637 Antigua6637a 5 Interbedded VF sandstone/shale B Antigua6637b 2.5 Sandy burrow-fill in shaly sand ( ) Antigua6637c 0.65 Quartz cement, pores in fine quartz sand Table 3. List of photomicrographs (continued): sample depth, file name, field of view, description File names in red are the photomicrographs used in the figures in this report. 22 • • DEPTH FILE FoV NOTES 6639 Antigua6639a 2.5 Graded(?) quart sandstone bed B Antigua6639b 5 Clay drapes in lenticular-bedded sand ( ) Antigua6639c 0.65 Small pores, pyrite, quartz cement, kaolinite 6640 Antigua6640a 5 Laminated silty sandstone/shale B Antigua6640b 2.5 Grain size laminae in VF sandstone ( ) Antigua6640c 0.65 Intergranular pores in sandy lamination 6641 Antigua6641 a 5 Boudinage of sandstone/shale B Antigua6641b 2.5 Shaly laminae in sandstone ( ) Antigua6641 c 0.65 Clay drapes in lenticular-bedded sand 6642 Antigua6642a 5 Ss/Sh laminations, sand burrow-fill B Antigua6642b 2.5 VF ankerite-cemented sandstone ( ) Antigua6642c 0.65 Pore-filling ankerite in fine quartz sand 6660 5 Antigua6660a 2.5 Helminthopsis burrows in shale . B Antigua6660b 2.5 Silty lens in shale ( ) Antigua6660c 0.65 Clay-filled burrow in silty shale 6672 Antigua6672a 5 Starved silt ripples in shale B Antigua6672b 2.5 Disrupted sandstone lenses ( ) Antigua6672c 0.65 Top of sandy lens 66 Antigua6675a 5 Pyrite in sandstone lens/slump 75 B Antigua6675b 2.5 Sand burrow-fill in lam. Silty shale ( ) Antigua6675c 0.65 Pyrite in very fine sandstone lens 6693 Antigua6693a 5 Planar-lam sandstone, contact with shale A Antigua6693b 2.5 Shaly micaceous lens in sandstone ( ) Antigua6693c 0.65 Small pores in quartz-cemented sandstone 6694 Antigua6694a 5 Planar-lam silt, burrowed shale A Antigua6694b 2.5 Pyrite nodules in massive silt ( ) Antigua6694c 0.65 Micaceous-lignitic silty lamination 6697 5 Antigua6697a 2.5 Sandy glauconitic shale . D~ Antigua6697b 2.5 Arenaceous foram in glauconitic shale ( ) Antigua6697c 0.65 Glauconitic pellets in poorly-sorted shale Table 4. List of photomicrographs (continued): sample depth, file name, field of view, description File names in red are the photomicrographs used in the figures in this report. 23 • • ~()t'1Q~~ ~'11~~1 S TRANSMITTAL CONF/DENT/AL DATA FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7`" Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Antigua 1 Permit: 206-019 DATE: 8/29/2006 RECEIVED SEP p 5 2006 ,~laska Ori ~ Gas Cons. CQmmissioi Anchorage Antigua 1 500292329900 nt ~ 1~1t1~ ~~Grain Size and Point count data -Mike Wilson, August 2006 Repo/rt and CDROM V Rotary Sidewall Core Analysis -Core Labs, July 22, 2006; Job HOU-060338 ~ l ~l l l'~ Halliburton - End of Well Mud loggers report- General well information, daily summaries, bit data, directional survey data, morning reports, show reports. ~~ ~~~ Color log prints - 2"=100' ~ ~/ 1 `~ ~ Formation Mud log Drilling Dynamics log LWD Formation Log Gas Ratio Show log I2 cd's -End of well report with SDL logs, digital logging data; and PDF log images; EMF format viewer; August 29, 2006 (Please check off each item as received, promptly sign and return the transmittal to address below. To a!l data recipients; All data is confidential Until State ofAlaska designated AOGCC release date CC: Andy Andreou, CPA( Geologist Receipt:~~l/~,,ti _- Date: _ / (~~ U ~~ °~`=~.R~... .* : '~ r;.LS-Tec.lnu~~ri Pdi~ i~h~~d~Nn~Nitl ~ Cur-ur~~Flriliiu5 j Anr.r~nr.~yN, Ai~sk~ ~ Fii: 9i77J.n".S.ri.947 Sandra. D. Lemke(a)Conocophillips.com r '~~r1+~~"11~~1 S TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Antigua 1 Permit: 206-019 DATE: 7/11 /2006 • ~~~ ~uL x ,:.: Oi! & Gds ;~,', AB~t~ <ctt TO: Christine Mahnken AOGCC 333 W. 7~' Ave, Suite 100 Anchorage, Alaska 99501 RE~'EI~/ED _1111 1 ~ •~ru~ Nance gelrve I r n matte - - r Antigua 1 500292329900 ~a~ska Oil & Gas Gores, Gummission Anchorage CDROM Schlumberger Field DSI and CST pdsview files; Field DSI DLIS file; REVISED LDWG OH EDITS 4/12/2006; Job 11217238; this disk marked REVISED and a complete redistribution of logs delivered in May. There was a calculation error on previous sonic curve data, Schlumberger (REVISED) Finai Dipole Sonic Imager; P&S and Lower Dipole 4/12/2006; run 1 4044-6780' and Please check off each item as received, promptly sign and return the transmittal to address below. To all data reci Tents: A//data is confidentia/until State ofAlaska desi Hated AOGCC release date CC: Andy Andreou, CPAI Geologist Receipt: Date: '~~~~~~~~ - GIS-Technical Data Management ~ ConocoPhillips E Anchorage, Alaska ~ Ph: 907,265.6947 Sandra. D. L emkeCa7Conocophillips. com . • i ; R ~Ib(o ~ ~ v ~ "~ ~ ~ ~ f~l (+t~~ :: `~-'~ i /'s~. ;:tit r A. ConocoPhillips May 23, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for Antigua #1 Dear Commissioner: Paul Mazzolini Exploration Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling and P&A operations of the exploration well Antigua #1. Attached to the 10-407 is a summary of daily operations, directional survey, summary of the P&A operations, photos of the P&A, and a core summary. If you have any questions regarding this matter, please contact me at 263-4603 or Mark Chambers at 265-1319. Sincerely, ~~ ~~ P. Mazzolini Exploration Drilling Team Leader CPAI Drilling PM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPO~,~=~-~D LOG 1a. Well Status: Oil ^ Gas Plugged ~ Abandoned Q Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development ^ Exploratory Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., Z ( /'r 2~. or,4band.: April , 2006 12. Permit to Drill Number: 206-019 / 306-138 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: March 30, 2006 13. API Number: 50-029-23299-00 4a. Location of Well (Governmental Section): Surface: 1771' FNL, 2358' FWL, Sec. 35, T10N, R10E, UM 7. Date TD Reached: April 11, 2006 14. Well Name and Number: Antigua 1 At Top Productive Horizon: 1813' FNL, 2345' FWL, Sec. 35, T10N, R10E, UM 8. KB Elevation (ft): 20' RKB 15. Field/Pool(s): Total Depth: 1813' FNL, 2344' FWL, Sec. 35, T10N, R10E, UM 9. Plug Back Depth (MD + ND): surface Exploratory 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558554 ' y- 5915642 Zone- 4 10. Total Depth (MD + ND): 6850' MD ! 6850' TVD 16. Property Designation: ADL 390484 TPI: x- 558541 y- 5915600 Zone- 4 Total Depth: x- 558539 - - 5915601 Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: na 18. Directional Sr + ^/ ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1250' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE NTING RE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEME CORD PULLED 16" 62.58# H-40 20' 100' 20' 100' 24" 146 sx ASI 9-5/8" 40# L-80 20' 4044' 20' 4044' 12.25" 426 bbls 10.7 ppg ASlite, 107 bbls 12.5 ppg DeepCRETE cement plug #1 from 6420'-6850' cement retainer set at 3969' cement plug #3 from surface to 300' 23. Pertorations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET none none 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement plug #1 from 6420'-6850' 37.5 bbls of 15.8 ppg Class G Cement plug #2: cement retainer @ 3969' 18.5 bbls of 15.8 ppg Class G cement plug #3 from surface to 300' 22 bbls of 15.8 ppg Class G 26. PRODUCTION TEST Date First Production none Method of Operation (Flowing, gas lift, etc.) Plugged & Abandoned Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". 1 '.~., ~ ~ ~ 4~ CAtj~ S ~ ~iAV ~ Q 2DD6 ~~ ~ ~~~ REFER TO ATTACHED SUMMARY _.~-.~ Form 10-407 Revised 12/2003 ~~ f ~ s/~~ r ~ 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Antigua 1 Kuparuk 6620' 6620' West Sak 3302' 3302' Ugnu 2600' 2600' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, P&A summary, P&A photos, core summary 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mark Chambers @ 265-1319 Printed Na Paul MazzoliniQ . ~ Title: Exploration Drillino Team Leader f Signature ~(~ f~~dZ~~/~P}'~^^--~ Phone Date ~/z3 J221D~ ,~, INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ConocoPhillips Alaska Operations Summary Report Legal Well Name: ANTIGUA #1 Common Well Name: ANTIGUA #1 Event Name: ROT -DRILLING Start: 3/24/2006 Contractor Name: Rig Release: Rig Name: Arctic Fox Rig Number: Date From - To 'Hours ' Code !Sub 'Code - - _- 3/24/2006 ;12:00 - 23:59 ; 11.98 MOVE MOVE Phase MOVE 3/25/2006 00:00 - 00:00 ' 24.00 ;MOVE MOVE i MOVE 3/26/2006 ' 00:00 - 00:00 24.00 3/27/2006 li 00:01 - 00:01 ! 24.00 MOVE I~MOVE MOVE I MOVE RURD RIGUP 3/28/2006 ' 00:01 - 00:01 24.00 MOVE RURD RIGUP i Ii 3/29/2006 100:00 - 12:00 ', 12.00 MOVE RURD RIGUP 12:00 - 12:30 0.501 MOVE 12:30 - 17:30 ' 5.00' MOVE RURD ', RIGUP RURD II RIGUP 17:30 - 18:30 I 1.001 MOVE I RURD I RIGUP 18:30 - 00:00 5.501 MOVE RURD ,RIGUP Page 1 of 6 Spud Date: 4/1/2006 End: Group: Description of Operations ';Cleaned rig water tank, prep pipe shed modules for rig move, Remove all outside high pressure mud lines, load out casing sheds and air 'heater, remove all service connections Ld beaver slide, LD windwalls on rig floor, RD hyd lines from pump room, LD frame work @ drawworks, Prep derrick and LD same, Pull auger our of mud pits, RD and load out remaining pipe shed pieces, rig down and load out derrick, sub base, and pony sub, rig down mud pits and load out, pull all remaining wires picked up location, removed snow i from top of buildings, knocked steam lines and water lines loose for moving Clear snow off complexes, load air heater and welder, clean up pad, !,Prep Antigua, spot pony sub, prep complexes, set derrick, drawworks, ',mud tanks, pipe shed, cont rig up Rig up auger, put pins in derrick, raise derrick, set windwalls, rig up steam and start boilers. Spot air heater to pipeshed, set rooof caps over drawworks. R/U stairs on back of drawworks. Warm up deck motor and start, telescope derrick, install degasser, Go liners in pumps, run all electrical lines unbridle blocks, finish hooking up koomey lines and air to sub. Fill water tank, drive line to rotary table, install guards to rotary drive and draw works, tarps on front of hydraulic unit. Change 3 valve seats on #1 & 2 mud pumps, clean dog house, installing diverter line out of sub. Continue rigging up. M/U MUD LINES FROM PUMP ROOM TO RIG FLOOR. M/U MUD !MANIFOLD ON RIG FLOOR. P/U KELLY AND MAKE UP KELLY i, HOSE, C/O WIPER RUBBER IN KELLY BUSHING. INSTALL 'DERRICK HOUSE IN DERRICK. INSTALL FLOW LINE TO MUD PITS. INSTALL STEAM LINE @ MUD LINE & WRAP TARPS AROUND SAME. INSTALL MOUSE HOLE SLEEVE IN CELLAR. CLEAN SNOW F/CELLAR, HANG RIG TONGS IN DERRICK. INSTALL 6" LINERS & SWABS IN #3 MUD PUMP. FINISH HOOOKING UP KOOMEY LINES. HOOOKED UP SUCTION LINES TO MUD PUMPS. M!U POP OFF LINES ON MUD PUMPS 1,2, &3. RIG UP SUPPORT UNITS (MUD ENGINEER, GEOLOGY AND ~ SPERRY SUN, N/U DIVERTER, FINAL PREP ON MUD TANKS (DEGASSER), CLEANING UP RIG, INSTALL 4" VALVES ON CONDUCTOR, CLEAN CELLAR, HOOK UP FLOW LINE. RECEIVED 300 BBL SPUD MUD F/BAROID. Install catch can to bell nipple, fix hydraulic leak on Koomi line install fill-up line and jet line, hook up drain hoses to catch can install lower hydraulic lines to kelly spinner & test same. change out 4" valve in rock washer, pump up sensors for tong line torque, install tarps on catch can. PU mouse hole, hook drain hoses to pipe rack, install screens on shakers (100s0 Chink cracks on complexes. Install steam regulators on rig floor pump room and rock washer, clean rig for inspection, fix leak on annular rregulator, prep for spud pre-spud meeting w/ Conoco Phillips Co-man and safety specialist, env '1 specialist and all rig personnel ',Prep for spud, install wooden planks around cellar and herculite for 'drainage, finish filling mud tanks w/ spud mud, check for leaks in pump '.shed. organize BHA in pipe shed ', Test diverter and accumulator. Whitneseec! t1y Ghue~c Scheve ~, Accept Rig 18:30 3/29/06 ~ Level rig using hyd jacks and shim w/ lumber. insulate in space Printed: 5!15/2006 12:51:48 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: ANTIGUA #1 ANTIGUA #1 ROT -DRILLING Arctic Fox Date From - To 'Hours Code 3/29/2006 Ii 18:30 - 00:00 3/30/2006 ' 00:00 - 04:00 04:00 - 09:00 ~I 09:00 - 12:00 12:00 - 20:00 20:00 - 00:00 5.50 ~; MOVE 4.001 DRILL i 5.OOII DRILL Start: 3/24/2006 Rig Release: Rig Number: Page 2 of 6 Spud Date: 4/1/2006 End: Group: Sub ' Phase I, Description of Operations Code RURD RIGUP ~ between pony sub and substructure. Weld on V-door for pipe alley, held Diverter and accumulator drill final muster in truck shop 6.53 min. final li walk through prep to PU BHA. PULD ~ SURFAC Strap BHA. Lift sub too large for 4" elevators. Borrow 5" elevators from Doyon 15. PULD SURFAC MU bit and change angle on motor to 1.15. RIH tag ice plug at 20'. drill 3.00 DRILL i DRLG 8.00 DRILL ~ DRLG 4.00 DRILL I DRLG 3/31/2006 ', 00:00 - 05:00 5.00 DRILL 05:00 - 05:30 0.50 i DRILL 05:30 - 12:00 ~! 6.50 '' DRILL 12:00 - 18:00 ~ 6.00 DRILL ',18:00 - 18:30 ! 0.50 DRILL ~I,18:30 - 00:00 '', 5.50 DRILL I 4/1/2006 X 00:00 - 03:00 I 3.00 DRILL 03:00 - 04:00 ' 1.00 DRILL 04:00 - 06:30 i 2.50 DRILL 06:30 - 12:00 5.50 ~ DRILL 12:00 - 18:00 6.00 DRILL 18:00 - 18:30 0.50!!, DRILL 18:30 - 00:00 ~ 5.50 i DRILL 4/2/2006 ~ 00:00 - 05:00 ! 5.001 DRILL 05:00 - 07:30 " 2.50' DRILL 07:30 - 12:00 ` 4.50 DRILL !, 12:00 - 18:00 ', 6.00 !!, DRILL 18:00 - 18:30 '! 0.50 DRILL 1 18:30 - 00:00 5.501 DRILL 4/3/2006 00:00 - 05:30 05:30 - 07:30 07:30 - 10:30 10:30 - 11:00 11:00 - 12:00 12:00 - 18:00 18:00 - 18:30 18:30 - 21:30 5.50 DRILL 2.00 DRILL 3.00 DRILL 0.50 DRILL 1.001 DRILL 6.001 DRILL 0.50 ~; DRILL 3.001 DRILL DRLG DRLG DRLG (DRLG I~ DRLG -:DRLG ;DRLG CIRC ~~ TRIP through ice to 82' Blow down Kelly. PU MWD and test. OK. PU rest of 'BHA SURFAC ' PU Kelly...Kelly hose froze. thawing kelly SURFAC 'Thaw stand pipe and kelly hose w/ steam. Blow air through mud line ',and stand pipe and kelly hose to verify clear. Thaw jet line from rig floor i to mud pits. thaw auger from rock washer to cuttings tank, repair rotary table air line, work on mud pumps caps and pony rod clamps. SURFAC Brk circ and verify drill ready. drill 100' to 211' spr #1 256 psi @ 65 spm, spr #2 230 psi @65 spm. PU 53K, SO 52K, ROT 52K, Torq on 250, torq off -0- SURFAC Drill 211 to 362' SURFAC I Repair ON/OFF switch on rock washer auger SURFAC 'Drill 362' to 711' @180 spm w/1600 psi, 10K WOB, w/80 rpm SURFAC '' Drill 711' to 1,051 SURFAC ', rig floor gas detector alarm sounded, evacuate rig, false alarm, Rig ~! service, grease blocks, swivel, and draw works SURFAC ', Drill 1051' to 1395' @170 spm w/ 1950psi 10-12 K WOB, w/85 rpm. ~, spr #1 65 spm@265 psi, spr#2 65 spm@ 230 psi Rot hrs = 14.12„ 152604 K revs PU=95, S0= 75, ROT= 85, Torq= 350 SURFAC Drlg from 1395 to 1524' SURFAC Circ and condition SURFAC Short trip to DC's RIH to 1454' wash to bottom @ 1524 no problems, Max gas 4378 units on btms up (C1 f/coal @-1500') mud wt gas cut by •5 PP9 DRLG I, SURFAC Drill 1524 to 1777 up 92K ,SO 95K, Rot 92K DRLG 'SURFAC Drill 1777 to 2001' OTHR 'SURFAC I Rig service, grease blocks, crown shives and swivel DRLG I SURFAC 'i Drlg 2001' to 2347 UP 102K, S0103K, Rot 100K rpm- 85-90, Rotating jDRLG TRIP DRLG DRLG OTHR DRLG DRLG TRIP DRLG OTHR DRLG DRLG OTHR DRLG !.hrs =11.87, 276,251 Krevs SURFAC ~ Drill from 2347 to 2505' pump hi vise sweep @ 2442' SURFAC I Short trip 2505' to 1500' RIH, tight from 1560' to 1640', 2050, 2260 SURFAC 'Drill ahead from 2505 to 2761 pump hi vise sweep @ 2665' SURFAC ''~ Drill 2761' to 2982' SURFAC ! Rig service, grease crown, swivel and draw works. SURFAC Drill 2982 to 3302' PU 110K, SO 113K, Rot 105K, torq on bot 3000, ~, torq off -0-, total drlg hrs = 40.17, today drlg hrs=12.6 p-rates down to 4'/hr thru concreations SURFAC ~ Drill ahead 3302' to 3493' SURFAC Short trip from 3493 to 2500', pull and run back 16 stds,. tight at 3075' SURFAC ,Break circ, ream last single down, drill ahead from 3493' to 3621' SURFAC Rig service crown, swivel, blocks, draworks, and driveline SURFAC !,Drill ahead from 3621 to 3685' SURFAC 'Drill 3685 to 3844' SURFAC ;Service rig, crown drawworks SURFAC !Drill 3844 to 4053' @ 270 gpm w/ 2005 psi, Up 122K, SO 122K, rot ,120, Torq on btm 2200, torq off 250, total rot hrs 52.10, jar hrs 52.10 ':.568932 Krevs Printed: 5/15/2006 12:51:48 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: ANTIGUA #1 Common Well Name: ANTIGUA #1 Event Name: ROT -DRILLING Start: 3/24/2006 Contractor Name: Rig Release: Rig Name: Arctic Fox Rig Number: Date From - To 2006 21:30 - 22:30 I 22:30 - 00:00 2006 00:00 - 01:00 01:00 - 03:00 03:00 - 06:00 ~. i 06:00 - 06:30 ! ~ 06:30 - 10:00 ~I 110:00-13:00 !i ;13:00-14:30 ~ '14:30-15:30 15:30 - 18:00 ! 18:00 - 19:00 1,19:00 - 20:00 Hours Code 1.00 DRILL 1.50 DRILL 1.00 DRILL 2.00 DRILL 3.00 DRILL 0.50 DRILL 3.50 DRILL 3.00 DRILL 1.501 DRILL 1.001 DRILL 2.50! DRILL 1.00 i CASE 1.00 ~ CASE 20:00 - 00:00 I 4.00 i CASE 00:00 - 06:30 i 6.501 CASE 06:30 - 11:00 11:00 - 12:00 ~~ 12:00 - 15:30 15:30 - 22:30 22:30 - 00:00 4/6/2006 !, 00:00 - 02:30 102:30 - 11:00 ~!~ 11:00 - 12:00 'I 12:00 - 15:00 15:00 - 22:00 22:00 - 00:00 4/7/2006 00:00 - 02:00 ! 02:00 - 05:30 ~I i ! 05:30 - 08:30 !, 108:30 - 10:30 '! ,10:30 - 11:30 11:30 - 13:00 13:00 - 14:30 4.50 1.00 3.50 7.00 1.50 2.50 Page 3 of 6 Spud Date: 4/1/2006 End: Group: Sub ', Phase ! Description of Operations Code CIRC SURFAC !Circ BU for depth correlation. OK. called TD CIRC SURFAC ''Pump high visc sweep CBU and prep floor for short trip. TRIP SURFAC ,Pump slug blow down, rack kelly back TRIP SURFAC I POOH f 4053' to 1100' tight at 3400' SLM + 1' TRIP SURFAC !~ RIH to 3990 fill hole @ 3140' hole slick TRIP SURFAC !, Brk circ ream last 60' to bottom. Pump hi visc sweep CIRC SURFAC Circ BU condition mud, check for flow. OK pump dry job. TRIP SURFAC POOH TRIP SURFAC LD BHA TRIP 'SURFAC Down load MWD TRIP !,SURFAC Finish LD BHA RUNC I SURFAC I RU to run casing OTHR !,SURFAC ''Weld 2" riser jet line onto conductor, RU to take rtns thrus conductor ! ~ outlets RUNC SURFAC !: PU float equipment, baker lock btm 3 jts, check floats OK RIH w/ 9-5/8" csg. RUNC SURFAC Continue runnng casing from 1543' to 2037 set down hard at 2037 PU !, csg swedge and spud through tight spot. circ clean and continue in hole '~ to 2920. brk circ. Continue in hole to 4044 CEMENTCIRC SURFAC condition mud and circ. Attempt to reciprocate. Pull up 3' and hang up. Pull 240k slack off and continue to circ w/ hanger 3' high CEMENT: PUMP SURFAC I PJSM, Dowell pump 20 bbls of spacer and test lines to 2500# CEMENT PUMP SURFAC pump 30 bbl spacer, drop bottom plug,pump 50 bbls mudpush followed WE WE WE by 426 bbls 10.7 ppg Arctic set lite folowed by 107 bbls of 12.5 ppg DeepCrete, drop top plug and displace w/ 275 bbls mud. Bump plug w/ !+/- 170 bbls of cement rtns. good returns throughout. CIP @ 15:00 I! 4/5/06. Flush annular and flow line to rock washer. suck up w/super sucker. NUND SURFAC ND diverter and diverter line. Clean and prep for storage, dump and clean rock washer and mud tanks to prep for new mud. NUND ~~ SURFAC ~ suck out cellar and set Vetco wellhead and test void, clean debris from sub structure and prep for NU. NUND !SURFAC ,PJSM on NU BOPs. Remove sub beams. PU kelly & break off saver I sub. NUND ;SURFAC ~ NU BOPs NUND !.SURFAC !Function test BOP, heat up kelly and blow down NUND ''SURFAC !~ Finish NU BOPS NUND ',SURFAC Repair annular, replace seals in top cap and test. OK NUND '',SURFAC 'Thaw kelly hose and stand pipe, blow down w/ air. finish nu flow line !~ 'and catch can system. set mouse hole. NUND II SURFAC !.Make up kelly hose, heat up kelly, blow down kelly, set test plug, fill stack. BOPE SURFAC !!Test BOPS 250 pis low, 5000 psi high, held for 5 min, Annular test 250 !! low, 3500 psi high. BOPE SURFAC 'I choke manifold valves would not hold pressure, service valves, attempt ~'to pressure test, with no success, service valves again with grease, test 8.50'; WE 1.001, WE 3.00 !. W E 7.00', WE 2.00' WE 2.0011 WE 3.501 WE 3.001 WE 2.00 1.00 1.50!! 1.501 again valves held. WELCTL! BOPE SURFAC Cont. test BOPE, Accum test drop 3000-1850, 200psi in 10 sec, ! 3000psi in 65 sec. 2350 Avg bottle press. WELCTL' BOPE SURFAC Pull test plug blow down choke line & manifold, install wear ring. PJSM !, on picking up & making up BHA DRILL I PULD INTRM1 PU 8-1/2" bit and MU BHA DRILL PULD 'i INTRM1 I, Upload RLL tool Printed: 5/15/2006 12:51:48 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: ANTIGUA #1 Common Well Name: ANTIGUA #1 Event Name: ROT -DRILLING Start: 3/24/2006 Contractor Name: Rig Release: Rig Name: Arctic Fox Rig Number: Date From - To Hours Code 4/7/2006 14:30 - 15:00 15:00 - 15:30 15:30 - 17:00 17:00 - 17:30 17:30 - 20:00 20:00 - 21:00 21:00 - 22:00 22:00 - 22:30 ~ 22:30 - 23:30 '; 23:30 - 00:00 '. 00:00 - 01:30 ' 0.50 0.50 1.50 0.50 2.50 1.00 1.001 0.501 1.001 DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL 4/8/2006 01:30 - 02:00 02:00 -04:00 04:00 - 05:30 05:30 - 06:30 06:30 - 07:00 ~i 07:00 - 11:30 11:30 - 12:00 ',12:00 - 00:00 4/9/2006 ~ 00:00 - 05:00 105:00 - 06:00 ~~ 06:00 - 08:00 08:00 - 08:30 08:30 - 09:00 09:00 - 12:00 i 12:00 - 00:00 4/10/2006 00:00 - 11:30 111:30-12:00 I~ '12:00-19:00 , 119:00-20:301 20:30 - 22:00 '..22:00 - 23:00 : 23:00 - 00:00 '~, 4/11 /2006 ~ 00:00 - 05:30 0.50 ~ DRILL 1.50: DRILL 0.50 j DRILL 2.00' DRILL 1.50 DRILL 1.00 DRILL 0.50 DRILL 4.50 DRILL 0.50 DRILL 12.00, DRILL 5.00 ~~ DRILL 1.001 DRILL 2.00!. DRILL 0.50 0.50 3.00 DRILL DRILL DRILL 12.001 DRILL 11.50 DRILL 0.501 DRILL 7.OO DRILL 1.501 DRILL 1.50'; DRILL 1.00. DRILL 1.00;, DRILL 5.50 ~ DRILL Page 4 of 6 Spud Date: 4/1/2006 End: Group: Sub :Phase Description of Operations Code SFTY INTRM1 _- Safety mtg for PU Nukes PULD INTRM1 I Load source in nuke toot TRIP INTRM1 RIH w/ BHA #2 TRIP INTRM1 Pulse test MWD OK TRIP ~ INTRM1 ~~ RIH to 3926' OTHR ~I INTRMI PJSM slip and cut 121' drlg line ckeck COM, inspect brakes SFTY INTRM1 !Held stripping drill table top w/ crew OTHR '. INTRMI 'Transfer 10 bbls to Dowell and pre-heat w/ steam i OTHR 1, INTRMI '1 RU to test csg pump 2 bbl H2O close TIW valve test lines, hammer 1 union failed at cement line manifold w/ 2700 psi OTHR INTRMI Repair hammer union OTHR INTRMI 'PJSM Test lines to 3000 psi, Test 9-5/8" casing to 2500 psi for 30Min ' OK DRLG INTRM1 Blow down lines and kelly up, wash in and tag cement at 3955' I DRLG INTRM1 Drill cmt, plugs, F.C. @3962' (ADT 30 min) drill shoe @4042 (ADT=10 min.) Clean out rat hole to 4053' DRLG INTRM1 Drill new hole 4053' to 4073' CIRC INTRM1 I, Circ and swap to new 9.4 ppg mud LOT INTRM1 ;Dowell to perform LOT 13.2ppg EMW DRLG , INTRM1 'drill ahead to 4283' torq on1 K - 1.5K, torq off=-0-, UP 112K,S0 106K, ;Rot 108K. spr 1=210 psi@65 stks, 2=200psi@65 stks, 3=220psi@65 i 'stks 460 gpm 80-90 rpm @ 2000 psi OTHR . INTRM1 'service rig, crown,blocks,swivel, &draworks DRLG '.,INTRMI 'drill 4283 to 4822' UP 112K, Dn 105K, rot 110, torq on 1900,torq off 700, spr @ 65 stks, #1=364 psi, 2=317, #3=323psi Jars 16220397= 163.41 rot hrs, total rot hrs =13.1, PWD = 10.7 460 gpm 80-90 rpm ~ DRLG I INTRM1 ' @2400 psi Drill ahead from 4822 to 5014; ADT = 3.9 hrs ;CIRC INTRM1 Circ BU chk kill rate, monitor well Pump slug blow down and rack back (TRIP INTRM1 kelly. Wiper trip back to shoe @ 4021, w intermittent 10-20 K drag w/ partial swabbing) ~ ', OTHR INTRM1 I Rig service crown blocks, swivel, draworks, driveline ~!, TRIP INTRM1 1~ RIH and brk cir, wash and ream 4976 to 5014' No fill. DRLG INTRM1 Drill from 5014 to 5078 ADT=1.4 hrs, spr @ 65 stks =#! 350 psi, #2 ~I 350psi, #3 340 psi, PU 118K, SO 118K, rot 115K, 90 rpm, 2500 psi@ 465 gpm. W6/12 kWOB DRLG INTRM1 'Drill from 5078 to 5622' ADT = 10.2 Jars 16220397 = 78.91 hrs, UP 118K,DN 115K, Rot 118K, TO on 1700, TQ off 700, 90 rpm, 2550 psi ' @ 475 gpm w/ 10K WOB. spr @65 stks #1 335, #2 322, #3 323 psi. II DRLG ~; INTRM1 'Drill ahead from 5622' to 6036' ADT= 8.2 hrs. UP 122K, SO 119K,Rot 122K, 95 rpm, 2950 psi @480 gpm w/ 8-12K WOB spr @65 stks #1=370, #2= 370, #3= 360, OTHR ' INTRM1 1 service rig, crown, blocks, swivel, drawworks, driveline DRLG '~, INTRMI ~I Drill from 6036 to 6291 ADT 5.3 hrs, pump Hi Visc @6281' CIRC ', INTRM1 ~1 Circ sweep out & BU, sweep returned 50% increase in cuttings, chk kill ', rate, check for flow pump slug, blow down TRIP 11 INTRMI I Make 20 std wiper trip to 5014' pulled slick hole fill 1.5 bbl long ;TRIP I INTRM1 RIH wash & ream 6252 to 6291 , no fill hole slick, pump hi visc sweep ',DRLG INTRM1 Drill from 6291 to 6323 ADT 1 hr. 95 rpm, 10K WOB 475 gpm @ 2950 psi. UP 130K, Dn 130K, rot 130K, torq on 2,000, torq off -0-, jars ', 116220397 = 93.4 hrs DRLG i I INTRMI Drill 6323 to 6535 ADT= 3.9 hrs Printed: 5/15/2006 12:51:48 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: ANTIGUA #1 Common Well Name: ANTIGUA #1 Event Name: ROT -DRILLING Start: 3/24/2006 Contractor Name: Rig Release: Rig Name: Arctic Fox Rig Number: Date From - To 1 Hours 4/11/2006 05:30 - 07:30 'I 07:30 - 08:30 ' 08:30 - 11:30 11:30 - 12:00 12:00 - 17:30 17:30 - 19:00 1119:00 - 19:30 19:30 - 20:00 20:00 - 20:30 20:30 - 22:30 i ~~~ ' 22:30 - 00:00 ' 4/12/2006 '~ 00:00 - 02:30 ~'I 02:30 - 04:00 !. 04:00 - 08:00 ~ 108:00 - 10:00 ', 1,10:00-12:00 !, ' 12:00 - 17:00 ' 17:00 - 17:30 17:30 - 18:00 18:00 - 19:30 19:30 - 23:00 23:00 - 23:30 23:30 - 00:00 4/13/2006 00:00 - 00:39 00:39 - 01:00 01:00 - 04:00 I', 04:00 - 07:30 ' 07:30 - 08:30 ', ' 08:30 - 09:00 ', 09:00 - 10:00 '.10:00 - 12:00 'i 12:00 - 13:30 '' 13:30 - 18:00 i 18:00 - 19:30 19:30 - 22:30 22:30 - 00:00 4/14/2006 ',00:00-04:00 Code Code l Phase 2.00 DRILL CIRC ~'i INTRMI 1.00 DRILL FIT ~I INTRM1 3.001 DRILL I DRLG 0.501 DRILL i OTHR 5.50 ~~ DRILL !DRLG 1.50; DRILL CIRC 0.50 DRILL ' , OTHR 0.50 1, DRILL 'TRIP 0.50 1 DRILL TRIP 2.00 1 DRILL CIRC 1.50 DRILL TRIP 2.50 1 DRILL ,TRIP 1.50 DRILL TRIP 4.00 DRILL TRIP 2.00 DRILL TRIP 2.00 LOG PULD 5.00 I LOG ELOG 0.50 LOG ~ ELOG 0.50'i LOG OTHR 1.50' DRILL i WIPR 3.50' DRILL ' WIPR 0.50! DRILL II WIPR 0.501 DRILL (WIPR 0.651 DRILL iWIPR 0.35 DRILL 'WIPR 3.00! DRILL !WIPR 3.50', DRILL WIPR 1.00 ' DRILL 0.50 DRILL 1.OOi LOG 2.00 LOG 1.50 LOG 4.50 LOG 1.50 LOG 3.00 ABANI INTRMI INTRM1 INTRMI INTRMI I NTRM 1 I NTRM 1 I NTRM 1 I NTRM 1 I NTRM 1 INTRMI INTRM1 INTRMI INTRMI INTRMI INTRM1 INTRMI INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 I NTRM 1 I NTRM 1 I NTRM 1 INTRM1 WIPR ' INTRM1 OTHR INTRM1 ELOG j INTRM1 ELOG ',,INTRMI ELOG INTRM1 ELOG , INTRM1 ELOG '.INTRMI TRIP IABANDN 1.50 ABANDI~TRIP ABANDN 4.00 ABAND CIRC ABANDN Page 5 of 6 Spud Date: 4/1/2006 End: Group: Description of Operations !Circ well, monitor well, wait on water Perform FIT w/ Dowell to 12.9 EMW hold 10 min. Blow down lines, Brk circ ',drill 6535 to 6643' ADT= 2.7 hrs PU 130KS0 127KRot 130K, spr @ 65 'stks #1 360, #2 370, #3 370, 95 rpm, 475 gpm @ 2900 psi WOB 10K I Rig service blocks, crown, swivel, draw works, driveline drill 6646 to 6850 ADT= 4.7 hrs UP 135K, DN 135KRot 135K, torq on 1200, torq off -0-, 95 rpm, 475 gpm 2950 psi, 10K WOBjars 16220397 =104.7 hrs CBU ,pump sweep around, clean hole flow check, pump slug, blow down. POOH to 6185, hole slick RIH to 6825' & kelly up Fill pipe 12 bbls.,break circ., wash & ream from 6822 to 6850', No Fill, CBU 800 units of gas, Pump &circ Hi visc sweep around -clean, check kill rate & flow check, pump slug, drop 2.375" rabbit w/ 45' slick line tail, blow down. ~, POOH f logs SLM. 6825 to 4467 POOH from 4467 SLM, monitor well at the shoe, LD single DP and Std 'back HWDP ', Recover drift @ XO and std back DC's and jars, LD flex collars PJSM, Down load Nukes, and MWD data ', LD MWD and mud motor, Monitor well ,Install Lubricator 'PJSM, RU logging tools and RU loggers I~ Wireline log, bridge @ 3826' inside 9-5/8" csg, POOH w/wireline tools II (clay on tools), RIH w/ wireline tools, work past bridge, cont'd with logging run, hit bridge @ 4841 MD in OH, POOH w/ wireline logs RD wireline. clean floor and hold pjsm MU bit and BHA (DC's &HWDP = 50K hanging wt.) RIH w! DP and fill pipe @ 2545, @5030, tight at 6281 MD Kelly up ~ Wash and ream from 6250 to 6344' w/ 130 rpm, 378 gpm, from 6285 to 6300' to 10-12 K WOB torq 1-2K, Blow down Cont' RIH to 6496' cont. RIH to 6496' Took 20K kelly up brk circ Ream bridge @6810 to 6815 wash and ream to 6850 (20' of fill 2-5K WOB 130 rprn @ 400 gpm .CBU+ @ 465 gpm, 130rpm, pump hi visc sweep around, flow check, ', pump slug, blow down, rack kelly 'POOH tight @6600- 30K over, 6430, 6230 20K over,6120 15K over, '~ 48080 20K over, Wipe all tight spots until clean, ;Stand back collars 'monitor well, clean floor, install shooting niple PJSM, PU logging tools and RU loggers 'Wireline log Sonic 1st attempt 6786, 2nd 6808' ,POOH change out WL tools !~ RIH for WL sidewall cores ~, RD wireline ', PJSM,RIH w/ OE DP (Run thread protector on pipe thread) transfer 10 li stds of HWDP to DS pipe rack, cont RIH w/ 4" DP PU singles out of pipe shed to 6839' Circ and condition mud @ 6839', work pipe, thaw line, RU Dowell, ,PJSM on cmt plugging, bring on warm water. Printed: 5/15/2006 12:51:48 PM ConocoPhillips Alaska Page 6 of 6 Operations Summary Report Legal Well Name: ANTIGUA #1 Common Well Name: ANTIGUA #1 Spud Date: 4/1/2006 Event Name: ROT -DRILLING Start: 3/24/2006 End: Contractor Name: Rig Release: Group: Rig Name: Arctic Fox Rig Number: Date From - To Hours ' Code 'Code Phase Description of Operations 4/14/2006 04:00 - 05:00 ', 1.00 ABANDry PLUG ABANDN Dowell pump 5 bbls water, test lines to 2500 OK, pump 37.5 bbls cmt 05:00 - 05:30 0.50 ABANDN TRIP 05:30 - 07:00 1.50 ABANDN CIRC 07:00 - 08:30 1.50 ABANDN TRIP 08:30 - 12:00 3.50 ABANDN TRIP 12:00 - 12:30 0.50 ABANDN TRIP 12:30 - 13:00 0.50 ABANDN ~ TRIP 13:00 - 15:30 I 2.50 !, ABAND TRIP 15:30 - 16:00 0.50 ABAND CIRC 16:00 - 17:00 : 1.00 !.. ABAND PLUG ',17:00 - 17:30 I~ 0.50 17:30 - 18:00 0.50 18:00 - 18:30 0.50 18:30 - 19:30 1.00 19:30 - 22:30 i 3.00 22:30 - 00:00 1.50 4/15/2006 00:00 - 02:30 2.50 02:30 - 03:00 j 0.50 ~ 03:00 - 06:00 j 3.00 06:00 - 08:30 ! 2.50 08:30 - 09:00 ', 0.50 1 09:00 - 12:00 3.00 12:00 - 00:00 ii 12.00 4/16/2006 i, 00:00 - 12:00 12.00 12:00 - 00:00 12.00 ABAND PLUG ABAND PLUG ABANDN PLUG ABANDHTRIP ABANDN TRIP ABANDN TRIP ABANDN OTHR ABANDN TRIP ABANDN TRIP ABAND PLUG ABAND TRIP ABAND OTHR ABANDN OTHR MOVE RURD I MOVE 'iRGRP followed by 1 bbl water, rig displace w! 65 bbls mud. CIP @ 04:45 4/14/06 ABANDN POOH 10 stds (7 wet) to 6205 ABANDN ,circ & condition mud, btms up +, pump slug, blow do mud lines ABANDN !POOH from 6205 to 2702' standing back 65 stands, ABANDN '' POOH LD DP from 2702' ABANDN '; LD remaining 4" DP ABANDN 'clean rig floor, PU 9-5/8" retainer and XO ABANDN I, RIH w/ 9-5/8" retainer to 3969' ABANDN 'I RU circ swedge Brk circ Blow down ABANDN Safety mtg, set retainer@ 3969' set do 50K whitnessed by AOGCC John Spaulding. ABANDN establish injection rate 1 bpm= 600 psi, 1.5 bpm = 620 psi, 2 bpm=680 psi, 3 bpm=750 psi w/ 10.2 psi ABANDN li Test lines to 2500 psi„ pump water, 18.5 bbl cement, + 39 bbls mud @ 2 bpm 550 psi, ABANDN L Pull out of retainer -eaving 50' of cement on top of retainer. pull to 3835' close annular, test retainer to 1000 psi 10 min.OK ABANDN ! RD cementers Pull 2 stds wet. ABANDN LD 4" dp ABANDN ', RIH w/ DC's ABANDN I Break Kelly, LD kelly hose and kelly spinner ABANDN I RIH w/ HWDP ABANDN POOH LD HWDP and Collars ABANDN I Pull wear bushing and push 9-5/8" plug to 317' and cement. pump 1 bbl followed by 22 bbls of 15.8 ppg folioed by 1 bbl water. blow down lines ABANDN POOH LD 4' DP ABANDN Open doors on stack and wash out same, close doors ABANDN ND BOPS, clean pits, flush lines, break down pump room & pumps, break down mud line MOVE ~ LD kellyand rig down mud manifold on rig floor. LD all floor tools, rig tongs etc, LD kelly spinner to pipe shedLD flow line. RD mud line from pump to rig floor. Prep pipe shed for move. LD derrick house from derrick. Rolled all hoses from cellar for move.. Load out pipe shed to yard.Prep derrick for LD and bridle up blocks. Pulled covers off j, draworks for LD. Unhook driveline from rotary. Pulled roofcaps over ;draworks, Pulled tarps over draworks. MOVE ', LD wind walls set roof tops in place for rig move. Take out center braces for roofs, install beams in cellar, secure derrick lines, hoses, & slings, Telescope derrick down and lay over derrick, secure blocks, ~ unpin draw works, pull electrical lines, finish cleaning pit and rockwasher, clean suctions on mud pumps, blow down water and steam to rig floor and mud pits, suck out water tank, grease fittings for hoses and hard lines Rig Release 24:00 hrs 4/16!06 Printed: 5/15/2006 12:51:46 PM ~ • Antigua P&A' 2006 Antigua: Excavated conductor and 9 5/8 inch casing on 4/20/06. Cut off conductor and 9 5/8 inch casing 5 feet below ground level on 4/21/06 Cemented 9 5/8 inch casing to top of casing stub (six inches) with SWS ASl by hand. Cement top witnessed by Chuck Sheve (AOGCC) on 4/21/06 Welded identification plate on casings 4/21/06 Buried conductor and 9 5/8 inch casing with soils removed from the excavation and conductor setting process on 4122/06. Robert L. Morrison Jr. ... (Kuparuk) Kuparuk River Unit Kuparuk River Unit Non Pad Plan Antigua #1 -Antigua #1 Plan Antigua #1 • Design: Antigua #1 Rig Surveys Sp~err~-~ur~ Combo Report 12 April, 2006 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan Antigua #1 -Slot Antigua #1 As-Built @ 130.80ft (As-Built RKB (110.8+20)) N True API - US Survey Feet HALLIBURTCtRt ConocoPhillips Alaska (Kuparuk) HALLI ~ U RTC RI Kuparuk River Unit Design Report for Plan Antigua #1 -Plan Antigua #1 -Antigua #1 Rig. Surveys Measured ND below Vertical Local Coordinates Map Coordinates Dogfeg Vertical Depth Inclination Azimuth System Depth +NI-S +E/_yy Northing Easting Rate Section Comments (ft) (°) (°) (ftl Ift1 (ft) lft) (ft) lft) (°/100ft) (ft) 20.00 0.00 0.00. -110.80 20.00 0.00 0.00 5,915,642.12 558,553.73 0.00 0.00 100.00 0.00 0.00 -30.80 100.00 0.00 0.00 5,915,642.12. 558,553.73 0.00 0.00 141.00 0.19 61.51 10.20 141.00 0.03 0.06 5,915,642.15 558,553.79 0.46 0.03 239.00 0.26 77.31 108.20 239.00 0.16 0.42 5,915,642.28 558,554.15 0.09 0.16 331.00 0.19 89.86 200.20 331.00 0.21 0.78 5,915,642.33 558,554.50 0.09 0.21 422.60 0.14 59.82 291.80 422.60 0.26 1.02 5,915,642.39 558,554.75 0.11 0.26 518.40 0.25 101.44 387.60 518.40 0.28 1.33 5,915,642.41 558,555.06 0.18 0.28 608.82 0.22 48.77 478.02 608.82 0.35 1.65 5,915,642.49 558,555.38 0.23 .0.35 701.32 0.17 60.69 570.52 701.32 0.54 1.91 5,915,642.67 558,555.63 0.07 0.54 794.69 0.12 30.16 663.89 794.69 0.69 2.08 5,915,642.83 558,555.80 0.10 0.69 887.18 0.22 75.38 756.38 887.18 0.82 2.30 5,915,642.96 558,556.02 0.17 0.82 978.60 . 0.20 121.40 847.80 978.60 0.78 2.60 5,915,642.92 558,556.33 0.18 0.78 1,073.53 0.28 128.77. 942.72 1,073.52 0.55 2.93 5,915,642.69 558,556.65 0.09 0.55 1,165.72 0.22 136.99 1,034.91 1,165.71 0.28 3.22 5,915,642.42 558,556.95 0.08 0.28 1,261.41 0.38 145.92 1,130.60 1,261.40 -0.12 3.53 5,915,642.03 558,557.26 0.17 -0.12 ,1,359.10 0.37 165.65 1,228.29 1,359.09 -0.69 3.79 5,915,641.46 558,557.52 0.13 -0.69 1,453.45 0.44 158.47 1,322.64 1,453.44 -1.32 3.99 5,915,640.83 58,557.73 0.09 -1.32 1,547.04 0.67 155.33 1,416.22 1,547.02 -2.16 4.35 5,915,640.00 558,558.10 0.25 -2.16 1,643.50 0.64 155.65 1,512.68 1,643.48 -3.16 4.81 5,915,639.00 558,558.57 0.03 -3.16 1,739.30 0.63 190.14 1,608.47 1,739.27 -4.17 4.94 5,915,637.99 558,558.70 0.39 -4.17 1,836.00 0.70 172.18 1,705.16 1,835.96 -5.27 4.93 5,915,636.88 558,558.70 ,0.23 -5.27 1,931.19 0.82 173.45 1,800.35 1,931.15 -6.53 5.08 5,915,635.63 558,558.86 0.13 -6.53 2,025.17 0.72 .181.79 1,894.32 2,025.12 -7.78 5.14 5,915,634.38 558,558.93 0.16 -7.78 2,119.67 0.69 181.69 1,988.81 2,119.61 -8.95 5.11 5,915,633.21 558,558.90 0.03 -8.95 2,215.51 0.80 183.32 2,084.64 2,215.44 -10.19 5.05 5,915,631.97 558,558.86 0.12 -10.19 2,309.41 1.10 184.66 2,178.53 2,309.33 -11.74 4.94 5,915,630.42 558,558.76 0.32 -11.74 2,403.96 1.17 185.96 2,273.06 2,403.86 -13.61 4.77 5,915,628.55 .558,558.60 0.08 -13.61 2,498.97 1.31 184.38 2,368,05 2,498.85 -15.66 4.58. 5,915,626.50 558,558.43 0.15 -15.66 2,595.58 1.13 189.18 2,464.64 2,595.44 -17.70 4.35 5,915,624.46 558,558.21 0.21 -17.70 2,691.53 1.21 194.73 2,560.57 2,691.37 -19.61 3.94 5,915,622.54 558,557.82 0.14 -19.61 2,787.08 1.15 196.11 2,656.10 2,786.90 -21.51 3.41 5,915,620.64 558,557.31 0.07 -21.51 2,884.01 1.06 196.06 2,753.01 2,883.81 -23.31 2.90 5,915,616.84 558,556.81 0.09 -23.31 2,980.05 0.79 190.05 2,849.04 2,979.84 -24.81 2.53 5,915,617.33 558,556.46 0.30 -24.81 3,076.15 0.70 185.02 2,945.13 3,075.93 -26.05 2.37 5,915,616.09 558,556.30 0.12 -26.05 3,169.03 . 0.69 155.23 3,038.00 3,168.80 -27.12 2.55 5,915,615.02 558,556.49 0.38 -27.12 3,263.90 0.67 139.80 3,132.86 3,263.66 -28.06 3.15 5,915,614.08 558,557.10 0.19 -28.06 3,361.23 0.39 143.78 3,230.19 3,360.99 -28.77 3.71 5,915,613.39 558,557.66 0.29 -28.77 3,455.18 0.20 174.37 3,324.14 3,454.94 -29.19 3.92 5,915,612.97 558,557.87 0.26 -29.19 3,551.69 0.31 203.32 3,420.65 3,551.45 -29.59 3.83 5,915,612.56 558,557.79 0.17 -29.59 3,647.23 . 0.45 209.07 3,516.19 _3,646.99 -30.16 3.55 5,915,611.99 ~ 558,557.51 0.15 -30.16 12 April, 2006 - 7:00 Page 2 of 5 COMPASS HALLIBURTCa~"11 ConocoPhillips Alaska (Kuparuk) Kupartxk River Unit Design Report for Plan Antigua #1 -Plan Antigua #1 -Antigua #1 Rig Surveys Measured ND below Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth System Depth +N/-S +E/-W Northing Easting Rate Section Comments (ft) (°) (°) (ft) (ft) (ft) (ft) (ftI (ft) (°/100ft) (ftl 3,742.37 0.41 206.74 3,611.32 3,742.12 -30.79. 3.21 5,915,611.36 558,557.18 0.05 -30.79 3,836.46 0.33 202.40 3,705.41 3,836.21 -31.34 2.96 5,915,610.81 558,556.93 0.09 -31.34 3,930.24 0.37 177.40 3,799.19 3,929.99 -31.89 2.87 5,915,610.25 558,556.84 0.17 -31.89 3,981.35 0.39 174.34 3,850.30 3,981.10 -32.23 2.89 5,915,609.92 558,556.87 0,06 -32.23 4,092.56 0.38 176.62 3,961.51 4,092.31 -32.98 2.95 5,915,609.17 558,556.94 0.02 -32.98 4,154.76 0.40 172.40 4,023.71 4,154.51 -33.40 2.99 5,915,608.75 558,556.98 0.06 -33.40 4,246.13 0.38 167.79 4,115.07 4,245.87 -34.01 3.10 5,915,608.14 558,557.09 0.04 -34.01 4,342.21 0.39 166.94 4,211.15 4,341.95 -34.64 3.24 5,915,607.51 558,557.24 0.01 -34.64 4,438.77 0.37 172.35 4,307.71 4,438.51 -35.27 3.36 5,915,606.88 558,557.36 0.04 -35.27 4,536.88 0.31 189.41 4,405.82 4,536.62 -35.84 3.35 5,915,606.31 558,557.36 0.12 -35.84 4,628.19 0.22 184.42 4,497.13 4,627.93 -36.26 3.30 5,915,605.89 558,557.31 0.10 -36.26 4,727.71 0.25 200.64 4,596.65 4,727.45 -36.66 3.21 5,915,605.49 558,557.22 0.07 -36.66 4,822.66 0.36 226.79 4,691.59 4,822.39 -37.05 2.92 5,915,605.09 558,556.93 0.18 -37.05 4,918.02 0.53 220.07 4,786.95 4,917.75 -37.60 2.42 5,915,604.55 558,556.44 0.19 -37.60 5,009.82 0.57 227.26 4,878.75 5,009.55 -38.23 1.81 5,915,603.91 558,555.83 0.09 -38.23 5,106.32 0.57 230.27 4,975.24 5,106.04 -38.86 1.08 5,915,603.27 558,555.12 0.03 -38.86 5,202.74 0.62 237.66 5,071.66 5,202.46 -39.45 0.28 5,915,602.68 558,554.31 0.09 -39.45 5,299.34 0.70 244.61 5,168.25 5,299.05 -39.98 -0.70 5,915,602.14 558,553.34 0.12 -39.98 5,394.99 0.68 249.01 5,263.89 5,394.69 -40.44 -1.76 5,915,601.68 558,552.29 0.06 -40.44 5,490.19 0.57 254.97 5,359.09 5,489.69 -40.76. -2.74 5,915,601.34 558,551.30 0.13 -40.76 5,591.19 0.47 248.08 5,460.08 5,590.88 -41.05 -3.61 5,915,601.05 558,550.44 0.12 -41.05 5,682.91 0.53 246.20 5,551.80 5,682.60 -41.36 -4.35 5,915,600.73 558,549.70 0.07 -41.36 5,780.55 0.53 249.75 5,649.44 5,780.24. -41.70 -5.19 5,915,600.39 558,548.87 0.03 -41.70 5,875.49 0.58 256.73 5,744.37 5,875.17 -41.96 -6.07 5,915,600.12 558,547.99 0.09 -41.96 5,968.14 0.55 263.11 5,837.02 5,967.82 -42.12 -6.96 5,915,599.95 558,547.09 0.08 -42.12 6,063.60 0.69 265.23 5,932.47 6,063.27 -42.22 -7.99 5,915,599.84 558,546.07 0.15 -42.22 6,159.44 0.61 263.36 6,028.31 6,159.11 -42.33 -9.07 5,915,599.73 558,544.99 0.09 -42.33 6,259.79 0.62 265.26 6,128.65 6,259.45 -42.44 -10.14 5,915,599.61 558,543.92 0.02 -42.44 6,354.16 . 0.53 273.91 6,223.01 6,353.81 -42.45 -11.09 5,915,599.59 558,542.97 0.13 -42.45 6,451.20 0.50 283.04 6,320.05 6,450.85 -42.32 -11.95 5,915,599.71 558,542.11 0.09 -42.32 6,543.32 0.50 287.71 6,412.17 6,542.97 -42.11 -12.72 .5,915,599.92 558,541:33 0.04 -42.11 6,637.41 0.45 285.73 6,506.25 6,637.05 -41.88 -13.47 5,915,600.14 558,540.59 0.06 -41:88 6,731.71 0.51 286.18 6,600.55 6,731.35 -41.67 -14.23 5,915,600.35 558,539.82 0.06 -41.67 6,850.00 0.51 286.18 6,718.84 6,849.64 ~ -41.37 -15.24 5,915,600.63 558,538.81 0.00 -41.37 Straight Line Projection to TD Based upon Minimum Curvature type calculations, at a Measured Depth of 6,850.OOft the Bottom Hole Displacement is 44.09ft in the Direction of 200.22° (Grid). • r: 12 Apnl, 2006 - 7:00 Page 3 of 5 COMPASS H/~I LL ~ ~ u ~TQ ~ ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Design Report for Plan Antigua #1 -Plan Antigua #1 -Antigua #1 Rig Surveys Vertical Section Infofmation Angle Origin Origin Start Type Target Azimuth TYPe +N/ S +EI-W ND l°) (ft) (ft) (ft) User No Target (Freehand) 0.00 Slot 0.00 0.00 20.00 SUNev tOO/ plO4ram From To Survey/Plan Survey Tool (ft) (ft) 100.00 6,850.00 Antigua #1 MVVD MWp • 12 April, 2006 - 7:00 Page 4 of 5 COMPASS ConocoPhillips Alaska (Kuparuk) HALLIIE-~tJRTORI Kuparuk River Unit North Reference Sheet for Kuparuk River Unit Non Pad -Plan Antigua #1 -Plan Antigua #1 Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 using datum NAD 1927 (NADCON CONUS), ellipsoid Clarke 1866 Projection method is Transverse Mercator (Gauss-Kruger) Central Meridian is -150.00°, Longitude Origin:0.00°, Latitude Origin:0.00° False Easting: 500,000.OOft, False Northing: O.OOft, Scale Reduction: 0.99990389 Grid Coordinates of Well: 5,915,642.12, 558,553.73 Geographical Coordinates of Well: 70° 10' 48.48" N, 149° 31' 42.70" W Grid Convergence at Surtace is: 0.4436° Magnetic Convergence at surface is: -23.6500° (4 April 2006, , 8GGM2005) T Magnetic Model: -BGGM2005 .Date: 04-Apr-06 Declination: 24.0925° Inclination/Dip: 80.7:141 ° Field Strength: 57558 • • Grid North is 0.4436° East of True North (Grid Convergence) `° Magnetic North is 24.0925° East of True North (Magnetic Declinatio Magnetic North is 23.6489° East of Grid North'(Magnetic Convergen To convert a True Direction to a Grid_Djrection, Subtract 0.4436° To convert a Magnetic Direction to a True Direction, Add 24.0.925 To convert a Magnetic Direction to a Grid Direction, Add 23.6489' 72 April, 2006 - 7:00 Page 5 of 5 COMPASS 1 ~~~~oG-vlq iHalliburton Company Survey Report n~[-i~ ~I~'i~lE Company: ConocoPhillips Alaska Ina __ Date: 5/10/2006 Timc: 09.25:53 Page: F'~eld: Exploratiori2006 Co-ordiuate(NE) Reference: We ll: Antigua #1, Tr ue North i Sitei Antigua Vertical (TVD) Refer ence: Ant igua#1; 130.8 ~ R'c)1: - Antigua #1 Section (VS) Referen eec We ll'(OOON,O:OOE,O.OOAzi) I Wellpath: Antigua #1 _ .. _ _ __ _ - Survey C:rleulation ~ _ _- 1ctluxl: Minimum Curvature --- - - - _.. Db: Oracle - -- __ _ 1 -_ Field: Exploration 2006 Map System:US State Pl ane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Well Centre Sys Datum: Mean Sea Level Geomagnetic Mo del: bggm2005 Well: Antigua #1 Slot Name: Well Position: +N/- S 0.00 ft Northing: 5915642.12 ft Latitude: 70 10 48.476 N +E/- W 0.00 ft Easting : 558553.73 ft Longitude: 149 31 42.704 W Position Uncertainty: 0.00 ft Wellpath: Antigua #1 Drilled From: Well Ref. Point 500292329900 Tie-on Depth: 20.00 ft Current Datum: Antigua#1: Height 130.80 ft Above System Datum: Mean Sea Level Magnetic Data: 3/27/2006 Declination: 24.10 deg Field Strength: 57559 nT Mag Dip Angle: 80.71 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direct ion ft ft ft deg 20.00 0.00 0.00 0.00 Survey Program for Defi nitive Wellpath '~ Date: 3/21/2006 Validated: N o Version: 1 ' Actual From To Survey Toolcode Tool Name ft ft __ _ 100.00 6731.71 Antigua #1 (100.00-6731 .71) MWD MWD -Standard Survey _ ~i _ l1D Incl _ ~zim TVD Svs"IVU _ N/5 F/~V MapN MapE Tool ft deg deg ft ft ft ft ft ft 20.00 0.00 0.00 20.00 -110.80 0.00 0.00 5915642.12 558553.73 TIE LINE 100.00 0.00 0.00 100.00 -30.80 0.00 0.00 5915642.12 558553.73 MWD 141.00 0.19 61.51 141.00 10.20 0.03 0.06 5915642.15 558553.79 MWD 239.00 0.26 77.31 239.00 108.20 0.16 0.42 5915642.28 558554.15 MWD 331.00 0.19 89.86 331.00 200.20 0.21 0.78 5915642.33 558554.50 MWD 422.60 0.14 59.82 422.60 291.80 0.26 1.02 5915642.39 558554.75 MWD 518.40 0.25 101.44 518.40 387.60 0.28 1.33 5915642.41 558555.06 MWD i 608.82 0.22 48.77 608.82 478.02 0.35 1.65 5915642.49 558555.38 MWD 701.32 0.17 60.69 701.32 570.52 0.54 1.91 5915642.67 558555.63 MWD 794.69 0.12 30.16 794.69 663.89 0.69 2.0$ 5915642.83 558555.80 MWD 887.18 0.22 75.38 887.18 756.38 0.82 2.30 5915642.96 558556.02 MWD i 978.60 0.20 121.40 978.60 847.80 0.78 2.60 5915642.92 558556.33 MWD 1073.53 0.28 128.77 1073.52 942.72 0.55 2.93 5915642.69 558556.65 MWD 1165.72 0.22 136.99 1165.71 1034.91 0.28 3.22 5915642.42 558556.95 MWD 1261.41 0.38 145.92 1261.40 1130.60 -0.12 3.53 5915642.03 558557.26 MWD 1359.10 0.37 165.65 1359.09 1228.29 -0.69 3.79 5915641.46 558557.52 MWD 1453.45 0.44 158.47 1453.44 1322.64 -1.32 3.99 5915640.83 558557.73 MWD 1547.04 0.67 155.33 1547.02 1416.22 -2.16 4.35 5915640.00 558558.10 MWD 1643.50 0.64 155.65 1643.48 1512.68 -3.16 4.81 5915639.00 558558.57. MWD 1739.30 0.63 190.14 1739.27 1608.47 -4.17 4.94 5915637.99 558558.70 MWD 1836.00 0.70 172.18 1835.96 1705.16 -5.27 4.93 5915636.88 558558.70 MWD I 19 0.82 1931 173.45 1931.15 1800.35 -6.53 5.08 5915635.63 558558.86 MWD . 17 0.72 2025 181.79 2025.12 1894.32 -7.78 5.14 5915634.38 558558.93 MWD . 67 0.69 2119 181.69 2119.61 1988.81 -8.95 5.11 5915633.21 558558.90 MWD . 2215.51 0.80 183.32 2215.44 2084.64 -10.19 5.05 5915631.97 558558.86 MWD 41 1.10 2309 184.66 2309.33 2178.53 -11.74 4.94 5915630.42 558558.76 MWD . 96 1.17 2403 185.96 2403.86 2273.06 -13.61 4.77 5915628.55 558558.60 MWD i . 97 1.31 2498 184.38 2498.85 2368.05 -15.66 4.58 5915626.50 558558.43 MWD . 58 1.13 2595 189.18 2595.44 2464.64 -17.70 4.35 5915624.46 558558.21 MWD . 2691.53 1.21 194.73 2691.37 2560.57 -19.61 3.94 5915622.54 558557.82 MWD Halliburton Company ' Survey Report Comp~n~°: ConocoPhillips Alaska Inc. Date: 5/10/2006 Time: 09 :25;53 Nhg~: 2 Field: Ex ploration 2006 C o-ordinate(NE,) Reference: Well: Antigua #1, T rue North Sile; An tigua V ertic al (TVD) Refe rence: Antig ua#1 130.8 V1~d1: An tigua #1 Sectio n(VS) Referen ce:. Well (QOON,O. OOE OApAzl} ~i'ellpatlf: An tigua.#1 Survcy~{,~Icul'ation Method: Minim um Curvature D'b. Oracle Survey `MD .Ind Azim f~'D SysT~' D- N/S E/W A1apN niap>; Cool i ft deg deg ft ft ft ft ft ft 2787.08 1.15 196 .11 2786 .90 2656 .10 -21 .51 3.41 5915620. 64 558557 .31 MWD 2884.01 1.06 196 .06 2883 :81 2753 .01. -23 .31 2.90 5915618. 84 558556. 81 MWD 2980.05 0.79 190 .05 2979. 84 2849 .04 -24 .81 2.53 5915617. 33 558556. 46 MWD 3076.15 0.70 185 .02 3075. 93 2945 .13 -26 .05 2.37 5915616. 09 558556. 30 MWD 3169.03 0.69 155 .23 3168. 80 3038 .00 -27 .12 2.55 5915615. 02 558556. 49 MWD 3263.90 0.67 139 .80 3263. 66 3132 .86 -28 .06 3.15 5915614. 08 558557. 10 MWD 3361.23 0.39 143 .78 3360. 99 3230 .19 -28 .77 3.71 5915613. 39 558557. 66 MWD 3455.18 0.20 174 .37 3454 .94 3324 .14 -29 .19 3.92 5915612. 97 558557. 87 MWD 3551.69 0.31 203 .32 3551 .45 3420 .65 -29 .59 3.83 5915612. 56 558557. 79 MWD 3647.23 0.45 209 .07 3646. 99 3516 .19 -30 .16 3.55 5915611. 99 558557. 51 MWD 3742.37 0.41 206 .74 3742. 12 3611 .32 -30 .79 3.21 5915611. 36 558557. 18 MWD 3836.46 0.33 202 .40 3836. 21 3705 .41 -31 .34 2.96 5915610. 81 558556. 93 MWD 3930.24 0.37 177 .40 3929. 99 3799 .19 -31 .89 2.87 5915610. 25 558556. 84 MWD 3981.35 0.39 174 .34 3981. 10 3850 .30 -32 .23 2.89 5915609. 92 558556. 87 MWD 4092.56 0.38 176 .62 4092. 31 3961 .51 -32 .98 2.95 5915609. 17 558556. 94 MWD 4154.76 0.40 172 .40 4154 .51 4023 .71 -33 .40 2.99 5915608. 75 558556. 98 MWD 4241.13 0.38 167 .79 4240 .87 4110 .07 -33 .98 3.09 5915608. 17 558557. 09 MWD i 4342.21 0.39 166 .94 4341. 95 4211 .15 -34 .64 3.24 5915607. 51 558557. 24 MWD 4438.77 0.37 172 .35 4438. 51 4307 .71 -35 .27 3.36 5915606. 88 558557. 36 MWD 4536.88 0.31 189 .41 4536. 62 4405 .82 -35 .84 3.36 5915606. 31 558557. 36 MWD I 4628.19 0.22 184 .42 4627. 93 4497 .13 -36 .26 3.30 5915605. 89 558557. 31 MWD I 4727.71 0.25 200 .84 4727. 45 4596 .65 -36 .65 3.21 5915605. 49 558557. 22 MWD 4822.66 0.36 226 .79 4822. 39 4691 .59 -37 .05 2.92 5915605. 09 558556. 94 MWD 4918.02 0.53 220 .07 4917. 75 4786 .95 -37 .60 2.42 5915604. 55 558556. 44 MWD ', 5009.82 0.57 227 .26 5009. 55 4878 .75 -38 .23 1.81 5915603. 91 558555. 83 MWD Il 5106.32 0.57 230 .27 5106 .04 4975 .24 -38 .86 1.09 5915603. 27 558555. 12 MWD 5202.74 0.62 237 .66 5202 .46 5071 .66 -39 .45 0.28 5915602. 68 558554. 31 MWD ~' 5299.34 0.70 244 .61 5299 .05 5168 .25 -39 .98 -0.70 5915602. 14 558553. 34 MWD 5394.99 0.68 249 .01 5394 .69 5263 .89 -40 .43 -1.76 5915601. 68 558552. 29 MWD 5490.19 0.57 254 .97 5489 .89 5359 .09 -40 .76 -2.74 5915601. 34 558551. 31 MWD 5591.19 0.47 248 .08 5590 .88 5460 .08 -41 .04 -3.61 5915601. 05 558550. 44 MWD 5682.91 0.53 246 .20 5682 .60 5551 .80 -41 .36 -4.35 5915600. 73 558549. 70 MWD 5780.55 0.53 249 .75 5780 .24 5649 .44 -41 .70 -5.18 5915600. 39 558548. 87 MWD 5875.49 0.58 256 .73 5875 .17 5744 .37 -41 .96 -6.06 5915600. 12 558547. 99 MWD ', 5968.14 0.55 263 .11 .5967 .82 5837 .02 -42 .12 -6.96 5915599. 95 558547. 10 MWD 6063.60 0.69 265 .23 6063 .27 5932 .47 -42 .22 -7.99 5915599. 84 558546. 07 MWD 6159.44 0.61 263 .36 6159 .11 6028 .31 -42 .33 -9.07 5915599. 73 558544. 99 MWD 6259.79 0.62 265 .26 6259 .45 6128 .65 -42 .43 -10.14 5915599. 61 558543. 92 MWD 6354.16 0.53 273 .91 6353 .81 6223 .01 -42 .45 -11.09 5915599. 59 558542. 97 MWD ', 6451.20 0.50 283 .04 6450 .85 6320 .05 -42 .32 -11.95 5915599. 71 558542. 11 MWD 6543.32 0.50 287 .71 6542 .97 6412 .17 -42 .11 -12.72 5915599. 92 558541. 34 MWD 6637.41 0.45 285 .73 6637 .05 6506 .25 -41 .88 -13.47 5915600. 14 558540. 59 MWD 6731.71 0.51 286 .18 6731 .35 6600 .55 -41 .67 -14.23 5915600. 35 558539. 83 MWD 6850.00 0.51 286 .18 6849 .64 6718 .84 -41 .37 -15.24 5915600. 63 558538. 81 PROJECTED to TD • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission ~--, TO: Jim Regg, }~;~t~~ ~ f ~ J~ ~ DATE: April 21, 2006 P. I. Supervisor ~ FROM: Chuck Scheve, SUBJECT: Surface Abandonment Petroleum Inspector Antigua #1 PTD # ~o I G dy,~~csa$ 2•-- 06 ~9. --__ Friday, April 21,2006: I traveled to the Conoco Phillips Antigua #1 exploratory location to inspect the casing cut off and abandonment of this well. All casing strings were cut off at approximately 4' below original ground level and all were found to be full of cement. A 3/4" thick marker plate was welded to the conductor casing with the required information bead welded to it. SUMMARY: I inspected the casing cut off depth, and the P&A marker plate on the Antigua #1found all to be in order. Attachments: Antigua #1 plate.JPG Antigua #1 cut off.JPG o~~~ $~F 3 ~ 2008 • • Antigua #1 (ConocoPhillips) Surface Abandonment Inspection Photos from Chuck Scheve, AOGCC April 21, 2006 a.,_ = im v ~~ ~} X ~ ~ ~ f ~ Y ~ ~ ~ a ~iY ~ ~ , ~~ - 9" y~ 9 .* h~' ~~~f~..~ F p~ . L. y i L.w - ~ ~l -* - f ._ $ ~ '~~ y . cti ~ Skr r,r~ ~ _~e" " ~ ~~ ~ ~ ~ ,~ `~ ~~ 1 I I - ~ .s ~`} ~~ .i '= ..~.. Y Casing Cut-off Marker Plate ~~ ~ .: ~: ~ vN 1: nti • • ~.., f ~ _ y 6, -- .- ~` ~, w d °-~_ta! ~+c ~ *~ ~ ~ [.~ .r t. -e m,, 4:.._ - ~ rW~F-~.~ Ali' _,1f 9 ". .._ ~ c -~-~ ~./ a~3.~~e-~.. ..';mil '?:''. _ ~ir¢~'~C-'ie..~~ ~'. _ ~ .~ r. 1 yy ~: P, ylvr y h` J~ ,~i ~ ~~ ~' ,i a , ~'p'~l ~i T.T~~ _.~ " • • s • .. _. _ .w~ . ... _ a: .,a,.,,_.,., • • ConocoPhillips Alaska ~ Antigua 1 KRU.~~' Alaska ~ ~3 core [~~ S'iiGl.-iih SEAY1Gf2 Rotary Sidewall Core Inventory File No.: HOU-060338 Date: April 20, 2006 Sample No Depth ft Length inches Suitable for Plu Anal sis Gas Det Litholo Remarks 1 6620.0 0.7 No 0 Sst Soft fra ment 2 6621.0 1.0 No 16 Sst Broken-vertical) fractured 3 6622.0 1.8 Yes 185 Sst 2 feces 4 6623.0 0.2 No 7 Sst Small fra ment onl 5 6625.0 0.7 No 8 Sst Fra ments onl 6 6627.0 2.0 Yes 37 Sst 2 feces 7 6628.0 1.5 Yes 23 Sst 8 6629.0 1.8 Yes 0 Sst 9 6631.0 1.7 Yes 282 Sst 2 feces, stron h drocarbon odor 10 6632.0 0.3 No 0 Sst Fra ments onl 11 6633.0 0.3 No 0 Sst Fra merits onl 12 6634.0 1.7 No 6 Sst Several fra merits & small feces 13 6637.0 1.8 Yes 0 Sst 2 feces 14 6640.0 1.5 Yes 6 Sst sh 2 feces 15 6641.0 1.6 Yes 15 Sst sh 16 6642.0 1.8 Yes 5 Sst 17 6660.5 0.3 No 25 Shale Fra merits onl 18 6672.0 1.7 Yes 0 Sst sh 19 6675.0 0.8 Yes 4 Sst sh short 20 6693.0 0.7 No 2 Shale Fra merits onl 21 6694.0 1.5 Yes 83 Sst vsh 22 6697.5 0.6 No 69 Shale Fractured Page 1 Rotary Core Descriptions Well Name: Antigua 1 Formation: Kuparuk C, B and A Geologist: Curtis Goddard Date: 73-Apr-2006 (cm.) # Depth Length Condition Show/Cut Flour. Est. ~ Desc Grn. Size Grn.Type Rel °~ BedForms Hvy Oil/Tar Comments shattered n/a dull gold 8 to 12 andstone, drk grn gry, qtz, glauc, sid Ivf - umed gtz/glaudlith 40% glauG25 % sid none observed frets to CoreLab Houston TX 1 8620 occ. s ots and fines in ores v hard fra , 2 6621 broken no sample to describe to CoreLab, Houston TX 3 6622 good no sample to describe to CoreLab, Houston TX 4 8623 1/4 Partial no sample to describe to CoreLab, Houston TX good no sample to describe frozen -sent to Baseline DGSI for 5 6624 fluid extracts shattered n/a dull gold 5 to10 an s one, gry, q , some g auc, tr Ivf-Ifine q~ lith frag/ 90% qtz, 7 % lith, 3% none observed trace to CoreLab Houston TX 6 6625 occ. s ots sid in ores, hard, cla matnc; shale taut taut , good n/a dull gold 5 to10 an s one, gry, q , some g auc, r Ivf-Ifine 9ti lith hag/ 90% qtz, 7% lith, 3% none observed trace frozen -sent to Baseline DGSI for 7 6626 occ. s ols sid in ores, hard, cla matnc; shale taut taut fluid extracts 8 6627 good no sample to describe to CoreLab, Houston TX 9 6628 good no sample to describe to CoreLab, Houston TX 10 6629 good no sample to describe to CoreLab, Houston TX good no sample to describe frozen -sent to Baseline DGSI for 11 6630 fluid extracts 12 6631 good no sample to describe to CoreLab, Houston TX 13 6832 shattered no sample to describe to CoreLab, Houston TX 14 6633 shattered no sample to describe to CoreLab, Houston TX good n/a brt yellow c10 an s one, gry, q r g auc, inn. Ivf-Ifine qti lith frag/ >90% qtz, lith, V none observed trace to CoreLab Houston TX 15 6634 oc .sots cla matnc taut taut , good no sample to describe frozen -sent to Baseline DGSI for 16 6635 fluid extracts good n/a brt yellow <10 an s one, gry, q r g auc, inn. Ivf-Ifne q~ lith frag/ >90 % qtz, lith, tr none observed trace to CoreLab Houston TX 17 6637 tr. s ots cla matnc tau taut , good n/a brt yellow c10 an s one, gry, q g auc, irm, Ivf-Ifne q~ lith frag/ >90% qtz, lith, tr none observed trace frozen -sent to Baseline DGSI for 18 6639 tr. s ots cla matrx taut taut fluid extracts good n/a no c1p an s one, gry, q r g auc, vm, Ivf-Ifine q~ lith frag/ >90% qtz, lith, tr none observed none to CoreLab Houston TX 19 6640 cla malrx taut taut , 20 6641 good no sample to describe to CoreLab, Houston TX good n/a no c10 an s one, gry, q r g auc, vm, Ivf-Ifine qti lith frag/ >90% qtz, lith, tr none observed none to CoreLab Houston TX 21 6842 cla matnc taut taut , 22 8848 sample not recovered not recovered 23 6852 sample not recovered not recovered 24 6657.5 sample not recovered not reoevered 25 6660.5 shattered no sample to describe to CoreLab, Houston TX good n/a no n/a Shale drk gry blky hard clay n/a 100% shale thin none to CoreLab Houston TX 28 6672 , , , laminations , 27 6675 fair n/a no n/a Shale, drk gry, blky, hard clay n/a 100% shale thin I minations none to CoreLab, Houston TX fair n/a no c10 Shale, drk gry, blky hard; Sandstone, Ivf-uvf qtz lith frag 90 % shale 10 % ss thin none to CoreLab Houston TX 28 6693 med lith fra fines cmt , , amin tions , 29 8894 good no sample to describe to CoreLab, Houston TX 30 6897.5 good no sample to describe to CoreLab, Houston TX • • Note: The petrophysicist on site would not allow me to take shavings off the sidewall cores for descriptions. The descriptions here were from cores where a small portion fell off when they were moved from the core tube to the aluminum foil wrap and individual sample jars. All the cores were wvered/caked in drilling mud and the lithology could not be determined without samples. • ConocoPhillips Antigua 1-Actual P8cA Procedure Confidential Sub-Surface Abandonment: • 1. (04/14/06) Cement Plug #1 -Spotted 37.50 bbls of 15.8 ppg, Class G Cement from TD @ 6,850' MD to 6,420' MD (approximately 200' above top Kuparuk at 6,620' MD). Plug length is approximately 430' based on 25% excess. Cement plug was layed directly on bottom, therefore no tag was required. Note: Opportunity to witness was waived by AOGCC. 2. (04/14/06) Cement Plug #2 -Set Baker Cement Retainer at 3,969' MD (75' above the 9-5/8" casing shoe). Weight tested Cement Retainer to 50K. Pumped 18.5 bbls of 15.8 ppg, Class G Cement (N14.5 bbls below retainer / X4.0 bbls on top of retainer). PU to 3,835' and pressure tested plug to 1,000 psi for 10 minutes. Note: Operation was witnessed by John Spaulding w/ AOGCC. Note: A sufficient volume of cement was pumped through the retainer to extend 175' below (75' of casing volume plus 100' of open holed and 50' of cement was layed on tog of the retainer. Open hole volume based on 25% excess. 3. (04/15/06) Cement Plug #3 -Spotted 22.0 bbls of 15.8 ppg, Class G Cement from 300' MD to Surface. To prevent the plug from running down hole, a 9-5/8"wiper plug was pushed down hole to 317' MD prior to spotting cement. Note: Oooortunity to witness was waived by AOGCC. Note: 10.2 ppg kill weight mud was left between cement plugs. Surface Abandonment: 1. (04/20/06) Excavated conductor and 9-5/8" casing. 2. (04/21/06) Removed wellhead. Cut off conductor and 9-5/8" casing 5 feet below ground level. 3. (04/21/06) Cemented 9-5/8" casing to top of casing stub (six inches) with SWS ASi. Note: Cement top was witnessed by Chuck Sheve w/ AOGCC. 4. (04/21/06) Welded 18" cover plate over all casing strings with the following information bead welded into the top: CONOCOPHILLIPS ALASKA, INC ANTIGUA #1 PTD# 206-019 API# 50-029-23299-00 5. (04/22/06) Buried conductor and 9-5/8" casing with soils removed from the excavation and conductor setting process. Cleaned /Bladed ice pad and demobilized equipment. CPAI Environmental Specialist (Chris Brown) performed a final walk around. Note: Abandonment Complete /Pad Closed. MAC 04/24/06 • • ConocoPhillips Antigua #1 (Permit # 206-019) Weekly AOGCC Report 04/03/06 03/24/06 (12:00) Rig released from Pioneer's Cronus Location and began mobilization to CPAI Antigua #1 Location 03/29/06 (17:30) Diverter /Accumulator test performed and witnessed by Chuck Scheve 03/30/06 (20:00) Spudded Antigua #1 03/31/06 Drilled from 211' MD to 1395' MD 04/01/06 Drilled from 1395' MD to 1524' MD Performed short trip - 4378 units gas @ btms up /mud wt gas cut by .5 ppg (Ci f/Coal @ ~1470~ Drilled from 1524' MD to 2347' MD 04/02/06 Drilled from 2347' MD to 2505' MD Performed short trip to 1500' MD -Tight from 1560' to 1640', 2050', 2260' Drilled from 2505' MD to 3302' MD We are currently drilling ahead a(~ +/- 3800' MD/TVD. Expect to TD 12-1/4" Surface Hole tonioht. Expect to run and cement 9-5/8"Surface Casing tomorrow morning. Weekly AOGCC Report 04/10/06 04/03/06 Drilled from 3302' MD to 3493' MD Performed short trip to 2500' MD -Tight at 3075' Drilled from 3493' MD to 4053' MD (TD Surface Hole) Circulate and condition mud 04/04/06 Performed short trip to 1100' MD -Tight at 3400' Circulate and condition mud POOH to run 9-5/8" casing Begin running 9-5/8" casing 04/05/06 Run /Cement 9-5/8" casing at 4044' MD (Full Returns, Bumped Plug, Floats Held) ND Diverter 1~~ ~` ~~ 04/06/06 NU BOPE and Test (Witness Waived by John Crisp) ~,~-Mc~c~L~St~~~T~~~3 04/07/06 Continue NU BOPE and Test ~~ ~(~ ~ PU 8-1/2" BHA, RIH and cleanout to Float Collar 04/08/06 RU Dowell to perform CIT /LOT Pressure Test 9-5/8" casing to 2500 psi for 30 min (Test OK) Drill out Float Equipment and 20' New Hole from 4053' MD to 4073' MD Displaced well with 9.4 ppg mud Performed 15.8 ppg EMW LOT Drilled from 4073' MD to 4822' MD 04/09/06 Drilled from 4822' MD to 5014' MD Performed short trip to 9-5/8" casing shoe - 10 to 20K intermittent drag (some swabbing) Dri-led from 5014' MD to 5622' MD We are currently drillino ahead Cal +/- 6075' MD/TVD. • • Weekly AOGCC Report 04/17/06 04/10/06 Drilled from 5622' MD to 6291' MD Performed short trip to 5014' MD -Pulled slick Drilled from 6291' MD to 6323' MD 04/11/06 Drilled from 6323' MD to 6535' MD Performed 13.0 ppg EMW FIT Drilled from 6535' MD to 6850' MD / TVD (Well TD) Performed short trip to 6185' MD -Pulled slick POOH to run logs 04/12/06 Continue POOH to run logs RU Schlumberger and attempt to run Sonic Log Unable to get below 4841' MD PU 8-1/2"cleanout assembly, RIH and cleanout to TD 04/13/06 Continue w/ cleanout run to 6850' MD RU Schlumberger and log -Sonic Tool and Rotary Sidewall Coring Tool (Successful) Prep to P&A. 04/14/06 RIH and lay 37.5 bbl cement plug on bottom isolating Kuparuk (Witness waived by AOGCC) RIH and set cement retainer @ 3969' MD (75' above 9-5/8" Surface Casing Shoe), Set down 50K on retainer, pumped 18.5 bbls cement total leaving 50' on top of retainer, PU to 3835' and pressure tested retainer to 1000 psi (Witnessed by John Spaulding) 04/15/06 Push 9-5/8"wiper plug to 317' and lay cement plug from wiper plug to surface (pumped 22 bbls total) Begin ND BOPE in preparation for rig move. 04/16/06 Release rig @ 24:00 hrs (04/16/06) • ~ ~ ~y 1 ~ 7 r.~f ~dd ~i ~ ;sJ ~ , ALASSA OIL A1~TD GAS COI~TSERQATIOiQ CODiDII5SIOIQ Paul Mazzolini Exploration Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Exploratory, Antigua 1 Sundry Number: 306-138 Dear Mr. Mazzolini: Y! I~ FRANK H. MURKOWSKI, GOVERNOR 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 ,f PHONE (907) 279-1433 FAX (907) 276-7542 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. DATED thi~~ day of April, 2006 Encl. Sincerelv. • ConocoPhillips April 12, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Paul Mazzolini Cook Inlet Exploration Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 P!I;.O ~, ~ ~~ ~~ °'~t ~ ~ ~ .., s,, r Subject: Application for Sundry Approval for Antigua 1 (206-019) '`~°<`. Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the upcoming plug and abandon operations of the exploration well Antigua 1. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). By submitting this data in compliance with the regulatory data submission requirements, ConocoPhillips Alaska, Inc. is not agreeing or acquiescing to the potential future application of the provisions of AS 31.05.035(c) and 20 AAC 25.537(d) that might allow the data to be disclosed to the public after the initial 24 month confidentiality period. ConocoPhillips Alaska, Inc. reserves all rights to dispute or appeal any attempt to apply those provisions to this data in the future. If you have any questions regarding this matter, please contact me at 263-4603 or Mark Chambers at 265-1319. Sincerely, y~'~~ G~~G~t. f ' ~ s`1/Js~ft' Li/11~>/Z~ .~viz,P%3u~ n/f~~~/cJl P. Mazzolini Cook Inlet/Exploration Drilling Team Leader CPAI Drilling PM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~'~~ ~ ~ ~~~~ 20 AAC 25.280 APPLICATION FOR SUNDRY APPROV~10~Isa ~~ 1s ores. commission Al~l~~or~tr~ 1. Type of Request: gbandon ~ ^ ' Sus end ^ O rational shutdown p pe ^ Perforate ^ Waiver Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ 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 ~ ~ 206-019 " 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23299-00 7. KB Elevation (ft): 9. Well Name and Number: 20' RKB Anti ua 1 8. Property Designation: 10. Field/Pools(s): ADL 390484 ~ Ex lorato ` 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured) Junk (measured): 6850' 6850' ' Casing Length Size MD ND Burst Collapse Structural Conductor 80' 16" 100' ~ 100' Surface 4024' 9-5/8" 4044' ~ 4044' Intermediate Production Liner Perforation Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None None None Packers and SSSV Type: Packers and SSSV MD (ft): None None 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^~ ~ Development ^ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/12/2006 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 Mark Chambers Ccil 265-1319 Printed Name Paul Mazzolini Title Exploration Drilling Team Leader Signature ~~ Phone 263-4603 Date oy`" /'L~C~~ ~' S ~ 2 ~~/,~j COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ..- Plug Integrity BOP Test ^ TTTT~~~ Mechanical Integrity Test ^ Location Clearance ` ~ ~, ~ ~ ~ ~gn ;` t~~1D1Yle~ p~Y olf'i~. App j 4 Z~~s G ~..`> G s,1 ~ Other: ~G.rc.. 'e~c~ t°Ca C.~.~ ~~C;.E.CIv ~. Subsequent Form Required: ~© ~ APPROVED BY 3 ~~ Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 7/2005 O~NAL 4~ /3 alb ~l~a~ BMIT IN DUPLICATE ~tigua #1 Proposed P&A Schematic Exploration Well -Confidential jA~dic Fox - 20' RKB~ • ~- ConocoPhillips =: C~E;11~Eflt 10.2 PPG LSND Mud Ceir~erit ~Pa3'IeTJ~ 8-1/2" Open Hole 10.2 PPG LSND Mud Kl 6,560' MD Top Kuparuk 6,620' MD Base Kuparuk 6,700' MD Ceri~erit Conductor (80'): 16", 62.58# Set @ +/- 100' MD / 100' TVD Float Collar: Weatherford -Single Valve 9-5/8" 32-53# BTC Box x Pin (2) Joints Casing: 9-5/8" 40# L-80 BTC Float Shoe: Weatherford -Single Valve 9-5/8" 32-53# BTC Box Up Surface Casing 9-5/8" 40# L-80 BTC Set @ +/- 4,044' MD / 4,044' TVD Below Base W. Sak TD Cal 6,$~0' MD / 6.850' TVD ' 300' Cement Plug set from Surface to 300' MD 140 Sacks Arctic Set 1 Slurry Weight 15.7 ppg Slurry Yield 0.93 cu-ft/sk Thickening Time 2.5 Hrs C-,CxvSCL v O r~ o~t~ ~~ l `~ 225' Cement Pluo set from 3,919' MD to 4,144' MD (50' Above and 175' Below Baker K-1 Cement Retainer) Cement Retainer set @ 3,969' MD (75' Above Casing Shoe) 90 Sacks Class G + Additives Slurry Weight 15.8 ppg Slurry Yield 1.17 cu-ft/sk Thickening Time 3.0 Hrs `~;~; z"'~J1i ~ 430' Cement Plug set from TD to +~- 6 420' MD (Top Cement Planned @ 200' MD Above Top Kuparuk Plan to set Cement Plug in 1 Staoe 180 Sacks Class G + Additives Slurry Weight 15.8 ppg Slurry Yield 1.17 cu-ft/sk Thickening Time 3.5 Hrs Cement Volume Based on 25% Excess Antigua #1 P&A Schematic prepared by Mark Chambers 04/12/06 • • ConocoPhillips Antigua 1-Proposed P&A Procedure Confidential 1. Notify AOGCC 24 hours in advance of all well abandonment operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. MIRU D/S for well P&A operations. 3. Cement Plug #i -Spot cement from TD @ 6,850' MD to 6,420' MD (approx. 200' above top of the Kuparuk at estimated 6,620' MD). Plug length is approximately 43'~0~',and plannedrfor -~ one stage 1"~ '~SS> ~~~ ~~ ~EC.~.SSCar~.r ~~:ti'. LCe? ~~U~~~~C.~.i~~Z tS ~~~ .~ r~ Note: Cement Plug #1 will be laid on bottom and does nllot require a tag. ~~~.~-~ ~--~ ~ \ v~ 4. Cement Plug #2 -Set Baker Ki Cement Retainer. Pump sufficient cement through the retainer to extend 175' below (75' of casing volume plus 100' of open hole) and lay a 50' ~.^ d-~~~f cement cap on top of the retainer. Weight test retainer before pumping cement. Leave 10.2 ~t ~ ppg mud above and below the plug (Weight of mud needed to TD the hole). Pressure test r plug to 1500 psi for 30 minutes. .,_..:~ C~~~.~C~,C_~.~~.,,c~~ C.4, -~C., ;~~~<~C~t~ .~ ,~,~~C-r~~SS C~~~~ C 5. Cement Plug #3 - Spot a balanced Arctic Set 1 cement plug from 300' to surface. Note: To prevent pluo from runnino down hole plan to spot cement on top of wiper plus. 6. RDMO D/S. 7. Remove wellhead and cut all casing strings at 3 feet below ground level. ,~~ ~~ //''~~ ----~f C~e~~ C~C~ ~~y~Cc { e::GZ ~ '~N ~~ +~re„SS ~•:r't't?~~"' 8. Weld cover plate (at least 18" in diameter) over all casing strings with the following information bead welded into the top: CONOCOPHILLIPS ALASKA, INC ANTIGUA #1 PTD# 206-019 API# 50-029-23299-00 Remove cellar. Back fill cellar with gravel as needed. Back fill remaining hole to ground level with gravel, Clear ice pad location and demob all materials and equipment. ~o ~v.~ c~ ~~.. ~~r,P ~c~ c~~~ ~,~_ S ~ ~-~~-E.~ _, ~,~C MAC 04/11/06 ConocoPhillips Alaska, Inc. Bayview Geological Facility 619 East Ship Creek Ave., Suite 102 Anchorage, AK 99510 phone 907.263.4859 SAMPLE TRANSMITTAL TO: AOGCC 333 WEST 7TH ANCHORAGE, AK. OPERATOR: CPAI DATE: MARCH 18, 2006 AIR BILL: AL 5325486 CPBV: 06-04-18-03 CHARGE CODE: 10103115 NAME: ANTIGUA 1 SAMPLE TYPE: DRY SAMPLES SENT: DRY SET 120'-6850' SENT BY: D.L.PRZYWOJSKI API NO: 500292329900 NUMBER OF BOXES: 6 ~ ~aoz UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: CPA BAYVIEW GEOLOGICAL FACILITY 619 EAST SHIP CREEK AVE SUITE 102 ANCHORAGE, AK. 99510 ATTN: DAN PRZYWOJSKI ABV100 RECEIVED: CC: AOGCC AOGCC A. ANDREOU CPAI ~~~-~~~ • • .. ~ ~ , ~ ~ ~ ;' ~'~ ~ i ; ~ ~ ~ ; FRANK H. MURKOWSKI, GOVERNOR ~~~~ ~~~~+r ~t~~ ~r ~~+ J AiIt1•-7~ OIL ~ ~ ~ 333 W. T" AVENUE, SUITE 100 CO1~T5ERQATIOI~T COl~'II-IISSIOI~T ;~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Mazzolini Cook Inlet/Exploration Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Antigua # 1 ConocoPhillips Alaska, Inc. Permit No: 206-019 Surface Location: 1770' FNL, 2358' FWL, SEC. 35, T10N, R10E, UM Bottomhole Location: 1770' FNL, 2358' FWL, SEC. 35, T10N, RlOE, UM Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. 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 use. Please note the following: 1. 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 first caught and 10' sample intervals through target zones. 2. Annular disposal of drilling wastes cannot be approved for this well until sufficient data is submitted via Form 10-403RD to ensure that the requirements of 20 AAC 25.080 are met. 3. Prior to this well being tested, those plans should be submitted to the Commission via Form 10-403. Permit No. 206-019 February 7, 2006 Page 2 of 2 Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager) . DATED this day of February, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ • FtE~El1/~D Ca~ocoPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360 Mark Chambers Phone: (907)265-1319 Fax: (907)265-1336 Email: Mark.A.Chambers(c~conocophillips.com January 27, 2006 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill: Antigua #1~Exploratory Test) Surface Location: Target 1 Location (Kuparuk C-Sand): Bottom Hole Location (Planned): Bottom Hole Location (Permitted): Dear Commissioner: 1770' FNL, 2358' FWL, 1770' FNL, 2358' FWL, 1770' FNL, 2358' FWL, 1770' FNL, 2358' FWL, FEB 0 2 2006 A{asks Oil & Gas Gons. Corrunission Anchorage Sec. 35, T10N, R10E, UM Sec. 35, T10N, R10E, UM Sec. 35, T10N, R10E, UM Sec. 35, T10N, R10E, UM ConocoPhillips Alaska, Inc. (CPAI) hereby applies for a Permit to Drill an onshore exploratory test well, the Antigua #1, from the location referenced above approximately 5.5 miles South of the Kuparuk River Unit's iJ-Pad. This well will be accessed via ice road originating from the gravel road to the North of 1J- Pad and drilled using the Doyon Arctic Fox. The Antigua #1 will be drilled as a straight hole and is designed to penetrate, evaluate and test the production potential of the objective sands. As indicated in the attachments, the proposed drilling program will entail drilling an 8-1/2" well bore through the objective with a full logging suite for evaluation. Elevated reservoir pressure in the objective sand is a possibility due to communication with 1J-Pad. Even though the probability of elevated pressure is very low, poor LOT results will force CPAI to top set the well with 7" intermediate casing and a 6-1/8" well bore will be drilled through the objective. A contingency completion schematic and cement program, outlining the top set option, have been attached for review. Based upon favorable log data, CPAI may decide to run production casing and test post-rig. However, no test is currently planned at this time. • • The proposed casing program will utilize 9 5/8" Surface Casing, 7" Production Casing and 3-1/2"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 (Doyon Arctic Fox) as required by 20 AAC 25.035 (a) (1) and (b). 5) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A well bore schematic is also attached visually depicting the proposed well. 6) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033, is attached in this APD package. 7) Seismic refraction or reflection analysis as required by 20 AAC 25.061(a) are attached in this APD package. 8) PHILLIPS does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the drilling rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Complete mud logging operations such as type log generation and sample catching are planned. The following are ConocoPhillip's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 2) Geologic Data and Logs Justine Boccanera, Geologist (20 AAC 25.071) 263-4236 The anticipated spud date for this well is March 01, 2006. If you have any questions or require further information, please contact Mark Chambers at (907) 265-1319 or Paul Mazzolini at (907) 263-4603 Sincerely, /~ Mark Chambers Sr. Exploration Drilling Engineer ConocoPhillips Alaska, Inc. cc: CONFIDENTIAL Antigua #1 Well File Paul Mazzolini ATO-1570 Tom Brasfield ATO-1550 Mark Chambers ATO-1566 Mike Morgan ATO-1438 STATE OF ALASKA ~ - .~~ ~l ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 REGEIVEC3~ ~~e o 2 zoos Alaska Oil & Gas Cana, Comrus3ion 1a. Type of Work: Drill / Redrill Re-entry ^ 1b. Current Well Class: Exploratory / Development Oil Multiple one ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 ' 11. Well Name and Number: Antigua #1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 7175' TVD: 7175' 12. Field/Pool(s): 4a. Location of Well (Governmental Section): Surface: 1770' FNL, 2358' FWL, Sec. 35, T10N, R10E, UM 7. Property Designation: a/Lt7cg` ~ AD4380C51~ 1'~"`~' Exploratory Top of Productive Horizon: 1770' FNL, 2358' FWL, Sec. 35, T10N, R10E, UM 8. Land Use Permit: ALK 13. Approximate Spud Date: 3/1!2006 Total Depth: 1770' FNL, 2358' FWL, Sec. 35, T10N, R10E, UM ~ 9. Acres in Property: 2560 14. Distance to~7,~r /ate Nearest Property: -~9~'-~,3~ j~E; 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558554 y- 5915643 `Zone- 4 10. KB Elevation (Height above GL): 20' RKB feet 15. Distance to Nearest Well within Pool: ,none 16. Deviated wells: Kickoff depth: 0 ft. Maximum Hole Angle: 0° deg 17. Maximum Anticipated Pressures in psig (see 2o.4AC 25.035) Downhole: psig ~?j(~, 5 ~ Surface: 2605 psig 18. Casing Program ifi ti S Setting Depth Quantity of Cement J~, Size ons pec ca Top Bottom ~ c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.58# K-55 Welded 80' 28' 28' 100' 100' Pre-installed 12.25" 9-5/8" 40# L-80 BTC 3985' 28' 28' 4005' ' 4005' 530 sx AS Lite, 270 sx DeepCRETE 8.5" 7" 26# L-80 BTCM 6855' 28' 28' 6875' ~ 6875' ~ 130 sx Class G 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (tt): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee Q BOP Sketch / Drilling Program ^ Time v. Depth Plot Shallow Hazard Analysis / Properly Plat ^ Diverter Sketch Q Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Chambers @ 265-1319 Printed Name Paul Mazzolini Title Cook Inlet/Exploration Drilling Team Leader a Signature 'Mr~ Phone ~,,3yl~(!~03 Date ~Z~62r~Zdblo P° r ha n All D k Commission Use Only Permit to Drill Number: ,~;~;~ "l_~r~ API Number: r~ 50-~-}~9- ~ ~ z.'7 ~~ ~.i~ Permit A proval Date: ~-"7fv~ See cover letter for other requirements Conditions of approval : ~~ ^~r-vii ~, ~~~~5 . Tr~S~~+`Cj'1~o~~c o-~E~r'~2~ ~Da~ "",~~~y~. S pies r wired i Yes [~ No ^ Mud log required Yes L~_I No ^ ; ydr sulfide measures Yes Q No ^ Directional survey required Yes ^ No ~'~ Other: © ~^ -,1.Kc/~c-~~~-f-rc:-n.. atz.r-~c?y~ P-Z~ ~~ ~ r-c~ i~~ APPROVED BY ~ .., ~ .r /'7 Approve THE COMMISSION Date: ~/ ..~G Form 10-401 Re 06/2004 ~ ~ ~ ~ ~ ~ ~ Submit in Duplicate ConocoPhillips Alaska, Inc. General Drilling Procedure 1. MIRU Doyon Arctic Fox over pre-installed 16" conductor casing. 2. NU Diverter and function test same. Notify_rggulatory agencies 48 hours prior to test. 3. PU Directional BHA and prepare to spud. 4. Spud well and drill 12-1/4" hole to surface casing point at +/- 4,005' MD / 4,005' TVD (N200' below Base W. Sak). ~- Run MWD /LWD logging tools in drill string as required for directional monitoring and formation data gathering. 5. Circulate and condition well bore. Perform short trip. POOH to run casing. 6. Run and cement 9-5/8", 40#, L-80, BTC Surface Casing to surface. Note: Light weight permafrost cement lead slurry and Dowell LiteCrete high compressive, lightweight tail slurry wilt be utilized 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. A Too ]ob mav~n,y~2erformed after consulting with the AOGCC. 7. ND Diverter System. NU and test ROPE. Notifv~ggulatory~gencies 48 hours gLior to test. 8. PU Directional BHA. RIH and cleanout to top of float equipment. 9. Pressure test casing to 2500 psi for 30 minutes. Notify regulatory agencies 48 hours orior to test. Note: Rewrd results and fax to town. 10. Drill out float equipment and 20' to 50' of new hole. 11. Perform LOT /FIT not to exceed 16.0 ppg EMW. Note: Record results and fax to town. 12. Drill 8-1/2" hole to below Base HRZ at +/- 6,565' MD / 6,565' TVD. Run MWD /LWD logging tools in drill string as required for directional monitoring and formation data gathering. 13. Perform LOT /FIT not to exceed 14.0 ppg EMW (Results will determine if Top Set is required). Note: Record results and fax to town. A Top Set will be required If the LOT is less than 12.5 nRg EMW. If a Ton Set is required -Plan to run 7" Intermediate Casing, drill 6-1/8" hole through the Production Interval and run 3-1/2" Production Liner. A contingency Completion Schematic and Cement Program, outlining the Top Set option, have been attached for review. 14. If no Ton Set is required, continue drilling 8-1/2" hole to TD at +/- 6,875' MD / 6,875' TVD (N200' below Base Kuparuk). Run MWD /LWD logging tools in drill string as required for directional monitoring and formation data gathering. 15. Circulate and wndition well bore. Perform short trip. POOH to run open hole Logs. 16. RU E-Line Unit. RIH and log well as required. RD E-Line Unit. 17. PU Drill Pipe Conveyed Logging Tools. RIH and log well as required. POOH and LD Drill Pipe Conveyed Logging Tools ,-1-.~• ~~-~-~ C~i~,,~~'~°~°~J~O'~"' Note: LQg reGults will determine plan to Comrllete Tem rarily~nend or P&A well bore. ~Z'~yy~ ConocoPhillips Alaska, Inc. 18. PU 8-1/2" cleanout assembly and RIH to TD. 19. Circulate and condition well bore. Perform short trip. POOH to run casing. 20. Run and cement 7", 26#, L-80, BTC Production Casing. 21. RIH-with cleanout Bit and Casing Scraper. Gean out to top of cement and displace well to seawater or kill weight brine. 22. RU E-Line Unit. RIM awd c:6~d.~ (USIT). RD E-lane Unit. 23. RU and tes# casing to 3000 psi for 30 minutes. Notify regulatory agencies 48 hours prior to test. Note: Record results and fax to town. 24. PU and RIH with 3-1/2", 9.3#, L-80, EUE 8rd Mod Completion Assembly (as detailed in attached schematic). Set packer, shear PBR, perform tubing space out and land tubing hanger. 25. With annulus open, pressure test tubing to 3000 psi for 5 minutes and monitor annulus for returns. 26. Bleed down pressure in tubing to 1500 psi. While holding 1500 psi on tubing, pressure 3-1/2" x 7"annulus to 3000 psi for 5 minutes. Bleed pressure in tubing to zero and shear valve in lower GLM. 27. ND BOP, NU Tree and Test to 5000 psi. Frneze protect with Diesel. Rig down and move off Doyon Arctic Fox. 28. MIRU well testing equipment and surface test tanks. Perform production tests as required. Produced fluids will be either re-injected into the formation or trucked to Kuparuk or Alp' production face ies. -~--~li° ~+EES ~ir~t r~~ ~tr ~rc G~.~~.6~t"~?~~ ~,it cc 5~~ ~ ~~.:.~- 29 Upon completion of testing, plug and bandon or temporarily suspend the well as per AOG C regu ations. 30. Thoroughly clean location and block off further ice road access to ice location. ~~ /,~s~ ORIGINAL ConocoPhillips Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Antigua #1 prilling Fluid Pro eR rties: Surface Hole 12-1/4" (Extended Bentonite): S ud to Base of Permafrost Base of Permafrost to 7ota1 De th Initial Value Final Value Initial Value Final Yalue Density (ppg) 10.0 10.0 10.0 10.0 Funnel Viscosity sewnds 150 120 120 75-80 Y~eid Point. cP 45-60 40-55 40-55 20-30 Plastic Yiscostiy Ib 100 25-35 15-30 15-30 10-25 10 sec Gel Strength Ib 100 20-35 15-30 15-30 10-25 10 min Gel Strength Ib 100 30-60 25-60 25-60 18-45 PH 8.5-9.5 8.5-9.5 8.5-9.5 8.5-9.5 API Filtrate (a) 10-15 8-15 6-8 <6 Solids (%) 6-12 7-12 7-13 8-14 Intermediate /Production Hole 8-1/2" (LSND Mud): Drill Out to Total De th Initial Value Final Value Density (ppg) 9.4 10.2 Funnel Viscosity seconds 45-60 45-60 Yield Point cP 15-25 17-25 Plastic Viscosti Ib 100 8-16 10-20 10 sec Gel Strength Ib 100 4-10 4-10 10 min Gel Strength Ib 100 6-14 6-14 PH 9.0-9.5 9.0-9.5 API Filtrate (cc) <6 <5 HTHP Filtrate <16 <12 Solids (%) 6-12 7-16 Drilling Fluid System: Equipment list for Doyon Arctic Fox (as provided by contractor) is attached for review. Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. ORIGINAL ConocoPhiliips Alaska, Inc. Maximum Anticipated Sulrtace Pressure and Casino Desi4n: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Casing Size Casing Setting Depth Fracture Gradient Pore Pressure Gradient Formation Pore Pressure DxMWx.052 MASP Drilling 16" 100' MD / 100' ND 11.30 ppg 8.75 ppg 46 psi NA 9-5/8" 4,005' MD / 4,005' ND 15.30 ppg 8.75 ppg .1822 psi 48 psi 7" 6,875' MD / 6,875' ND 17.20 ppg 9.40 ppg 3361 psi 2605 psi Permit 7,175' MD J 7,175'ND Requested Permit Depth To Allow For Depth Control Uncertain Note: MASP Information, outlined above, is based on the attached Seismic Pore Pressure Analysis. Procedure for Calculating Maximum Anticipated Surface Pressure: MASP 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) formaton pore pressure at the next casing point less a gas gradient to the surface as follows: 1) MASP = [(FG x 0.052) - 0.11] x D Where: MASP =Maximum Anticipated Surface Pressure r-G =Fracture Gradient at the casing seat in Ib/gal 0.052 =Conversion factor from Ib/gal to psi/ft 0.11 =Gas Gradient in psi/ft (above 10,000' ND) D =True vertical depth to casing seat in ft from RKB 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 MASP = [(FG x 0.052) - 0.11] x D _ [(11.3 x 0.052) - 0.11] x 100' -OR- MASP =FPP - (0.11 x D) = 1822 - (0.11 x 4005 = 1381 psi 2. Drilling below 9-5/8" Surface Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(15.3 x 0.052}- 0.11] x 4005' MASP = 2746 psi -OR- MASP =FPP - (0.11 x D) = 3361- (0.11 x 6875 = 2605 usi , ORIGINAL In~ ConocoPhllllps Alaska, Casing /Tubing Design Performance Properties Size Weight ~PP~ Grade Connection Burst (Psi) Collapse (Psi) Tensile Yield 16" 63.0 B PEB Conductor Casing 9-5/8" 40.0 L-80 BTC 5,750 3,090 916 M 7" 26.0 L-80 BTC Mod 7,240 5,410 604 M 3-1/2" 9.30 L-80 EUE-8rd Mod 10,160 10,530 207 M Drillina Area Risks: Well Proximity: No Well Proximity Risks have been identified at the Antigua #1 location. Shallow Hazards: A Seismic Analysis was performed for die Antigua #1 well and Pore Pressure /Fracture Gradient Curves derived. No indications of abnormal pressure, shallow gas hazards or hydrake development were observed near the prospect Nation. However, prudent and precautionary drilling /tripping tedmiques will be emphasized while drilling this well with specific regard to potential shallow gas , hazards. See attached Seismic Pore Pressure Analysis for more detail. Drilling Hazards: See attached Drilling Hazards Summary. Annular Pumnina Oinerations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II 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 Antigua #1 Surface /Intermediate Casing Annulus will be filled with diesel after setting intermediate casing and prior to the drilling rig moving off of die well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the Intermediate/production cement jobs to cover those formations. PAI may request approval to inject or dispose of fluids in the, Antigua #1, 9-5/8" x 7" annulus at a later date. This request would be made after sufficient data is available to meet requirements per 20 AAC 25.080. ORIGINAL ConocoPhillips Alaska, Inc. e..«.. ~~e.l r.n..l.... ~rl.e .IenH, . .m.+~...l.i Fl~ girl nrnr.nrki~ ~nrl r.nrn nrnK~ ~rce nro ne fnllm-ie• Formation a°th [ND-SS) jp~y PQ,~ible Fluid Tvoe Pore Pressure Estimated lost) Permafrost -Base 1250' + - 150' 570 West Sak - T 3170' + - 100' Possible Oil 1445 West Sak -Base 3680' + - 100' 1675 C-80 K-10 4230' + - 100' 1925 C-40 K-5 5745' + - 100' 2750 HRZ - To 6220' + - 100' 3040 HRZ -Base 6400' + - 50' 3130 K-1 Marker 6455' + - 50' 3155 Ku ruk C-Sand o 6515' + - 50' Oil 3185 Ku ruk C-Sand Base 6550' + -50' 3200 Miluveach LCU 6550' + - 50' 3200 Total De th Planned 6750' 3185 Total D th Permitted 7050' 3528°" Note: e Pore Pressure Estimates, outlined above, are based on the attached Seismic Pore Pressure Analysis. The interpreted fluid pressures near the Antigua prospect indicate near hydrostatic conditions (.455 psi/ft) to a depth of about 5,200' with slowly rising pressure t-elow that. Formation Evaluation: ~i .~-i kM~ C'1~R15 Antidpated logging, coring and testing for this well is as follows: ~~ ~~~ Logging: 12-1/4" Surface Interval `'c' ~----~~ ~ ~ LWD: GR / Res 8-1/2" Intermediate /Production Interval LWD: GR / Res / Neu /Den / PWD E-Une / DP Conveyed: MDT / CMR /Dipole Sonic /Rotary Sidewall Cores Coring: None currently planned. Mud Logging: Mud logging 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 HzS detection - Thirty-foot (30~ wet and dry samples will be collected from Surface to Surface Casing Point. Thirty-foot (30~ wet and dry samples will be collected from Surface Casing Point to Well TD. Ten-foot (10~ wet and dry samples, or continuous, collected across all shows and all target intervals. . Flow Testing: Based upon favorable log data, ConocoPhillips may decide to complete and test the Antigua #1. However, no test is curcentiy planned at this time. If the decision is made to wmplete and test the Antigua #1 then flow testing and pressure build-up tests will be used to determine formation properties and estimate the commerciality of this exploratory well. Reservoir stimulation may be performed in the form of an acid or frac treatment. 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 re-injected into the formation following completion of the flow testing operations. ORIGINAL ~ i ConocoPhillips Alaska, Inc. Antigua #1 Drilling Hazards Summary (Post in Rig Floor Doghouse Prior to Spud) 12-1/4" Hole / 9-5/8" Casino Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval Gas Hydrates Moderate ~ Mud gas detection, Increased mud weight, Decreased mud viscosity, Decreased circulating times, Controlled drilling rates, Low mud temperatures Hole swabbing on trips Moderate Reduced trip speeds, Mud rheology, Proper hole fiNing (use of trip sheets), Pumping out of hole, Flow checks Running Sands and Gravels Moderate Maintain planned mud parameters, Elevated mud viscosity from spud, High density sweeps Abnormal Pressure in Surface Formations Low - Diverter drills, increased mud weight. Reduced / Cautious trip speeds while drilling surface hole. Geologist on location to assist in picking surface casing shoe depth above the C80/K10 marker Sticky Clay /Tight Hate low Attention to hole cleaning, Wiper trips Lost Circulation Low Reduced pump rates, Mud rheology, Lost circulation material, Use of low density cement slurries 8-1/2" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy Low Leak-Off Test (LOT) High Top Set the Kuparuk C Abnormal Reservoir Pressure High ~ Well control drills, Increased mud weight, PWD tools, Contingency for top set casing string Hole swabbing on trips Moderate Reduced trip speeds, Mud rheology, Proper hole filling (use of trip sheets), Pumping out of hole, Flow checks Lost ciraalation Moderate Reduced pump rates, reduced trip speeds, mud Theology, lost circulation material Sticky Clay /Tight Hole Moderate Attention to hole cleaning, Wiper trips Differential Sticking Low Good drilling practices, Mud tubes, Keep string moving, Avoid stopping w/ BHA across sands Hydrogen Sulfide gas Low ' HZS drills, detection systems, alarms, standard well control practices, mud scavengers ,- ORIGINAL ~J Pre-Drill Seismic Fluid and Fracture Pressure Analysis for the Proposed Antigua Prospect FINAL REPORT Prepared for ConocoPhillips Dr. Alan R. Huffman, Dr. Richard Lahann and Walter Kessinger Fusion Petroleum Technologies Inc. 25231 Grogans Mill Road, Suite 175 The Woodlands, TX 77380 F U S I O N I ORIGINAL • • CONTENTS LIST OF FIGURES 1N THIS REPORT I - Introduction II - Summary III - Seismic Processing 3 5 5 b IV - Potential for the Presence of Shallow Gas, Gas Hydrates and Seismic Pressure Prediction 6 V - Pressure Prediction Procedure 6 VI - Pressure Calibration from Offset Control Wells 9 VII - Seismic Fluid and Fracture Pressure Analyses for the Antigua Prospect 9 VIII -Interpretation of lines A-A' and B-B' IX - Conclusions 10 10 ORIGINAL ~ • LIST OF FIGURES IN THIS REPORT Figure 1. Basemap showing the outline of the interpreted velocity volume, the three prospect surface locations and the surface locations of the five control wells. Also displayed is the location of line A-A' which links the W Sak 26 well with the Antigua prospect and terminates near the W_Sak_5 well. Line B-B' contains the Winter Trails_2 and _3 wells and the Antigua prospect and is and is roughly orthogonal to line A-A'. Figure 2. Smoothed interval velocity profile along line A-A'. Figure 3. Smoothed interval velocity profile along line B-B'. Figure 4. Interpreted fluid pressure gradient along line A-A'. The yellow line indicates the approximate TD for the Antigua prospect. Figure 5. Interpreted fluid pressure gradient along line B-B'. The yellow line indicates the approximate TD for the Antigua prospect. Figure 6. Interpreted fracture pressure gradient along line A-A'. Figure 7. Interpreted fracture pressure gradient along line B-B'. Figure 8. Original (unsmoothed) interval velocity profile along line A-A'. Figure 9. Original (unsmoothed) interval velocity profile along line B-B'. Figure 10. Depth plot of MDT fluid pressure data from regional wells. The MDT data from. the Winter Trails 1 wells are plotted in orange and conform closely to the plotted hydrostatic line. The hydrostatic pressure line has a surface intercept at the sea. level and a slope of .455 psi/foot (8.7 ppg). Figure 11. Depth plot of mud weight data from the W_Sak_5 (orange), W_Sak 26 (purple), Winter Trails_1 (blue), Winter Trails_2 (black) and Winter Trails_3 (red) wells. Also posted are MDT data from the Winter Trails_1 well (cyan). Figure 12. Depth plot of gamma ray, resistivity, neutron porosity, velocity, and density logs from the Winter Trails_1 (blue), Winter Trails_2 (orange), Winter Trails_3 (purple), W_Sak 5 (magenta) and the W Sak 26 (cyan) wells. Figure 13. Density data from the Winter Trails_1 (blue), W Sak_26 (cyan), and W Sak 5 (magenta) wells. The blue data in the right track is the integrated vertical stress (overburden) from the red points in the left track. The red curve is a mathematical representation of the vertical stress. Figure 14. Sonic log (blue) from the W Sak 5 well plotted with surface location interval velocity profile. Figure 15. Sonic log (blue) from the Winter Trails_1 well plotted with the surface location interval velocity profile. ORIGINAL • • Figure 16. Depth/interval velocity relations calculated for the W_Sak_5 well from the checkshot data (blue) at that well and from the interval velocity profile nearest the surface location (purple). Figure 17. Depth/interval velocity relations calculated for the W_Sak_26 well from the checkshot data (blue) at that well and from the interval velocity profile nearest the surface location purple). Figure 18. Depth/time relations calculated for the W Sak 5 well from the checkshot data (blue) at that well and from the interval velocity profile nearest the surface location (purple). Figure 19. Depth/time relations calculated for the W Sak 26 well from the checkshot data (magenta) at that well and from the interval velocity profile nearest the surface location (blue). Figure 20. Interval velocity data from the surface location for the Winter Trails_1 well along with a compaction profile (left track). The right track shows mud weight data and MDT data from the control wells. The Winter Trails_1 MDT and mud weight data are in cyan and blue. The red trend in the right track is fluid pressure interpretation from the red compaction model. Figure 21. Effective stress/interval velocity data for the Winter Trails_1 MDT data (cyan) and the surface locations for the 5 control wells (W Sak 5, blue; W_Sak_26, orange; Winter Trails_1, purple; Winter Trails_2, black; Winter Trails_3, red) for depths to about 6000 feet. Figure 22. Depth plot of Leak-Off Tests (LOT) expressed as percentage of vertical stress. Figure 23. Depth plot of Leak-Off Tests (LOT) expressed as pressure gradient, ppg. Data specifically characterized as LOT tests are highlighted in pink. Figure 24. Fluid and fracture pressure interpretation at the surface location of the W_Sak_5 well. The brown stars indicate mud weight data from the well. The pink line indicates an extension of fracture gradient into the permafrost where the model used to generate the brown fracture gradient curve is not valid. Figure 25. Fluid and fracture pressure interpretation at the surface location of the W Sak 26 well. The brown stars indicate mud weight data from the well. The pink line indicates an extension of fracture gradient into the permafrost where the model used to generate the brown fracture gradient curve is not valid. Figure 26. Fluid and fracture pressure interpretation at the surface location of the Winter Trails_1 well. The brown and blue stars indicate mud weight and MDT data. from the well. The pink line indicates an extension of fracture gradient into the permafrost where the model used to generate the brown fracture gradient curve is not valid. Figure 27. Fluid and fracture pressure interpretation at the TD location of the Winter Trails_2 well. The brown stars indicate mud weight data from the well. The ORIGINAL • pink line indicates an extension of fracture gradient into the permafrost where the model used to generate the brown fracture gradient curve is not valid. Figure 28. Fluid and fracture pressure interpretation at the surface location of the Winter Trails_3 well. The brown stars indicate mud weight data from the well. The pink line indicates an extension of fracture gradient into the permafrost where the model used to generate the brown fracture gradient curve is not valid. Figure 29. Fluid and fracture pressure interpretations at the Antigua location. Proposed TD is 6750 feet. The pink line indicates an extension of fracture gradient into the permafrost where the model used to generate the brown fracture gradient curve is not valid. Figure 30. Edited interpretation of fluid and fracture pressures at the Antigua location. The shape of the fracture pressure profile above 1500 feet is very uncertain. oRiciNA~ • r Introduction The purpose of this project is to provide 3D fluid and fracture pressure interpretation and shallow hazard analysis on a 3D velocity volume containing the Antigua prospect, in Alaska. The velocity and seismic volume contained the West Sak 5, West_Sak_26, Winter Trails_1, Winter Trails_2 and Winter Trails_3 as well as the Antigua prospect. No confirmed shallow hazards or hydrates in the control wells were reported by - ConocoPhillips. The fluid pressure is expected to be near hydrostatic until near TD at the Antigua prospect. Maximum fluid pressure gradient anticipated is less than 10 ppg. ~ Summary lnterpretation of the velocity cube with calibrated velocity/stress functions showed little development of excess fluid pressure near the Antigua prospects within the proposed drilling depths. A small fluid pressure increase was interpreted at the prospect location beginning at about 5200 feet. The velocity, fluid pressure gradient and fracture pressure gradient interpretations along lines A-A' and B-B' (Figure 1) are shown on Figures 2-7. The interval velocity display along the A-A' line (Figure 2} shows a small slow zone primarily south (left) of the prospect near .6 seconds. The Antigua prospect crosses this small velocity anomaly. North of the prospect, near the Winter Trails_1 well, the interval of relatively slow (less than 8500 feedsecond) sediments thickens slightly. The velocity display along line B-B' (Figure 3) also displays the small velocity anomaly near the Antigua location at .5 seconds. This velocity anomaly contains prominent reflectors and. maybe due to fluid or lithology effects. The interpreted fluid pressure gradients along lines A-A' and B-B' are displayed on Figures 4 and 5. Line A-A' contains a relatively thin (.1 seconds) pressure gradient `anomaly' centered near the 'W_Sak 261ocation and apparently limited to a small structure. The most likely cause of this velocity/pressure gradient anomaly is lithology/fluid content and not increased fluid pressure. Figures 4 and 5 both indicate near hydrostatic conditions down to about 1.5 seconds, with some pressure increase below that depth. The fracture gradient displays (Figures 6 and 7) show continuous increase in fracture pressure with depth. This pattern is the expected result from the fracture pressure model employed in this study. The very low fracture pressures interpreted above .2 seconds are - probably lower than occur in the permafrost interval. The velocity and reflection character of the seismic data were examined for any indications of shallow gas hazards or hydrate development. No indicators of shallow L hazards were observed. The presence of a fast and shallow permafrost interval overlying much slower water and hydrocarbon bearing intervals makes recognition of shallow, gas- bearing intervals very problematic. Such intervals could be hidden within the rapid ORIGINAL C. velocity reduction between the base of the permafrost, +/- 1400 feet; and the top reservoir zone at +/- 3000 feet. ORIGINAL • Seismic Processing The velocity volume was processed prior to delivery to Fusion by the AVEL interval velocity extraction program. The displays of the original velocity data on line A-A' and B-B' are shown in Figures 8 and 9. The data set contains narrow vertical streaks of anomalous velocities which have little correlation to stratigraphy or structure. Anomalously slow velocities were frequently underlain by anomalously fast velocities, which are commonly observed in seismic data sets where velocity picks are not robust. These data quality issues extend throughout the data set. To address this issue, the original velocity set was conditioned by first clipping velocities below 6500 feet/second to a minimum value 6500 feet/second followed by a 33 x 33 CDP spatial filter to stabilize the trace to trace variations that appeared to be non-physical in character. The filtered velocity volume (Figures 2 and 3) was used as input to the fluid/fracture pressure and shallow hazard interpretation. Potential for the Presence of Shallow Gas, Gas Hydrates and Seismic Pressure Prediction The potential for shallow gas accumulation or gas hydrates at the prospect locations is considered low. Figures 3 and 4 shows no anomalously fast or slow velocities or - anomalous amplitude variations near the prospects which might suggest either gas accumulation or hydrate development. Pressure Prediction Procedure Regional and local MDT data and mud weight profiles were used to constrain an interpretation of the fluid pressure profiles in the control wells (Figures 10 and 11). The fluid pressure data show a strong correlation with a hydrostatic pressure profile of .455 psi/foot (8.7 ppg). The local well with MDT data, the Winter Trails_1 well, has pressure data very near the regional gradient. At least part of the elevated (off trend) pressures on Figure 10 can be attributed to hydrocarbon displacement pressure and does not indicate an increased aquifer fluid pressure. The mud weight data indicate that the reservoir intervals, roughly 2400 to 3500 feet (see Figures 10 and 12), were drilled with mud weights between 9.2 and 9.8 ppg. These mud weights are consistent with the MDT data and indicative of near hydrostatic conditions in the region, down to a depth of at least 5000 feet subsea. Well log density data (Figure 12) were used to generate alocally-calibrated overburden (vertical stress) profile (Figure 13). Vertical stress (OBG) in psi is represented as, (1) OBG = .00061*d^i.oss*1000, ORIGINAL • where d is depth in feet. Effective stress/depth profiles were generated at the control wells by assuming the vertical stress profile (Figure 13) and hydrostatic conditions (Figure 11) to a depth of at least 4000 feet. The seismic interval velocity data were used to establish interval velocity/effective stress relationships at the control wells. The velocity data were imported at 100% of their interpreted values, rather than the 90% procedure commonly employed. Comparison of interval velocity profiles with sonic log profiles shows only fair agreement with the sonic log data (Figures 14 and 15 for wells W_Sak 5 and Winter Trails_1). The agreement between the data sets is variable from poor to good in the very shallow section. The seismic velocity profile is fast relative to the logs between 1000 and +/- 2500 feet, and then slightly slow relative to the log below +/- 2500 feet. The poor correlation between 1000 and +/- 2500 feet maybe due to the inability of the seismic velocity interpretation program to adequately model the very rapid velocity reduction in this depth range which underlies the permafrost. Figures 16 and 17 display the depth/interval velocity relationships from the checkshot profiles at the W_Sak 5 and W_Sak 26 wells, along with the depth/interval velocity relationship calculated from the 100% interval velocity data. For both wells, the two data sets diverge immediately below the permafrost, but are in reasonable agreement above and below that interval. The deviation in the data sets, as discussed previously, maybe due to the inability of the seismic velocity interpretation to adequately model the very rapid velocity reduction directly beneath the permafrost. Time-depth profiles from checkshot and interval velocity data for the W_Sak_5 and W_Sak 26 wells are shown in Figures 18 and 19. In both cases, the interval velocity profile is slightly deeper than the checkshot profile. The depth errors are on the order of 100-200 feet. Slowing the velocity field by 10 %, a common interpretation procedure, would result in greater depth errors over most of the plotted depth range. The MDT data from the Winter Trails_1 well (Figures 10 and 11) indicate near ' hydrostatic conditions between 3000 and 3500 feet in that well. The interval velocity profile for the surface location for the Winter Trails_1 well is shown in Figure 20, along with a compaction models (discussed below). The fluid pressure interpretation employing the compaction profile and the vertical stress curve (Figure 13) are shown in red on the right panel of Figure 20. The sediments from 2500 feet to 5000 feet are interpreted to be near hydrostatic pressure, in agreement with the regional mud weight data and the MDT data at this location. Figure 21 displays a crossplot of interval velocity and effective stress, calculated from the mud weight data, from the surface down to about 6500 feet. The data were sampled at 500 foot intervals. A strong, clear relationship exists between interval velocity and effective stress; departures from a simple relationship to slow velocities would indicate development of excess fluid pressure; departures to fast velocities would indicate a change of fades or development of extensive cementation. Some slow departures were • • observed at depths of 6000 feet or greater and these values were removed from the plot so as not to influence the derived `hydrostatic' stress/velocity relationship. The relationship plotted in Figure 21 was accepted as a calibration model for the seismic velocity volume. The placement of the calibration function near the MDT data and slightly to the right of the mud weight-derived data trend allows for the small amount of overbalance present from the mud weight data. The interval velocities in the shallow interval (less than 2500 feet) are fast relative to the primary compaction trend. These data plot on the left side of Figure 21 as a trend of increasing velocity at very low effective stress due to permafrost development near the sediment surface. The calibration function shown in Figure 21 in red was used to interpret fluid pressure at all depths. The velocity/effective stress relationships described above were applied across the seismic volume and effective stress was determined as a function of time and depth. Fluid pressure was interpreted from the Terzhagi relationship, (2) Overburden =fluid pressure + effective stress. When the calculated fluid pressure from the interval velocity was less than hydrostatic pressure, the hydrostatic value was substituted for the calculated value. The calibration function posted on Figure 21 does not constrain the interpretation to be hydrostatic at the prospect locations or other areas within the velocity volume. The points used for calibration were taken exclusively from the control wells where hydrostatic or near- hydrostatic conditions can be demonstrated or inferred. ConocoPhillips-Anchorage provided a regional database of leak-off test (LOT) data; this data is displayed with leak off pressure posted as equivalent mud weight on Figure 22. The data scatter is considerable and maybe due to variable drilling practice, inclusion of formation integrity tests along with leak-off tests, variability in lithology/tensile strength of the tested formations and/or regional variations in the tectonic stress field. The data specifically identified as LOT's are not systematically greater than the other tests. One reported LOT value is substantially greater than the calculated vertical stress, which suggests either substantial tensile strength or substantial horizontal tectonic stresses. Attempts were made to model the data with a Matthews and Kelly, stress-ratio approach. These attempts required an interpretation (or assumption) of fluid pressure at the test depth for all the data. Hydrostatic fluid pressure was assumed in all cases and resulted in a decreasing stress-ratio with depth which is counter-intuitive and contradicts industry experience. The absence of demonstrated excess pressure in the MDT data set provided by ConocoPhillips suggests that a Matthews and Kelly approach, which explicitly includes fluid pressure contribution to Leak-off pressure, is not required for this data set. Further, any shallow zones with interpreted fluid pressure (from seismic velocities) may be due to lithology or fluid effects and a Matthews and Kelly model would calculate increased fracture pressure, whereas decreased fracture pressure is more likely. ORIGINAL • • A model was generated (Figure 23) which relates LOT to a percentage of the vertical stress. The LOT model is expressed in ppg as a function of depth in Figure 21. The data below 4500 feet were removed from the calibration since they appear anomalously low compared to the values from shallower depths. The resulting fracture pressure model, (3) fracture pressure = (.18 + (.074*d^.a63)*OBG, where d is depth in feet, was used to calculate fracture pressure for the velocity volume. This model may underestimate fracture pressure slightly in regions with `real' overpressure. The LOT/FIT data provided by ConocoPhillips (see Figure 23) were from depths greater than 2000 feet, which is below the base of the permafrost in this region (near 1500 feet). At depths shallower than 1500 feet, the intergranular ice can be expected to contribute to the sediment tensile strength, analogous to intergranular quartz or carbonate cements in deeply buried sediments. The fracture pressure model employed will underestimate the sediment strength in the permafrost zone. ConocoPhillips reports that the permafrost zone is normally drilled with 10 ppg fluid without lost circulation. This observation suggests a formation strength greater than 10 ppg in this depth range. Given that no fracture pressure data are available in the permafrost zone, the estimated fracture pressures and gradients for the sediment section below permafrost are probably not valid for the permafrost layer. Pressure Calibration from Offset Control Wells Figures 24-28 display the interpreted fluid and fracture pressures, mud weights and MDT data at the five control wells. Note that in most cases the interpreted pressures are near, but below the mud weight. The only exception is the W_Sak 26 well (Figure 25) where the calculated pressure near 2800 feet is slightly greater than the mudweight. The depth of the `high' pressure calculation is near the depth of a resistive zone (Figure 12) in the well; the low velocity is perhaps due to fluid/friable lithology effects in a shallow, hydrocarbon bearing zone. For both the W_Sak_5 and W Sak 26 wells, the interpretation indicates slightly rising fluid pressure near the base of the well. In both cases, the mud weights were increased in these zones, suggesting awell-calibrated model. For the Winter Trails l we11(Figure 26), the interpretation indicates fluid pressure in agreement with the MDT data and the mud weight data. The Winter Trails_2 and _3 wells were limited to the shallow, near-hydrostatic interval; the interpretation is consistent with the mud weight data. Because the effect of permafrost on shallow fracture pressure is unknown, figures 24-28 have included in them an interpreted shallow fracture pressure trend which is constant • • from about 1500 feet (base permafrost +/-) to the surface. The brown fracture gradient curve that was calibrated to the sediment section should be ignored above 1500 feet. Seismic Fluid and Fracture Pressure Analyses for the Antigua Prospect The fluid and fracture pressure interpretation at the Antigua Prospect location is shown in Figure 29. The interpretation indicates near hydrostatic conditions to near about 5200 ' feet and gradually increasing fluid pressure below that depth. The fluid pressure gradient is interpreted to be less than 10 ppg down to a depth of 7500 feet. As before, a probable permafrost influenced fracture pressure is shown in pink. Because the effect of permafrost on shallow fracture pressure is unknown, Figure 29 has included in it the same interpreted shallow fracture pressure trend as shown in Figures 24-2$. The brown fracture gradient curve that was calibrated to the sediment section should be ignored above 1500 feet. The data displayed in Figure 29 were extracted and edited to produce a `best interpretation' fluid and fracture pressure profile. This interpretation is shown in Figure 30. The excess pressure interpreted at 2800 feet has been reduced slightly and smoothed and the transition from fracture pressure in a friable shale/sand to `cemented' permafrost has been smoothed. The shape and magnitude of the permafrost fracture pressure profile is supported only by drilling observation that the formation does not fracture with 10 ppg drilling fluid and an interpretation that the fracture pressure decreases toward the sediment surface. However, if the ice content increases toward the sediment surface, the fracture strength could increase upward toward a value appropriate for pure ice. In the absence of any actual data, the trend from the sediment section below permafrost has been modified to make it more realistic than using the sediment trend which is known to be incorrect in the permafrost, and also to be more realistic than the simple straight line applied in Figures 24-29. ~ ~ *. ~~~~~ • ~ ~_ Interpretation of lines A-A' and B-B' The interpreted fluid pressure gradients along lines A-A' and B-B' are displayed on Figures 4 and 5. Line A-A' contains a relatively thin (.1 seconds) pressure gradient `anomaly' centered near the W_Sak 26 location and apparently limited to a small structure. The most likely cause of this velocity/pressure gradient anomaly is lithology/fluid content and not increased fluid pressure. Figures 4 and 5 both indicate near hydrostatic conditions down to about 1.5 seconds, with. some pressure increase below that depth. The top of the fluid pressure increase rises from about 1.5 seconds at the W Sak 26 location to 1.4 seconds at the W_Sak_5 location. Figure 4 contains indications of pressure sealing faults below 1.5 seconds to the left (south) and right (north) of the Antigua structure. The top of overpressure rises, on Figure 5, from about 1.5 seconds at the left (southwest) to about 1.35 seconds at the right (east) end of the line. The top overpressure also moves up section along this line. The magnitude of the interpreted pressure gradient is somewhat patchy near the base of the section, but is less than 11.5 ppg in all cases. Conclusions An interval velocity data cube was conditioned for interpretation of fluid pressure near the Antigua prospect. A one-layer fluid pressure interpretation was calibrated to MDT, mud weight and interval velocity data from 5 control wells near the prospect. A fracture pressure model, based on the depth and vertical stress, was developed and calibrated. The interpreted fluid pressures near the Antigua prospect indicate near hydrostatic conditions to a depth of about 5200 feet, with slowly rising pressure below that depth.. The interval velocity distribution and reflection character were examined for evidence of shallow hazards and/or hydrate development. The rapid velocity reduction below the permafrost makes recognition of shallow gas accumulation problematic. No evidence of shallow gas hazards or hydrate development was observed near the prospect locations. ORIGINAL 16b 0 ~0 0 ~ ~ g °o c~ g ii o ~ g n 1 ~ o o tN 0 n o 0 c oE n °o n oc c"` n 00 'n t ~ " -` ~ o °o t 0 0 in a c 0 00 n ° om t c o ~ o x5 f21 900~ 594141~f~~ 11125 ~ ~~~~200 11125 11 00 11100 11075 5 1 11075 1 050 11050 11025 1 11025 11060 11000 10975 10975 10950 10950 10925 ~ 10925 10900 E t~~6 T / 10875 3 10875 ----- / V J 10850 10850 10825 10825 ~} 10800 6 10800 r~ 10775 10775 10750 10750 10725 10725 10700 T 10700 10675 10675 166~60~ o 0 0 0 0 0 0 0 0 0 0 0 0 0~ o 0 0 x'21 ~J00 w w A A .n a to to to to cn rn rn rn --~ ..-~ --~ --~ o~ o~ o0 to -v o ny to --~ o n~ to --r o e.~ to -.i o n~ to -.i o r.~ to o to o cn o to o cn o to o to o cn o to o to o to o Figure 1. Basemap showing the outline of the interpreted velocity volume, the three prospect surface locations and the surface locations of the five control wells. Also displayed is the location of line A-A' which links the W_Sak_26 well with the Antigua prospect and terminates near the W_Sak_5 well. Line B-B' contains the Winter Trails_2 and _3 wells and the Antigua prospect and is and is roughly orthogonal to line A-A'. r 1NT 2 VvT 3 Anti u~. c v 19229 ft c~ 17881 ft c~ B ~k Ln: 10439.0 10447.0 10456.0 10465.0 10474A 1D483.0 10492.0 10516.0 10546.0 10576.0 1D6050 10835.D 10666.0 10695.0 10725.0 10755.0 10785.0 10815.D XLn: 1 D889.0 10718.0 10746.0 10775.0 10804.0 10832.0 10861.0 10871.0 1 D874.D 10877A 1088D.0 1 UBB3.0 10885.0 l OBB8.0 1 D891.0 1 D89 3.0 10896.0 10898.0 12UGO.000 11750.000 115RD.000 "~ '~ 11370.CU0 111f;Q000 i 1C540.DU0 iU?4C CUU 10530.000 1p32p.DGD 1p11c DDD s4DD DDo ~ 4E4c DDD °~f~P OCU . 9270.000 50b0.000 i 6650 CC0 SE4U OOC i 843p.GCC 0220 OC0 ~ ~ EO1C L'CO • 7EOQ000 7e9apnG ~ 7z.~D DDo '17D 000 ^c~p.GOG i ~ F7`O.OGO £E~D.OOU ' f:".O.COp B12C OG0 5910ADU 5'DD CCC 5+90ADC 528C.D00 SG00.000 • Figure 3. Smoothed interval velocity profile along line B-B'. WS 2E. 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Q:.~,~ p ' ~tfu ~,,.°"~ ~ +a+q`~'~!1# ~++av. tr~asr~.i.r^ 1n`ry~,.d'ty~~y`f'Nt'i"rk'.,Irw..~, ~, "+ r :!~t rt.~l. I 1C.~`,L D _ .fir ~+~~ ~~. ~s i :.^ f~~ ,., ., ~ ^' ~, + `~lr•i1~7V'.,• t .:~,,,, ~~, ii =0.4D0 1C5DC ~~~t ~` ~r+ Tye +4+' F*r't t- r :r.°, i . ~~ ,:Fb t.di~ti ~Mvy aTwN.~y„ ~"rp~b. ~ It 1 ° f°Y.,,m,rA - ~ r ~ ,a~,rr.t ' Ye++<. ~ ~ t,+, ys~: r +, : rl! '. ~- ~ tO.S.`C hra,~''i` r~rti> r w d. N.r. t r r ~ i ! aw rr'riityt,. ' ~ i i o-~*+.a•°°rY:~a~, , ; ~,+ ,r., ,,,,~ t 0.3G C ~'"+ ~ .» h. r>~ P .*:,r r r ~. ~ rl tr ~.y i ~. l,r ^ 10.1f~0 0 :~ 'r4 ~-w r,~ ~e ,~ i„i YrAH t ~ ~ t .v i~ 1 ~_-0.~00 `r"^i~ , rAtt~' N ~`? t '' +. 815 ~! r. ~ ~. Irw a+~+l r. r 1 t., ,1t + „a H^aMtie .., ' ~ 1C.OCD 'tit~tt r `'~'- n r ++rr+1i' r ~ i ~ r at+ i= 5.8`0 li.. n rk,.y,. ,~6_ , w«y, w~ 4b., ,.•,e y yk, iKy, ~ ~r t ~ 1'° r ~, t ~- t rte. ,Van. tt 1Nrali.H!'~ I Hfl { ti, ~ q, ~1 t yccJ ,. D I .~+ ~ ,'*K,.' ~; y,- 3N° 'ru .;r r ,,lwN ~ 1 tl IN"r+~ Lyra 1 i r ,aMrr , f.: ~-0-6DU ~ _~G Q i ', rv r., r4ar+ x.a w 1c,.l~,;W H~Mr' raa. ~.~ it %r n ~~ 1~ni ~ c' +~~5 ,s m~, ,~ •: ~ ns r., rh.; yu r i .. i~ r Yrypry~ ,.. ... r in, ? ~ P ~ ._ S.tCC _ ~, ( .t" ro, '-ir idl r,. ~;! .Ll y.".lid ~TR°' r« r ,~r ~ r ^ ~,: _'~~.~ -.::I 4~~C -~ 0 r ., .ra~ ,:~w"trPrn ~;. ~~' 1++~»°M r ,'' .+, _'i~r+a..t++i-iiN9 i r'~a;rr,,,+~v"rF .f*-.. F, ~:~. j~1.700 &.5 0 ~f .~:., f t IPa§sa ra .; r-d-~.~~^.,',t +. !l ~ r' It++v:+n+. ,i+ i fs.T'•!'~'+~'~~'}"rr ^hri i1~nlpy.err .. ~; r 1., ry r, i.>_v' ~r+j~`.Fr _ E 800 y ~ t ~ i '~ } , ~r+ .; W¢"T r rw~ r~o^ ,,: a 71 ' w n''.rb. n itdcq~ c.gg0 4Y~+ Wd '+r 1 M ~'a!- ps- in Fi? r'F'4n r reaw~4f. ~ i ~+wkp• tri+u'+tlr yd' r" *"#~'~ ~.p.lt f a} ~ rt ~~ ~~R'r Hy*ai 4 .by, .§3 ~''+Itl; I- 1c. (S . r r'9- ..~.1~ i~~. ire +,. ~' ~i ~ ;~ wa. ~~'° .. ram,, H•~-',~ = F."CC D'i ' •rr~ r ~~ aw r~. ia~,., }b ~~~ :., ri~~~ ~a'#„~rt~" '~ K!r`~ r""•1r},,r~~ r rtyi" '~ `~ It r s~~e~f~; i~1.000 GOC ~~ -''ki >Z _ ~"4.r~^' '''~ ,.'r ~"r r~-!%i' N .~z`' ~ t trt;~~ ,HN+. rf,~.: e r "wfiy, ~ ;.~+s iii ,'~ ,aa,-, n ~, `r'rNr ~' ro* #r'rs+ "~,+ ~ ! +f Ni t! t ~N , k 3,.rA' riaag,~ w F~a+•+wx , r+ r 1,- + v. ~"b/Ba - r ~ ~ : t ~ 1 L i t ~" j} ~:,fr ~+ 'h+u. , ,...~+.«..H~+>~'{~~" ,! "' A ~ t' ~ wr ~^~ Yn. a~ t t~ r ft I_1 000 ,.yn ;' c#+ IbK ,+a rt1.+t'i" 4, m~w~r. I+.. ~ 4,~-.s7~+, a",~ ,. i r~~'c+.rb+a°n,a'>' r - e > rta. p..yy pTW!•a'>yu.+ l f a ~9 s" rtYC r`l w t r r '~ .. wt ~' , ~' 1 .1~Y' ,art r.,i+k~~.~ ~t,r:ba+ ~..i~J,wr t. ;'.`r t~.~~.. uti...?$-; ....^„ iw'Y`w•.~` I_ ~5.~ r~W ,,, ..wa"~. i.w r .. ! I i ~I'r~+'! ,~r `'7"R.T'"pi'aa.,Jpl rt~'ih, a4 i'i~r h.~ r: '^ wtf,; j-1.10D a r s 1 ' v i .. t ~ F. ~+rm~r. dwi-~rz t.vi~ irtiA: iN^ r i ~ i u Ta.u.:. ` "tr,~'ryyeh r'i°'~w r grrt+'a""+~., •'~y' =1.20G r+ h r t~, W+++ Ids r ~Rr ~ w uq~>,.~'~rr p~pe ^n M, r'+v `'q'tr, - r '~ g. ~aWhYSk'y, -~ ++', r++ / ha ~. rr ,~rNa i,~ t i ,, ro%r`~i ryP` w r~ ~~uA h s, } rr~i, v4!.. ~ f -~ r h 1 rte`, , rz+ ra. ~ ~ M h n,.ti. cabe' t°idr ~`" rN"• F~irr -1.3U0 v Y i r ~ ~ ~ 'ua ~)hkdiM..at~+l.rr ~,~~.y ~.-,. ~ t ~t~' .1i i~. ~, il~ 1 r^''~~~ ,.taerut+r r.-. nr'1 7 a~ .n, vee~*ia.w.r;n - taxrnFak~'+t''Wd'~rhm ~y2~Y frdd73EM'+NI ,.: ,r ~' ~,+F~~-I r}}P~ "r``1 .t ac i aly .. r art ~i - -+il _~ q#> .. ., _ `T' .~ Y'-r.~ r+#icaraiMMr.a4ni~ry„a,Sygaa~{.~~.i~tM ~ - a..:.. ~ "rr - i a, ~ , +~. _ 1 ' ~' t I fr r t rrW1~7~ rtrf srr t'..+`+ ,~ 1 > . .~1++Y j; 'xar»tA . w :r At ur°'y'YP~~~ ~ =1.4DO t sir ,~t: ~, ywK rs)s~-,ni,JY9lR~~ > rrrla~E tl u 1 ~ - yt~'t` -.'+~ ,r; ~ n •, ~I i~2 ~ ~ ~ Y fa -~ ia,:~py,h.~~ - -tr; i+FC>tr~tkii r ~rr' -15D0 fMY,1 '~ ~ 1"II , r Iriraar ' '. _ ~.+.~. ~'ssi ~ _ruNFtNr ! lit`V6plk »rSr N~ x+~u~, - Hs«.6~',yri r .!~vFM lrgkyw t I ~: ~ .:~brr y+..M? Nr lil )rir~al r rfr)`F Irlk~rrr I :'IP rtKfyr ~M~trrriN - • '..s 'ttsf ~,r r tr .sits, rs)lf p t'- I 1 r_ : 2 , ~rrHirR~ ;. Nanl -. M pNh~p.liiq y ~'f ~~ ~ r. iF I u ~' ~~ ,.. ~ 'rWrWa.r ~ 11 r b '. _1.5DD N51Prra~u+` ~E»r »il~~It' r41t+2+2a+ 1+j)4jy~1»»~i+'. G .») is rung ~ rr lrrtr Y;Irii itkM7FN~lw~~r't`IIYIrr.~h+> ~1 t t.rr~yl _ r'i~;,,~~n -sr fir. ,. ,4r... ,~ at r,: ~rlM' ~. V i~1ruNYrt ri»n rt~ _. ~'r`_~ _ 1 h.w+ '~i a r~ ~ a Nd tr+.r r. , k r 1r ) l~l/N-l1~ rtkM~~MiM91~---V`~tH++l ~N~r-IMNi~I~~lY1-M} ~-~ .r~r}yttr~P -1.7D0 - t ors i~: tsiNr 1 (il rlE6PhiFkV ~f Ia r r Ir 1 H ~1~+~I~~ a sMr r £ rl rV~1M11~V i r+'~~r~1T1P" rlr r s r ~. ,rr; I )}rri9iH1+~Y+1rN rFlifiliii-Ilr~ 1 M r }f 1F}+Ftl~+ »r~~r+r+rrarf ;.}rt 1r ritwlt!~ ,,.. y i~ iA'Ywvr»iYfMfikt .;~M- a 41i1~~~ 1 r r `" ;.~' Ilr tkV'rl+» ~IINMa ! _ Syr ~ rH ~,.~,:. n1:N,N?'r Nrr ~ ,) rirr~rl MfY ~ rMIMM NIrH r11 I ~ »Y~~ t u'rl =1.SDD 44~~~~ , ~ „~ ~:vrpt~W •r• » r ' leir«-~t~lrl r t1"! , r~ll-f~i .i :_,.. ____ .. ~l.t., nl.n~Z'n.~,.t~"~H _,. ~ ~ ,'a:Yaeaws+~ ~«+'r'rf"y''r.ti~u ,rFaullN++~1+lu+NiAwM~rill~~~IIEi!~ir~ .:.ir: ti..~,, ,~~. "`r• __.~ih.'~~~ ~,- • • Figure 4. Interpreted fluid pressure gradient along line A-A'. The yellow line indicates the approximate TD for the Antigua prospect. bVT 2 WT 3 Anti ua o . 19229ft - o ~ 17881ft - !~ ~S Ln 10439.0 10447.0 10466.0 104E5.0 10474.0 10483.0 10492.0 10516.D 1054E 0 10576.0 10605.0 10E35.0 10666.0 1D695.0 10725.0 10755 D 107D5.0 10815.0 XLn I 'i~Irll"! 1'I,, ~Il ,91,f1 1'I~O~(' 1 IIIILII I ?~l h1 '.I 11,7' I'~ 1 I'~- ', 1 I %h ~ 'CI h, 1 ~ '~~t' 1 I ~~;f' I ry1 ~'I •r,:i-I 1 I,.,Fii,-~ I ~''iII , ..• ,~ ,.,a s a - - ~+ ,.« 6Wh t ` R R tii• 1T h 1 . ` • •$ ~~ £. ~F kyi pye tPN edgtgti" ... - = + FYer+•r ~^w°a .tif sa r ~ h~ ~~ ~`'r #~~ 7rv r ..~ r ~*; sr~ r~ sue, <y a: 3,: .-~~ 0.11 ~ e, ''Ors'S't+nt ;ww +, w, ': c. a :z,„~• '~~yyr~,a~a, ~.,...,~~'~.° ~•~°'°~ '~, ,,,, q t '+ , ,~ ¢ .w w r,, ' `'-0.100 • t `k"~13+'i~.t-.,. 5' Y1P-, 4ti1., ^+r :. .qpw .p. M1 ~.yrp:. .HVr~, . .k ~~~ r ~ , ,. 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W,~ r~ r r°" ap "w.:., ,+4 ,j ~.. l D.~:I 7' ,w?w..a~ ~ w:; y~.ty+FH,,,. h,: ,,, •++.' ~ r,ma:,~,a -.,,'~ -.., 'w" ~ ; l~•• ~ m~ ~ +~ ~ -0.500 Y y3ii•v. . ' ! '+%z- trr' 4m '3.. s >+s ',tt+ P / _ M + ~'. ~ t^..rv- " • y.• r u~,,,, '.' ~« +Yw:-. w.M °~` '- i , ~`~~~ R ,+.. ~ -'~",~" a, .h,; ,r2.;. '=' !~ '.'`'`' •~.. _ D.lil w Ys ~ ~ w, •:. ,~. 4,.,'~.,sr... s,., ~." ,~ ,+. " + "~~# ~ ~t `r r°~"' • » .: >i `~~s*.,. .~ ~ '~` ~ fn~ ={1.600 '4,i +e.. ~~ +rAa a ,+N~r r ^ &., 6+7ytii'h~ - °, c.• , a yha ... _ ` ~ firr+.p 5 ',µ fd+i., ~ '~ H+ at . .;.,n. " '" P ~MNIM~r~~ w• .+..•, .~~say4s, Y+t. .;.~a D ~ ~ '"" ~ •, m ., ,; r ~~ •~.~. -• ,~ ~ "~^ •.. ~ ~,- a ••' ~ •' "r+ ~, y~ ={1.700 ~? - _ x.. ma>v, , ,,. °., ~3 .,tom a*+ ~. ~ ~,. •.,., :~. ,. r rr }y,:h,,, •„r ° ,-w `.+~ rx...,y„ "~ i'~: a = IiJ Y' ,.«,:. ~ -~' ~:W+,:p ..r, y,~,' - • ~+...,~ +~ ' "p ` r+ !~r ~r.c. , +9.b,u~ "`+'V~"~~ . ~ ry,;,a _ 0 c ~ `. w..N air"`. ...., {+.~,+-= t ~'~Tx~ ''•<.. 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'tiygy~ .+.r.y ~^r te'M~ira~ i 1 4 wv, Iraaa+as~R' ~s"-'hl~`l`H' a * °rtt Ci~+sr~i~ltfr'1"lA.q,..~`. t r.a=-n rr>,s .p`k~it ~ ti .. h, t`.;~,ta, ' _ -`reltii~nl,l; = 1 ~`giath~y•:.'Ar -a~'_tyy,j,, - ay~„.~wAllorfr+•= a"~,1!hs~hyei~MMr. ~_ _1.4DD ., lerr"~. w>. ,' a b .~~ r. _ • - sa.,) Mar G i 1.51 ,. w: ~. '< ,: , . ,. m..>.t xr ". >jt."~,wr; . ' Ha.e pn^.r, ~ =1.500 ah. M14tpMsW •,k... ~"-;.r-)ttY~'P/~?'~`•^ i :hna,'~.~',~s:r1-!'4R .r+..~-au,.ea w1s ., a~~{{~.; ~,~ .- - - ` ~ h- ..r i ~"Y' •e•+NYros ' r•. Ma., ;. . Frf~X .~ -x. _ l.lil '~„', 1 ~taw+~+1"= ,1,, ~ K w . , ~.w, 4-w.. r° a Kn ~ =1.600 1 .. 191 1J' .Y. : ~•' .+a, r .3r ~ .y: llyn H ' "~~ t y '"1 l i I ~r'rr.-~~'r)1+lhatt Mr".'S41Ip~i1/M~f" rl+r r- .'4S'y11n.,r- ~ ^afi~IFt4rea11'kMeplM :»atiH~'4hia.r ~ r• '~it'il"~°"0 - ,+teraurwyw ' Mfr. , ..r•) leu+,, t adi~'t!!?r~.wa AF ..,».., w ,arr. „ KI,., _1.70D w, re ! } ., =Y,..-,~T~ Mwfr, ad{+}.4 ) 111 t { t a, ~ ~~. at1 :' r= "t' ~)'t' ;>r '°"'aHrK~.~,r,, .yx ~r.~.,~.,.,t.~.~. ~~ „'ke 1-++wtW1~YMw «y r n,) "i ~?r7 ~4tnr«'""FtilhN~lt~N°M",+y _ I r x '" •aM raa•r A1i'w ~' ! r:., r 9~lMhk ~'~"^"'°'q+lyt' -., S Na>2 h ,, _ - i !h ro r',re5 rwa 4 ~N'Ar I i 1 s11 .• - ' 4..- ~~. ,..,.. r -1.soD - 1! IU ter'JsY r '''" t s. 17'1 ~ ~ ~,',N't''fazWr?Fn+rWt' t 1 I+~~ a_ I ,r"11MN~t'!P ,N ~,~",~'z',~,".pa!,y•ai~'~„w, 4yd ; :'`:"A1'y~~'`"~"`i~'~ .- .... , _'ra* I. ,~,rir '=ate'.+~,~wstiuaPt~ x. . )Ny~tx~}._~ »._._,,,: + ..u!" Figure 7. Interpreted fracture pressure gradient along line B-B'. tnl ~ 1`e `aT I- 12COC.OOC 11790.000 115-EO.000 11370.C00 11160 OGD 10960.000 10750.000 1052.6.000 1 Lt32CA06 10110G0C 9900.000 9690. GGO 94EL.6GG 9270,000 9064.604 E&56.000 E65U GC6 E436. Goo Ezz6.c4o EG 1 D.000 7E00.000 7=_~9C.DOU ??EQ C04 71?G.D40 s96o.600 F.75.0.000 654p.D04 s:~so.ooo 61 zo.c4o 591G.D00 57C0.000 5490.000 ezzc.4oG EOUC.U04 Figure 8. Original (unsmoothed) interval velocity profile along line A-A'. 1tGGaaoG 1 nsG aoG 115ac GGo 11370.000 111€0.000 10950.000 107':0.000 10530.000 103?L`.000 10110.000 e!9U0 C9D 9890 UCO 9<GQl OG0 92.70.C00 9UE0 000 8850 000 2;40 OG0 843U OG0 8 [O OCO 8010.600 7EUO.OOC 7590 UOU 7380.000 7170.000 0~0.00C 8750.000 c840.000 6330 OCO 0120.0A0 _910.000 8700.000 8490.000 S~E0.000 £000.000 • Figure 9. Original (unsmoothed) interval velocity profile along line B-B'. 0 I~ z r s ~. a~ 0 2000.0 2500.0 3000.0 3500.0 4000.0 4500.0 5000.0 1000.0 1400.0 1800.0 RFT Fnrmatinn Prpcc~~rp pgj • All Data -Hydrostat Winter Trails 1 2200.0 Figure 10. Depth plot of MDT fluid pressure data from regional wells. The MDT data from the Winter Trails 1 wells are plotted in orange and conform closely to the plotted hydrostatic line. The hydrostatic pressure line has a surface intercept at the sea level and a slope of .455 psi/foot u 2000" D e p t h f t 400U M -- u d 1 i ~ n e 6000' 800 ~n Pore Pressure (PPG) 12 14 16 :, ~ inter•_Tr•ai ls_1_M~l lJinter•_Trai Is_1 ~ ~ `~ ~ ~ ~ - - - ~ ._ ~• •~ U 2000 D e p t h f 4000 t -6000 M u d 1 i n e • -8000 Figure 11. Depth plot of mud weight data from the W_Sak_5 (orange), W_Sak_26 (purple), Winter Trails_1 (blue), Winter Trails_2 (black) and Winter Trails_3 (red) wells. Also posted are MDT data from the Winter Trails_1 well (cyan). ._.. z ~' e }~ f r~ u d 1 i n e U D 20Q0 ~ h f :~aaa ~ 60U0 Joao M u d 1 i n e . Figure 12. Depth plot of gamma ray, resistivity, neutron porosity, velocity, and density logs from the Winter Trails_1 (blue), Winter Trails_2 (orange), Winter Trails_3 (purple), W_Sak_5 (magenta) and the W_Sak_26 (cyan) wells. O ____ i 1`i~~ I I-'° e t h f t J L 1 1 ~v~er~ued~rr Stress ~}~si ~ ~ ~ ~ ~ ''1 ~k ~ ~ \. ~ * u -2Q~0 -~~~~ ~~~~ ~~~~ D e P . t h t J l ~~ 1 1 • ~QQ ~.d Figure 13. Density data from the Winter Trails_1 (blue), W_Sak_26 (cyan), and W_Sak_5 (magenta) wells. The blue data in the right track is the integrated vertical stress (overburden) from the red points in the left track. The red curve is a mathematical representation of the vertical stress. ~'~looit~r ~ ~~~ ~;~ ____ r--~ ~ ~~~ ~ ~ ~~ . }~ ~t 1 ~o~~ ~0~~ ~~~~ ~~~~ Figure 14. Sonic log (blue) from the W_Sak_5 well plotted with surface location interval velocity profile. e ~ ~ }y u 1 • ~'elocit~ ~f~~s~ O ~7 __._ ~ G7 ~ ~-.~~ ~ ~~~ti ~Z t h f ~t 1 1 u ~0~0 ~~~~ ~~~~ ~~~~ Figure 15. Sonic log (blue) from the Winter Trails_1 well plotted with the surface location interval velocity profile. t }~ f #r ~~ d 1 1 • ~7 I~ Z 1000 ~~ . .~ 2000 !~ ,~ 3 0 0 0 -- ! ~ - --- ~ ~ 4000 ~ ~ !~ ! 5000 ~: 6000 ~ ~~ 7000 5000 6000 7000 8000 9000 10000 11000 velocity, feet/second -•- Checkshot ~ G EO PRESS • Figure 16. Depth/interval velocity relations calculated for the 1ii/f_Sak_5 well from the Checkshot data (blue) at that well and from the interval velocity profile nearest the surface location (purple). 0 D r- 0 1000 2000 3000 4000 5000 6000 7000 8000 -Checkshot GEOPRESS .- .• .• .• - - _ • .• .• 5000 6000 7000 8000 9000 10000 11000 12000 Figure 17. Depth/interval velocity relations calculated for the W_Sak_26 well from the checkshot data (blue) at that well and from the interval velocity profile nearest the surface location purple). 0- 1000 - ,2000 - >3000 - C~ t ~- Q4000 - ~ o ~ 5000 - ~ ' ~ 6000 - 7000 0.000 0.200 0.400 0.600 0.800 1.000 1.200 Time, seconds -•- Checkshot • GEOPRESS ' ~. •• ~~ ~ y ~,., '~ ~ •. •. •. .~ 1.400 1.600 • Figure 18. Depth/time relations calculated for the W_Sak_5 well from the checkshot data (blue) at that well and from the interval velocity profile nearest the surface location (purple). O I- .. .. .~ .* •,~ •ri .~~t4• . ~ h ''~: .: . t . t •r '•i '~' . t ~'••.. . . ~ , .~ 0.000 0.200 0.400 0.600 0.800 1.000 1.200 1.400 1.600 Time, seconds • Checkshot ~ GEOPRESS 0 1000 2000 3000 .a 4000 ~ 5000 0 6000 7000 8000 r: Figure 19. Depth/time relations calculated for the W_Sak_26 well from the checkshot data (magenta) at that well and from the interval velocity profile nearest the surface location (blue). r .-~.. P'...~ 6DOi soo u 2000 D e P t h f 4000 t 600D soda Figure 20. Interval velocity data from the surface location for the Winter Trails_1 well along with a compaction profile (left track). The right track shows mud weight data and MDT data from the control wells. The Winter Trails_1 MDT and mud weight data are in cyan and blue. The red trend in the right track is fluid pressure interpretation from the red compaction model. Velocity (ft/s:) D e P t }y 200 f t 4001 M Ll d 1 1 n e Pore Pressure (PPG) 60 00 $0 00 10 00 12 00 0 2 4 6 anti g~~a_Uin#._33x33sm_ 4>;4 none I ~, ~,~:. -,~ ~ inter_Trails_1_MlJ lJinter_Trails 1 .~ _ _ _ j ~ I I 1 ~ ``:~ I~lir~,tar_ira:l _l_r~rt I~lint.rr_ Tr~il:__1 1 i i i i M Ll d 1 1 n e • Effective Stress (~sl) Y e 1 a c ~ -~ i ~~, t t I 12001 1000 8001 600 1i ~~~'`:-~ 1[ $( ~~ ~~ ooa 000 100 goo Figure 21. Effective stress/interval velocity data for the Winter Trails_1 MDT data (cyan) and the surface locations for the 5 control wells (W_Sak_5, blue; W_Sak_26, orange; Winter Trails_1, purple; Winter Trails_2, black; Winter Trails_3, red) for depths to about 6000 feet. e 1 0 c i t Y f t r O G7 z ~' r c~ m O 0 0 L O J 1 .20 1 .00 0.80 0.60 0.40 0.20 0.00 • • • ~ • • k 0 1,000 2,000 3,000 4,000 Depth, Feet TVDSS 5,000 6,000 • Figure 22. Depth plot of Leak-Off Tests (LOT) expressed as percentage of vertical stress. d w m Q V1 Q g' ~~ 0 -1,000 -2, 000 -3,000 -4, 000 -5, 000 -6, 000 -7,000 Pressure Gradient, ppg • All Data ^ LOT Series3 • Figure 23. Depth plat ~f Leak-Off Tests (LOT) expressed as pressure gradient, ppg. Data specifically characterized as LOT tests are highlighted in pink. 8.0 10.0 12.0 14.0 16.0 18.0 20.0 0 z D r ~'~el~city ~ft~s~ 600 0iD.00 10p00 1200 D ~ 2001 1~ t }~ f ~ X001 rt 1 001 ~~~ u D 2000 ~ • t }~ f X000 rt u ~~~~ 1 ~ • X000 Figure 24. Fluid and fracture pressure interpretation at the surface location of the W_Sak_5 well. The brown stars indicate mud weight data from the well. The pink line indicates an extension of fracture gradient into the permafrost where the model used to generate the brown fracture gradient curve is not valid. .~r~t i ~~~.aa_~ ~ i r-~t,_? ~~:~ ~~?~;r~~_~:~::~i r,~ ,r-,r~ D e t h t ~z ~ ~` u ~=t ~ I,I ~::: 1 i ~:. B ~elocit~ ~ft~s~ 6000 8000 10U00 12Q00 2001 4001 6001 ~00 U 2000 4000 6000 ~~~~ Figure 25. Fluid and fracture pressure interpretation at the surface location of the W_Sak_26 well. The brown stars indicate mud weight data from the well. The pink line indicates an extension of fracture gradient into the permafrost where the model used to generate the brown fracture gradient curve is not valid. ~~nt.i~-~~_a,~_~„ir-~t. ?~~::,:?~?~:;:r~,_~;~::4 r-.•.r-,r D t }~ t M u d 1 1 ~ . u e h f ~~ t ~~ ~-~ M ®_ ~ d ~~ 1 ~- i 2000 ~ t h f .~o0a ~ ?r[ u 1 ~a00 i X000 Figure 26. Fluid and fracture pressure interpretation at the surface location of the Winter Trails_1 well. The brown and blue stars indicate mud weight and MDT data from the well. The pink line indicates an extension of fracture gradient into the permafrost where the model used to generate the brown fracture gradient curve is not valid. U D e t }y ~ f ~ ~ ~, ~ ri ~°~~ u G~. ~ ~Y 1 2000 ~ ~ • }~ f Joao ~ u 1 ~~~~ 1 ri ~ • ~~~~ Figure 27. Fluid and fracture pressure interpretation at the TD location of the Winter Trails_2 well. The brown stars indicate mud weight data from the well. The pink line indicates an extension of fracture gradient into the permafrost where the model used to generate the brown fracture gradient curve is not valid. ~'el~~i ~ ft j ~ ~ 6000 8000 1000 12p00 f ~ ~ ~t u 1 _-~ 1 n ~ 2001 t h X001 6001 u D 2000 ~ • 1~ t }~ f X000 ~ M u d 1 6000 1 ~ • ~~~ ~ ~~~~ Figure 28. Fluid and fracture pressure interpretation at the surface location of the Winter Trails_3 well. The brown stars indicate mud weight data from the well. The pink line indicates an extension of fracture gradient into the permafrost where the model used to generate the brown fracture gradient curve is not valid. velocity ~ftj~j 6Q00 80.00 10Q00 12000 D e t h f t ~' ~ ~ u 1 1 e 2001 X001 X6001 ~~~ u 2000 X000 ~~OQ ~~~~ Figure 29. Fluid and fracture pressure interpretations at the Antigua location. Proposed TD is 6750 feet. The pink line indicates an extension of fracture gradient into the permafrost where the model used to generate the brown fracture gradient curve is not valid. ,=,r-~t. i ~=~~-a,~,~, ~ i r-~t ??~::~:; `~ `~:_:r~i_~:~::~ r,. ~r-,r, P e t }~ f t M ~l 1 1 e r ~ ~J a Pore Pressuuee CPPG~ ~~ ^~ ~~ 0 1000 2000 3000 .. a~ m w O 4000 a a~ 0 5000 6000 7000 8000 8.0 Figure 30. Edited interpretation of fluid and fracture pressures at the Antigua location. The shape of the fracture pressure profile above 1500 feet is very uncertain. • • 9.0 ~~ 510.0 11.0 12.0 13.0 14.0 15.0 16.0 17.0 18.0 Z, ~ -~ Pressure Gradient, ppg --O~rburden Fracture -Fluid • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk River Unit Non Pad Plan Antigua #1 Plan: Antigua #1 (wp04) Proposal Report 19 January, 2006 • HALLIBt.lRTON Sperry Drilling S~rvi~es c_ 0 e 0 N O 1 Z O c_ O O to L a a~ 0 `~ a~ a~ H Antigua #1 (wp04) .~ SHL ®1770ft FNL & 2358ft FWL -Sec 35 - T10N - R10E a __ ~ - _ _ =~tt y W ~ 6875ft MD, 6875ft TVD, SHL (p3 1770ft FNL 8 2358ft FWL -Sec 35 - T10N - R10E SHL ®1770ft FNL 8 2358ft FWL -Sec 35 - T10N - R10E - - ~; ~ 1 s" Base Perm I, I N,o,L.L.ISUaTOni South Hardline 8p~rry Drllliny 8KVbr•s -800 -700 -600 -500 -400 -300 -200 -100 0 100 200 300 West(-)/East(+) (200 ft/in) 9 5/8" Top West SaK Base West Sak K-10 K-5 7. H RZ Base HRZ K-t Top Kup C i - Base Kup C / LCU CASING DETAILS No TVD MD Name Size 1 105.00 105.00 16" 16 2 4005.00 4005.00 95/8" 9-5/8 3 6874.99 6874.99 7" 7 6875ft MD, 6875ft TVD, SHL Q 1770ft FNL 8 2358ft FWL -Sec 35 - 710N - R10E -5250 -4500 -3750 -3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 4500 5250 Vertical Section at 0.00° (1500 ft/in) T tN4zimuths to True North Magnetic North: 24.20° Magnetic Field Strength: 57556.9nT Dip Angle: 80.71 ° Date: 12/15/2005 Model: BGGM2005 400 500 600 FORMATION TOP DETAILS No.TVDPath TVDSS MDPath Formation 1 1375.00 1250 1375.00 Base Perm 2 3295.00 3170 3295.00 Top West SaK 3 3805.00 3680 3805.00 Base West Sak 4 4355.00 4230 4355.00 K-10 5 5870.00 5745 5870.00 K-5 6 6345.00 6220 6345.00 HRZ 7 6525.00 6400 6525.00 Base HRZ 8 6580.00 6455 6580.00 K-1 9 6640.00 6515 6640.00 Top Kup C 10 6675.00 6550 6675.00 Base Kup C / LCl ORIGINAI ConocoPhillips Alaska Halliburton Energy Services • Planning Report -Geographic HALLIBURTON Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-0rdinate Reference: Well Plan Antigua #1 Company: ConocoPhillips Alaska (Kuparuk) N D Reference: Arctic Fox Plan RKB @ 125.OOft (Estimated RKB (105a Project: Kuparuk River Unit M D Reference: Arctic Fox Plan RKB @ 125.OOft (Estimated RKB (105 Site: Kuparuk River Unit Non Pad No rth Reference: True Weil: Plan Antigua #1 Su rvey Calculation Method: Minimum Curvature Wellbore: Plan Antigua #1 Design: Antigua #1 (wp04) Project Kuparuk River Unit, North Slope Alaska, U nited States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Wall Plan Antigua #1 Well Position +N/S 0.00 ft Northing: 5,915,643.00 ft Latitude: 70° 10' 48.484" N +E/-W 0.00 ft Easting: 558,554.00 ft Longitude: 149° 31' 42.696" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 105.OOft Audit Notes: Version: Vertical Section: Phase: PLAN Depth From (TVD) +N/S (ft) (ff) 20.00 0.00 Tie On Depth: 20.00 +E/-W Direction (ff) (°) 0.00 0.00 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/S +EI-W Rate Rate Rate TFO (~) (°) (°) (~) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 20.00 0.00 0.00 20.00 0.00 0.00 0.00 0.00 0.00 0.00 6,875.00 0.00 0.00 6,875.00 0.00 0.00 0.00 0.00 0.00 0.00 1/19/2006 3:52:04PM ORIGINAL COMPASS 2003.11 Build 48 ,% ConocoPhillips Alaska Halliburton Energy Services Punning Report -Geographic Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Slte: Kuparuk River Unit Non Pad Well: Plan Antigua #1 Wellbore: Plan Antigua #1 Design: Antigua #1 (wp04) • HALLIBURTON Local Co-ordinate Reference: Well Plan Antigua #1 ND Reference: Arctic Fox Plan RKB Q 125.OOft (Estimated RKB (105+ MD Reference: Arctic Fox Plan RKB @ 125.OOft (Estimated RKB (105+ North Reference: True Survey Calculation Method: Minimum Curvature Planned Surv ey Antigua #1 (wp04) Map Map MD Inclination Azimuth ND SSND +N/S +E/-W Northing Easting DLSEV Vert Section lft) (°) (°) (h) (ft) (ft) (ft) (n) (~) (°/100ft) (ft) 20.00 SHL ~ 177 0.00 0ft FNL 8~ 2 0.00 358ft FW 20.00 L -Sec 35 - T10 -105.00 N - R10E -An 0.00 tigua #1 - 0.00 Polygon 5,915,643.00 558,554.00 0.00 0.00 100.00 0.00 0.00 100.00 -25.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 105.00 0.00 0.00 105.00 -20.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 16" 200.00 0.00 0.00 200.00 75.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 300.00 0.00 0.00 300.00 175.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 400.00 0.00 0.00 400.00 275.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 500.00 0.00 0.00 500.00 375.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 600.00 0.00 0.00 600.00 475.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 700.00 0.00 0.00 700.00 575.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 800.00 0.00 0.00 800.00 675.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 900.00 0.00 0.00 900.00 775.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 1,000.00 0.00 0.00 1,000.00 875.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 1,100.00 0.00 0.00 1,100.00 975.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 1,200.00 0.00 0.00 1,200.00 1,075.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 1,300.00 0.00 0.00 1,300.00 1,175.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 1,375.00 0.00 0.00 1,375.00 1,250.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 Base Perm 1,400.00 0.00 0.00 1,400.00 1,275.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 1,500.00 0.00 0.00 1,500.00 1,375.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 1,600.00 0.00 0.00 1,600.00 1,475.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 1,700.00 0.00 0.00 1,700.00 1,575.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 1,800.00 0.00 0.00 1,800.00 1,675.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 1,900.00 0.00 0.00 1,900.00 1,775.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 2,000.00 0.00 0.00 2,000.00 1,875.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 2,100.00 0.00 0.00 2,100.00 1,975.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 2,200.00 0.00 0.00 2,200.00 2,075.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 2,300.00 0.00 0.00 2,300.00 2,175.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 2,400.00 0.00 0.00 2,400.00 2,275.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 2,500.00 0.00 0.00 2,500.00 2,375.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 2,600.00 0.00 0.00 2,600.00 2,475.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 2,700.00 0.00 0.00 2,700.00 2,575.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 2,800.00 0.00 0.00 2,800.00 2,675.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 2,900.00 0.00 0.00 2,900.00 2,775.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 3,000.00 0.00 0.00 3,000.00 2,875.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 3,100.00 0.00 0.00 3,100.00 2,975.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 3,200.00 0.00 0.00 3,200.00 3,075.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 3,295.00 0.00 0.00 3,295.00 3,170.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 Top West SaK 3,300.00 0.00 0.00 3,300.00 3,175.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 3,400.00 0.00 0.00 3,400.00 3,275.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 3,500.00 0.00 0.00 3,500.00 3,375.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 3,600.00 0.00 0.00 3,600.00 3,475.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 3,700.00 0.00 0.00 3,700.00 3,575.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 3,800.00 0.00 0.00 3,800.00 3,675.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 3,805.00 0.00 0.00 3,805.00 3,680.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 Base West Sak 1/19/2006 3:52:04PM Page 3 of 5 ORIGINAI COMPASS 2003.11 Build 48 ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk River Unit Non Pad Well: Plan Antigua #1 Wellbore: Plan Antigua #1 Design: Antigua #1 (wp04) Local Co-0rdinate Reference: Well Plan Antigua #1 TVD Reference: Arctic Fox Plan RKB (~ 125.OOft (Estimated RKB (1051 MD Reference: Arctic Fox Plan RKB Q 125.OOft (Estimated RKB (1051 North Reference: True Survey Calculation Method: Minimum Curvature Planned Surv ey Antigua #1 (wp04) Map Map MD Inclination Azimuth ND SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (n) (°) (°) (ft) (ft) (ft) (ff) (ft) (~) (°/100ft) (~) 3,900.00 0.00 0.00 3,900.00 3,775.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 4,000.00 0.00 0.00 4,000.00 3,875.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 4,005.00 0.00 0.00 4,005.00 3,880.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 9 5/8" 4,100.00 0.00 0.00 4,100.00 3,975.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 4,200.00 0.00 0.00 4,200.00 4,075.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 4,300.00 0.00 0.00 4,300.00 4,175.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 4,355.00 0.00 0.00 4,355.00 4,230.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 K-10 4,400.00 0.00 0.00 4,400.00 4,275.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 4,500.00 0.00 0.00 4,500.00 4,375.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 4,600.00 0.00 0.00 4,600.00 4,475.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 4,700.00 0.00 0.00 4,700.00 4,575.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 4,800.00 0.00 0.00 4,800.00 4,675.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 4,900.00 0.00 0.00 4,900.00 4,775.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 5,000.00 0.00 0.00 5,000.00 4,875.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 5,100.00 0.00 0.00 5,100.00 4,975.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 5,200.00 0.00 0.00 5,200.00 5,075.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 5,300.00 0.00 0.00 5,300.00 5,175.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 5,400.00 0.00 0.00 5,400.00 5,275.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 5,500.00 0.00 0.00 5,500.00 5,375.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 5,600.00 0.00 0.00 5,600.00 5,475.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 5,700.00 0.00 0.00 5,700.00 5,575.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 5,800.00 0.00 0.00 5,800.00 5,675.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 5,870.00 0.00 0.00 5,870.00 5,745.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 K-5 5,900.00 0.00 0.00 5,900.00 5,775.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 6,000.00 0.00 0.00 6,000.00 5,875.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 6,100.00 0.00 0.00 6,100.00 5,975.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 6,200.00 0.00 0.00 6,200.00 6,075.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 6,300.00 0.00 0.00 6,300.00 6,175.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 6,345.00 0.00 0.00 6,345.00 6,220.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 HRZ 6,400.00 0.00 0.00 6,400.00 6,275.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 6,500.00 0.00 0.00 6,500.00 6,375.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 6,525.00 0.00 0.00 6,525.00 6,400.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 Base HRZ 6,580.00 0.00 0.00 6,580.00 6,455.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 K-1 6,600.00 0.00 0.00 6,600.00 6,475.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 6,640.00 0.00 0.00 6,640.00 6,515.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 Top Kup C 6,675.00 0.00 0.00 6,675.00 6,550.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 Base Kup C / LCU 6,700.00 0.00 0.00 6,700.00 6,575.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 6,800.00 0.00 0.00 6,800.00 6,675.00 0.00 0.00 5,915,643.00 558,554.00 0.00 0.00 1/19/2006 3:52:04PM Page 4 0(5 COMPASS 2003.11 Build 48 • Halliburton Energy Services ~ HALLIBURTON Planning Report -Geographic Sperry Drilling Services ORIGINAL ConocoPhillips Alaska Halliburton Energy Services Planning Report -Geographic Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk River Unit Non Pad Well: Plan Antigua #1 Wellbore: Plan Antigua #1 Design: Antigua #1 (wp04) HALLIBLJFRTON ------ Spsrry Drllling Ssnricss Local Co-ordinate Reference: Well Plan Antigua #1 TVD Reference: Arctic Fox Plan RKB @ 125.OOft (Estimated RKB (1051 MD Reference: Arctic Fox Plan RKB @ 125.OOft (Estimated RKB (105+ North Reference: True Survey Calculation Method: Minimum Curvature tanned Survey Antigua #1 (wp04) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section tft) (°) (°) (ft) (ft) (ft) lft) (ft) (ft) (°/100ft) (ft) 6,875.00 0.00 0.00 6,875.00 TD ~ 6875ft MD, 6875ft TVD, SHL Q 1770ft F 6,750.00 NL 8 2358ft F 0.00 WL • Sec 35 0.00 - T10N - R10 5,915,643.00 E - 7" 558,554.00 0.00 0.00 Geologic Targets Plan Antigua #1 TVD (ft) 20.00 - Polygon Point 1 Point 2 Point 3 Point 4 Target Namrr +NI-S +E/-W Northing - Shaa'~r ft ft (ft) Antigua #1 - Polygon 445.11 -432.84 5,916,084.70 0.00 0.00 5,916,084.70 558,117.77 700.03 -5.42 5,916,084.70 558,817.75 494.94 -658.90 5,915,429.71 558,617.75 -5.07 -655.03 5,915,429.71 558,117.77 Easting (ft) 558,117.77 Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (") 105.00 105.00 16 16 4,005.00 4,005.00 9-5/8 12-114 6,874.99 6,874.99 7 8-1/2 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W Name (ft) (°) (°) (ft) (ft) tft) 1,375.00 0.00 0.00 1,375.00 0.00 0.00 Base Perm 3,295.00 0.00 0.00 3,295.00 0.00 0.00 Top West SaK 3,805.00 0.00 0.00 3,805.00 0.00 0.00 Base West Sak 4,355.00 0.00 0.00 4,355.00 0.00 0.00 K-10 5,870.00 0.00 0.00 5,870.00 0.00 0.00 K-5 6,345.00 0.00 0.00 6,345.00 0.00 0.00 HRZ 6,525.00 0.00 0.00 6,525.00 0.00 0.00 Base HRZ 6,580.00 0.00 0.00 6,580.00 0.00 0.00 K-1 6,640.00 0.00 0.00 6,640.00 0.00 0.00 Top Kup C 6,675.00 0.00 0.00 6,675.00 0.00 0.00 Base Kup C / LCU 1/19/2006 3:52:04PM Page 5 of 5 COMPASS 2003.11 Build 48 ORIGINAL An~jua #1 Planned Completion Schematic (Long String) Exploration Well -Confidential (Arctic Fox - 20'KLCB) Conductor (80'): 16", 62.58# Set @ +/- 100' MD / 100' ND Float Collar: Weatherford -Single Valve 9-5/8" 32-53# BTC Box x Pin (2) Joints Casing: 9-5/8" 40# L-80 BTC Float Shoe: Weatherford -Single Valve 9-5/8" 32-53# BTC Box Up Surface Casing 9-5/8" 40# L-80 BTC Set @ +/- 4,005' MD / 4,005' ND X200' MD Be%w Base W. Sak ConocoPhillips Tubing Hanger: Vetco Hanger w/ 3-1/2" L-80 EUE 8rd Mod pup joint installed (Special Drift Hanger to 2.910" w/ Pup Joint Installed). Spaceout Tubing Pups (as required ): 3-1/2", 9.3#, L-80, EUE 8rd Mod (Special Drift Tubing to 2.910") Tubing (as required ): 3-1/2", 9.3#, L-80, EUE 8rd Mod (Special Drift Tubing to 2.910") Landing Nipple: 3-1/2" Camco'DS-Nipple' wJ 2.875" No-Go Profile set @ +/- 500' MD / ND-RKB (CS Lock = 2.906" OD) Tubing (as required ): 3-1/2", 9.3#, L-80, EUE 8rd Mod Gas Lift Mandrel (4 Total): 3-1/2" x 1" Camco'KBUG' GLM wJ dummy valves and latches, 6' handling pups installed on top and bottom Position GLM's in the following locations: M1Q IYQ Tubing (as required): 3-1/2" 9.3# L-80 EUE 8rd Mod Gas Lift Mandrel (i Total): 3-1/2" x 1-1/2" Camco ~MMG' GLM w/ Dump Kill Valve (3000 psi casing to tubing shear). 6' handling pups installed on top and bottom Tubing (i Joint): 3-1/2" 9.3# L-80 EUE 8rd Mod Sliding Sleeve: Baker 3-1/2" CMU Sliding Sleeve w/ 2.813" Camco ADS' No-Go Profile (Lock = 2.856" OD), EUE 8rd Box x Pin, 6' handling pups installed on top and bottom Tubing (1 Joint): 3-1/2", 9.3#, L-80, EUE 8rd Mod PBR /Packer Assembly, by Baker Oil Tools, consisting of the folbwing: Packer SettingQa to h TBD Handling Pup Joint: 3-1/2", 9.3#, L-80, EUE 8rd Mod (6 foot length) Polished Bore Recepticle with Seal Stem: Baker, 3-1/2'80-40' PBR w/ 12 ft of seal travel, pinned to shear with 39 KSI overpull Packer: Baker, 7" x 3-1/2"'FHL' (Retrievable Packer) Handling Pup Joint: 3-i/2", 9.3#, L-80, EUE 8rd Mod (6 foot length) Float Collar: Weatherford -Single Valve 7" 20-35# BTC Box x Pin (2) Joints Casing: 7" 26# L-80 BTC Float Shoe: Weatherford -Single Valve 7" 20-35# BTC Box Up Production Casing 7" 26# L-80 BTC Set @ +/- 6,875' MD / 6,875' ND ^200' MD Be%w Base Ku,oaruk Tubing (1 Joint ): 3-1/2", 9.3#, L-80, EUE 8rd Mod Gas Lift Mandrel: 3-1/2" x 1" Camco 'KBUG' GLM w/ dummy valves and latches, 6-foot handling pups installed on top and bottom. Tubing /Pup Joints (as required ): 3-1/2", 9.3#, L-80, EUE 8rd Mod Gas Lift Mandrel: 3-1/2" x 1" Camco 'KBUG' GLM w/ dummy valves and latches, 6-foot handling pups installed on top and bottom. Tubing /Pup Joints (as required ): 3-1/2", 9.3#, L-80, EUE 8rd Mod Landing Nipple: 3-1/2" Halliburton'XN' Nipple w/ 2.750" No-Go Profile Tubing /Pup Joints (as required ): 3-1/2", 9.3#, L-80, EUE 8rd Mod Wireline Re-entry / Shearout: 3-1/2" Baker Mtigua #1 Schematk v2.0 prepared by Mark Chambers 01/23/06 CemCADE Preliminary Job Design 9 5/8" Surface Casing Preliminary Jab Design based on limited input data. Fa es°mate purposes only. Rig: Arctic Fox Location: Exploration Client: ConocoPhillips Alaska, Inc. Revision Date: 1/26/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface Previous Csg. < 16", 62.6# casing at 100' MD < Base of Permafrost at 1,375' MD (1,375' ND) Volume Calculations and Cement Systems Volumes are based on 300% excess in the permafrost and 50% excess below the permafrost. The top of the tail slurry is designed to be at 2,795' MD. Lead Slurry Minimum pump time: 220 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 0.7632 ft3/ft x (100') x 1.00 (no excess) = 76.3 ft3 0.3132 ft3/ft x (1375' - 100') x 4.00 (300% excess) = 1597.3 ft3 0.3132 ft3/ft x (2795' - 1375') x 1.50 (50% excess) = 667.1 ft3 76.3 ft3 + 1597.3 ft3+ 667.1 ft3 = 2340.7 ft3 2340.7 ft3 / 4.45 ft3/sk = 526 sks Round up to 530 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 150 min. (pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/sk 0.3132 ft3/ft x (4005' - 2795') x 1.50 (50% excess) = 568.5 ft3 0.4257 ft3/ft x 80' 3(Shoe Joint) = 34.1 ft3 568.5 ft3 + 34.1 ft = 602.6 ft3 602.6 tt3/ 2.25 ft3/sk = 267.8 sks Round up to 270 sks BHST = 93°F, Estimated BHCT = 87°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) < Top of Tail at 2,795' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 4,005' MD (4,005' TVD) i Mark of Schlumtterger CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW 100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL 7.0 416.9 59.6 92.9 DeepCRETE 6.0 107. 17.9 110.8 Drop top plug 0.0 0.0 5.0 115.8 Water 5.0 20.0 4.0 119.8 Switch to rig 0.0 0.0 5.0 124.8 Mud 7.0 268. 38.4 163.2 Slow & bump plug 3.0 9.0 3.0 166.2 MUD REMOVAL Recommended Mud Properties: 10 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, Pv ? 17-21, TY ? 20-25 Centralizers: Recommend 1 per joint on the shoe track and 1 every other joint throughout the tail slurry. g ~ ' ~ ~ ~11 Ce+CAQE i?reliminary JQb pesgn 7" Production Casing.: Preliminary Job Design based On Iimite0 input data. Fa estimate purposes only. Rig: Arctic Fox Location: Exploration Client: ConocoPhillips Alaska, Inc. Revision Date: 1 /26/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263.4207 Mobile: (907) 748-6900 email: martin13@slb.com Previous Csg. < 9 5/8", 40.0# casing at 4,005' MD < Top of Tail at 6,140' MD < 7", 26.0# casing in 8 1/2" OH TD at 8,875' MD (6,875' TVD) Volume Calculations and Cement Systems Volumes are based on 40% excess. Tail slurry is designed for 500' MD above target - (735' MD annular length). Tail Slurry Minimum thickening time: 150 min. (Pump time plus 90 min.) 15.8 ppg Class G + 2.0 gpS D600G + 0.05% 6155 + 0.3% D65 + 0.2 gps D47 - 1.17 ft3/sk 0.1268 ft3/ft x 735' x 1.40 (40% excess) = 130.5 ft3 0.2148 ft3/ft x 80' (Shoe Joint) = 17.2 ft3 130.5 ft3 + 17.2 ft3 = 147.7 ft3 147.7 ft3/ 1.17 ft3/sk = 126.2 sks Round up to 130 sks BHST = 162°F, Estimated BHCT = 125°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 10.0 2.0 14.0 Drop bottom plug 0.0 0.0 5.0 19.0 MUDPUSH II 5.0 30.0 6.0 25.0 Kuparuk Tail 5.0 26.3 5.3 30.3 Drop top plug 0.0 0.0 5.0 35.3 Water 5.0 20.0 4.0 39.3 Switch to rig 0.0 0.0 5.0 44.3 Mud 6.0 231.0 38.5 82.8 Slow & bump plug 3.0 9.0 3.0 85.8 MUD REMOVAL Recommended Mud Properties: 10.2 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.0 ppg MudPUSH* II, Pv ? 19-22, TY ? 22-29 Centralizers: Recommend 1 per joint on shoe track and 1 per 2 joints to TOC ~ ~, $, i , 3 i r"_ ~ig ua # 1 • Contingency -Completion Schematic (Top Set) ~ +~ Exploration Well -Confidential ~~~~~ (Arctic Fox - 20' RKB) Conductor (80'): Tubing Hanger: Vetco Hanger w/ 3-1/2" L-80 EUE 8rd Mod pup joint 16", 62.58# installed (Special Drift Hanger to 2.910" w/ Pup Joint Installed). Set @ +/- 100' MD / 100' TVD Spaceout Tubing Pups (as required): 3-1/2" 9.3# L-80 EUE 8rd Mod (Special Drift Tubing to 2.910") Tubing (as required): 3-1/2" 9.3# L-80 EUE 8rd Mod Float Collar: (Special Drift Tubing to 2.910") Weatherford -Single Valve ~ ~:.'-,~ s% 9-5/8" 32-53# BTC Box x Pin Landing Nipple: 3-1/2" Camco'DS-Nipple' w/ 2.875" No-Go Profile set @ +/- 500' MD / TVD-RKB (CS Lock = 2.906" OD) (2) Joints Casing: _ 9-5/8" 40# L-80 BTC Tubing (as required): 3-1/2" 9.3# L-80 EUE 8rd Mod Float Shoe: Gas Lift Mandrel (4 Total): 3-1/2" x 1" Camco'KBUG' GLM w/ dummy Weatherford -Single Valve ,,,.,. , valves and latches, 6' handling pups installed on top and bottom 9-5/8" 32-53# BTC Box Up ''''` Position GLM's in the following locations: Surface Casing: " ~ ~p 9-5/8" 40# L-80 BTC ---- Set @ +/- 4,005' MD / 4,005' TVD --- ~200' MD Be%w Base W. Sak -- Float Collar: Weatherford -Single Valve 7" 20-35# BTC Box x Pin (2) ]oints Casing: 7" 26# L-80 BTC Float Shoe: Weatherford -Single Valve 7" 20-35# BTC Box Up Intermediate /Production Casing: 7" 26# L-80 BTC Set @ +/- 6,565' MD / 6,565' TVD Be%w Base HRZ Production Liner: 3-'/z" 9.3# L-80 EUE 8rd Mod Set @ 6,875' MD / 6,875' TVD X200' MD Be%w Base Kuparuk Tubing (as required): 3-1/2" 9.3# L-80 EUE 8rd Mod Gas Lift Mandrel (1 Total): 3-1/2" x 1-1/2" Camco ~MMG' GLM w/ Dump Kill Valve (3000 psi casing to tubing shear). 6' handling pups installed on top and bottom Tubing (1 Joint): 3-1/2" 9.3# L-80 EUE 8rd Mod Sliding Sleeve: Baker 3-1/2" CMU Sliding Sleeve w/ 2.813" Camco 'DS' No-Go Profile (Lock = 2.856" OD), EUE 8rd Box x Pin, 6' handling pups installed on top and bottom Tubing (1 Joint): 3-1/2" 9.3# L-80 EUE 8rd Mod Liner Top Packer /Hanger Assembly (Non-Rotating): Packer Setting.~~th Planned Ca 150' above 7" Casing Shoe Packer: Baker 5" x 7" ZXP Liner Top Packer w/ C-2 Profile (5.969" OD, 4.408" ID) Hanger: Baker 5" x 7" HMC Liner Hanger (5.924" OD, 4.408" ID) Seal Bore Receptacle (SBR): Baker 80-40 Casing Seal Bore Receptacle 17' w/ 15' of Effective Seals (5" OD, 4" ID) Crossover Sub: Baker 4-1/2" Stub Acme Box x 3-1/2" EUE 8rd Mod Pin Production Liner: 3-1/2" 9.3# L-80 EUE 8rd Mod Landing Collar: Baker w/ 3-1/2" EUE 8rd Mod Box x Pin (1) Joints Casing: 3-1/2" 9.3# L-80 EUE 8rd Mod Float Collar: Baker -Single Valve w/ 3-1/2" EUE 8rd Mod Box x Pin (2) Joints Casing: 3-1/2" 9.3# L-80 EUE 8rd Mod Float Shoe: Baker -Single Valve w/ 3-1/2" EUE 8rd Box Up _i Antigua #i Schematic v1.0 prepared by Mark Chambers 01/23/06 CernGAL3E Preliminary Job 1]esign 9 518" Star#aee CaSjng PreGminary Job Design based on limited input data. Fa estimate purposes only. Rig: Arctic Fox Location: Exploration Client: ConocoPhillips Alaska, Inc. Revision Date: 1/26/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 '~ email: martinl3(c))slb.com < TOC at Surface Previous Csg. < 16", 62.6# casing at 100' MD < Base of Permafrost at 1,375' MD (1,375' TVD) Volume Calculations and Cement Systems Volumes are based on 300% excess in the permafrost and 50% excess below. the permafrost. The top of the tail slurry is designed to be at 2,795' MD. Lead Slurry Minimum pump time: 220 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 0.7632 ft3/ft x (100') x 1.00 (no excess) = 76.3 ft3 0.3132 ft3/ft x (1375' - 100') x 4.00 (300% excess) = 1597.3 ft3 0.3132 ft3/ft x (2795' - 1375') x 1.50 (50% excess) = 667.1 ft3 76.3 ft3 + 1597.3 ft3+ 667.1 ft3 = 2340.7 ft3 2340.7 ft3! 4.45 ft3/sk = 526 sks Round up to 530 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 150 min. (pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/sk 0.3132 ft3/ft x (4005' - 2795') x 1.50 (50% excess) = 568.5 ft3 0.4257 ft3/ft x 80' Shoe Joint) = 34.1 ft3 568.5 ft3 + 34.1 ft = 602.6 ft3 602.6 ft3/ 2.25 ft3/sk = 267.8 sks Round up to 270 sks BHST = 93°F, Estimated BHCT = 87°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) < Top of Tail at 2,795' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 4,005' MD (4,005' TVD) Mark of Schlumklerger CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 AS 7.0 416. 59. 92.9 DeepCRETE 6.0 107.3 17.9 110.8 Drop top plug 0.0 0.0 5.0 115.8 Water 5.0 20.0 4.0 119.8 Switch to rig 0.0 0.0 5.0 124.8 Mud 7.0 268. 38.4 163.2 Slow & bump plug 3.0 9.0 3.0 166.2 MUD REMOVAL Recommended Mud Properties: 10 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* 11, Pv ? 17-21, TY ? 20-25 Centralizers: Recommend 1 per joint on the shoe track and 1 every other joint throughout the tail slurry. Rig: Arctic Fox Location: Exploration Client: ConocoPhillips Alaska, Inc. Revision Date: 1/26/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 2634207 Mobile: (907) 748-6900 email: martinl3@slb.t:om Previous Csg. < 9 5!8", 40.0# casing at 4,005' MD < Top of Tail at 5,765' MD < 7", 26.0# casing in 8 1/2" OH TD at 6,565' MD (6,565' TVD) aE Preliminary Job Design 7'" Top Set Casing 1gn based on Gmfted input data. For estimate purples only r r (' ' r Volume Calculations and Cement Systems Volumes are based on 40% excess. Tail slurry is designed for 800' MD annular length. Tail Slurry Minimum thickening time: 140 min. (Pump time plus 90 min.) 15.8 ppg Class G + 0.2%D46, 0.3%D65, 0.08%B155, 0.4% D167 - 1.16 ft3/sk 0.1268 ft3/ft x 800' x 1.40 (40% excess) = 142.0 ft3 0.2148 ft3/ft x 80'3(Shoe Joint) = 17.2 ft3 142.0 ft3 + 17.2 ft = 159.2 ft3 159.2 ft3/ 1.16 ft3/sk = 137.2 sks Round up to 140 sks BHST = 155°F, Estimated BHCT = 120°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time Ibbll (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 10.0 CW100 5.0 10.0 2.0 2.0 Drop bottom plug 0.0 0.0 5.0 17.0 MUDPUSH II 5.0 30.0 6.0 23.0 Tail 5.0 28.4 5.7 28.7 Drop top plug 0.0 0.0 5.0 33.7 Water 5.0 20.0 4.0 37.7 Switch to rig 0.0 0.0 5.0 42.7 Mud 7.0 219.1 31.3 74.0 Slow & bump plug 3.0 9.0 3.0 77.0 MUD REMOVAL Recommended Mud Properties: 10.2 ppg., Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.0 ppg MudPUSH* 11, Pv ? 19-22, TY ? 22-29 Centralizers: Recommend 1 per joint in shoe track and 1 per 2 joints to TOC . ,.. .~~~ Pr~it~ir~ary J'ob Qesign S°1J~" Liner Rig: Arctic Fox Location: Exploration Client: ConocoPhillips Alaska Revision Date: 1 /26/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263~t207 Mobile: (907) 748-6900 email: martinl3@slb.rom Top of Tail at < 6,215' MD < Liner Top at 6,415' MD Previous Csg. 7", 26.0# casing at 6,565' MD Prelimirrdry Job Design Dared an Nmited input data. For estimate pur{wses only S6hl~ml~rger Volume Calculations and Cement Systems Volumes are based on 40% excess. Displacement is calculated with a 4.0"- 14.0# drill string. Tail Siurrv Minimum thickening time: 110 min. (pump time plus 90 min.) 15.8 ppg Class G + 2.0 gps D600G + 0.05% 8155 + 0.3% D65 + 0.2 gps D47 - 1.17 ft3/sk Liner Cap: 3 0.1276 ft /ft x 200' x 1.00 (no excess) = 25.5 ft Liner Lap: 0.1480 ft3/ft x (6565' - 6415') x 1.00 (no excess) = 22.2 ft3 Annular Volume: 0.1378 ft3/ft x (6875' - 6565') x 1.40 (40% excess) = 59.8 ft3 Shoe Volume: 0.0488 ft3/ft x 80' x 1.00 (no excess) = 4.4 ft3 Totals: 25.5 ft3 + 22.2 ft3 + 59.8 ft3 + 4.4 ft3 = 111.9 ft3 111.9 ft3( 1.17 ft3/sk = 95.6 sks Round up to 100 sks BHST = 162°F, Estimated BHCT = 125°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbll (min) (min) < 3 1/2", 9.3# casing in 6 1/8" OH TO at 6,875' MD (6,875' TVD) Mark of Schlumt-erger CW100 4.0 10. 2.5 2.5 Pressure test lines 0.0 0.0 10.0 12.5 MUDPUSH II 4.0 20. 5.0 17.5 Kuparuk Tail 4.0 19. 5.0 22.5 Drop wiper dart 0.0 0.0 5.0 27.5 Wate 4.0 5.0 1.3 28.8 Switch to rig 0.0 0.0 5.0 33.3 Mud 4.0 62. 15.7 49.0 Slaw - p!u wiper plug and bump 2.0 5.0 2.5 51.5 MUD REMOVAL Recommended Mud Properties: 10.2 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.0 ppg MudPUSH" 11, Pv ? 19-22, TY ? 22-29 Centralizers: Recommend 1 per joint from 6415' MD to TD for proper cement placement. :.t " „~ ~~~ _.-- 4, to DOGHOUSE w! SLIDE OUT LUNCH ROOM AND TONG ROOM ON END BOP HANDLING TROLLEY ~~ 8 RIGMASTER P-750 ONE PIECE SUB w/ TELESCOPIC DOUBLE MAST AND TSM-7000H DRAWWORKS SKATE TYPE POWER CATWALK WITH TWO ENCLOSED CASING SHEDS AND ONE ENCLOSED PIPE TUB. AIR HEATER DETROIT 60 SERIES 400 kW 600 V GENS ~FUELTANK 8450 gal. (32,000 I) ~ FUEL & WATER PUMP ROOM of h M N ~ WATER TANK ~ 370 Barcels (59 m3 TWO 100 HP BOILERS WORK BENCH, AIR COMPRESSORS AND PARTS STORAGE 180 gal 6 STATION ACCUMULATOR THREE GARDNER DENVER PZ-8 MUD PUMPS POWERED BY 3412 E CAT MOTORS CUTTINGS PROCESSOR mw.e w.anendryr tlw mda~e) - abetah water tank 1' (Net water) - eaNd eemM atom MNarb d.h. - maarcy acaN rook (eeebhtarepan lwase) - aay nnw in Den roan -waDxbubr - uDdeted mud mNa, bdbia - modlry maNfdd eMck - EaorNN Imk (below stNm) - eed ab habr8 wltlnpe DrooaeaDr -update alraunpreworv - rtwve doDlau Bo/ wabrbnk out -19' - InaeaN dletenoe betaaen hnb 8 aub - uptlste balers, Wmla, snQlna0. exam man byan, NN roan loran ~OYON DRILLING WIILL~NO TwD. Rea! Ba easel, NIeIN NbsN TDE n1 Tel: D80) 8a60i0a The Inromroden eoneelnsd In d11e drnvlnp lathe Jolnt property otAIgTA DAlling Ltd. My roproduatlon In wMele or pert wkhout fhe sgrroa wnllen wnesnt of AICrtA Dmuna Ltd b prehlbhed. " tnnaros e-per.. DRN we l.eyout Doyon Aleeka Pioneer Resouraea - Doydn DAlilnp Aleaka Expbratlon Rip Layout • • ®RILLING OR®ER No. 20933.0-Si4 i4KR-sOW-1.0 Exhibit C RIG and EQUIPMENT INFORM~-TION/ INVENTORY DESCRIPTION OF RIG EQTJIPMISIT PROVIDID BY CONTRACTOR Rig Number: Arctic Fox 1 Depth Capacity of: 10000'(3050m with 4'/z" f114mm) Drill Pipe and BHA DRAWWORK5 Make: TSM or ltigmas[er equivalent ModeL• TSM 7000 or equivalent Input Power Rating: 750 Ho (560 kW) Maximum Hoisting Capacity: 4000001bs (178000 daN) (Ivlarnrfacturers) Maximum Hoisting Capacity: 3600001bs (160000 daN) (Contractors) No. of Hoisting Speeds:..4 Auxiliary Brake: Type: Water-cooled Disc Brake Make: Parlcersbure Model: 324 WCBD Crown Block Protection: Yes Make: CrownAleR Model: Drive Group: Make: Detroit Diesel Model: 14L 60 Series Type: Diesel Input Power Rating: 600 Ho (448 kW) PRIME MOVER Engine #1 Engine.#2 Engine #3 Engine #4 Make: Detroit Diesel Model: 14L 60 Series Continuous Power 600Hn(448kW) (a) RPM 2100 PRIME MOVER (Electric Rigs Only) Generator#1 Generator#XL Generator#3 Generator #4 Make: Model: Power Rating (kW) kVA-AC kVA-DC ROTARY TABLE Make: National or equivalent Mode1• G205 or equivalent Maximum Table Opening: 20'h" (SZI mm) Power Available: 600 Ho (448 kW) -when Operating Main Pomp Static Load Rating: SOOOOO lbs (222.400 daN) Rotary Speeds: Forward 4 Maximum RPM 180 Minimum RPM 20 Reverse 1 Maximum RPM 2 Murinrum RPM Drive Grwp: Make: TSM or equivalent Model: 7000 or equivalent .Type: Vertical Input Power Rating: 200 Ho (150 kW) Kelly: Size & Type: 4'/," Square Length: 40' DERRICK Make; Rigmaster ModeL• T1049.5-400E Type: Telescopic Maximum Hook Load (Manufac4uers) 4000001bs (178000 daN) with 8 Lmes Maximum Hook Load (Contractors) 360000 Ibs (160000 daN) with 8 Lines Racking Capacity of 10000' 3 SO m) of 4,'3/_'_(114 mmL Drdl Pipe and BHA Racking Capacity of 11800' (3600 m) of 4 " (102 mm) Drill Pipe and BHA Height 31.7 meters. Hook to Rotary Table Distance w/Blocks at Crown Stop 90' (27.6 m) Date of Last Inspection: N/A SUBSTRUCTURE Make; Rimnaster Model: ST-1414.2-3000 Type: Step Down Max. Table Load (Casing Capacity) 3370001bs (150000 daN) with 281000 Ibs (125000 daN) Maximum Setback KB to Ground: 18'9" (5.7 m) (with ponv sub) ClearHeight for BOFs:15' 3° (4.65 m) (with pony sub) Pony Sub Height: 4- C-1 ~~~~~'a ~ • TRAVELLING EQUIPMENT Crown Blks Travel Blks Hook Bails Elevators Swivel Make: Rigmaster McKinney Mickinnev B7 MGG National Model: f3LR"a?"/212a° Arctic 200 Arctic 200 2'/a"x96"x250T 4 I/2" x 18° N=47 Load Rating (lbs/daN) 400000/178000 400000/178000 400000/178000 500000/222400 400000/178000 400000/17800 # of Sheaves 6 4 NIA N/A N/A N/A API Bearing Rating (lbs/daN) N/A N/A N/A N/A N/A 212000!94234 ~ ~ N/A N/A N/A N/A " in.I.D (u mm) M N/A N/A NIA N/A N/A /76mm 3 Date of Lest Inspection: N/A DRILLING LINE Rope Diameter 1 1/8" (28.6 mm) Rope Type 6 X 19 EIPS Core Type IWRC Nominal Strength 1300001bs (57800 daN) Slip Interval at Mega Joules Cut at Mega joules DEADLINE ANCHOR Make: Rietnaster Model: Dead Load Rating: daN MUD PUMPS Pump #1: Make: National ModeL• 8-P-80 or eo uiv. Power Rating: S00 Hp (596 kW) Make: Cateroillaz Model: 3412 DITA Continuous Power. 550 Ho (410 kW3 RPM: 1200 Stroke: 8.5" (216mm) pulsation Dampner: Make: Hvdril Model: K-20.5000 Prechatge 5000 osi (3500 kPa) Liner Sizes Available 4 'h" (114mm). Minimum Strokes/min 60 spm 5" (127mm) 6" 152mm 60 spm 60 spm - Maximum Strokes/min 120 spm 120 spm 120 spm Max Manuf. Rated press. 4395 nsi (30300 kPa) 3553 osi (24500 kPa) 2470 osi (17000 kPa) Max Cont. Allowable Press. 3516 nsi (24300 kPa) 2842 usi (19600 kPa) 1972 usi (13600 kPa) Pump #2: Make: National Model- 8-P-SO or eo uiv. Power Rating: 800 Ho (596 kW) Make: CaterQillaz Model: 3412 DTTA Continuous Power: 550 Hp1410 kl~ RPM 1200 Stroke: 8.5" (216mm) Pulsation Dampner: Make: Hydril Model: K-20.5000 Precharge 5000 osi (3500 kPa) Liner Sizes Available 4'h" (114mm1 5" (127mm) 6" (152mm) Mmimum Strokes/min. 60 spm 60 spm 60 spm Maximum Strokes/min 120 spm 120 spm 120 spm Max Manuf. Rated Press. 4395 i 30300 kPa 3553 i 24500 kPa 2470 osi (17000 kPa) Max Cont Allowable Press. 3516 psi (24300 kPal 2842 psi (19600 kPa) 1972 Qom[ 13600 kPa) Pump #3: Make: National Model: 8-P-80 or ec nuv. Power Rating: 800 Hn (596 k4V1 Make: Caterpillar Model: 3412 DTTA Continuous power. 550 Ho (410 kVJ1RPM: 1200 Stroke: 8.5° (216mm) Pulsation Dampner. Make: H~iril Model: K-20-5000 Precharge 5000 psi (3500 kPa) Liner Sizes Available 4'/z" (114mm). 5" (127mm) 6" 152mm Muumum Stmkeslmin. 60 spm 60 spm 60 spm Mmamum Strokes/min. 120 spm 120 spm 120 spm Max Manuf. Rated Press. 4395 nsi (30300 kPa) 3553 osi (24500 kPa) 2470 psi (17000 kPa) Max. Cont. Allowable Press. 3516 nsi (24300 kPal 2842 vsi (19600 kPa) 1972 nsi (13600 kPal MUD TANKS Tank #1: # of Compartments 3 + Trio Tank .Height 8' (2.43m) .Usable Capacity 580 brrls (92m') Tank #2: # of Compartrnents 4 .Height 8' f2.43m1 -Usable Capacity 460 brrls (74m') Tank #3: # of Compartments N/A Height Usable Capacity Trip Tank: Width 4' 1.22m Length 5' 1.52m Height 8' 2.43m Usable Capacity 28 brrls (4.Sm') m3 Trip Tank Location Tank Trip Tank Pump: Make: Mission Model: 2x3x11 mm Type: Electric Pill Tank Volmne: 41 brrls (6 Sm3) Agitator Size 7.5 Hp (5.6 kVJ) Premix Tank Volume: Agitator Size Total No. of Agitators: 6 Power Rating ,7.5 Hn (5.6 kW) M1xing Hoppers: No. 2 Type: Venturi C-2 • CENTRIFUGAL PUMPS Pump #1 Make: Mission Mae Model: 5X6 Site: 127 x 152 Impeller Size (mm): 14" (356mm) n P I1 ower (k~ I p : 45 Used For: Pump #1: Mi~dna. Gun Line pump #2: 1vL+x;no Gun Line Pump #3: Prechatr;e #1 Pumo Pump #4: Prechame #2 Pumn pump #5: Precharee #3 Pumv SOLIDS CONTROL Shale Shaker #1 Pump#2 Pump#3 Pump#4 Pump #5 NfissionMae Mission Mae Mission Mae Mission Mae 5X6 5x6 5x6 5x6 127 x 152 127 x 152 127 x 152 127 x 152 14" (356mm) 14" (356mm) 14" (356mm) 14° (356mm1 118 45 Pumo Driver Pumo Driver Pumo Driver Shale Shaker #Z Shale Shaker #2 Make: 4 Panel Hi G or eouivalent 4 Pane1Hi G or equivalent 4 Panel Hi G or eauivalent Model: Liner Motion LinearMohon LrnearMotron Contractor Will Supply _, Mesh Screens. As Per Contract Desander Desiker Make: N/A N/A Model: Make of Cones: No. of Cones: Size of Cones (mm): Capacity: Operating Pressure (meters of head): Centrifuge: Power Available for kW, Voles Breaker Rating 2 x 100 Amps, Plug Type Other. ~yowet requirements beyond liahtvlarrt caoacity to be suoolied by operator. CUTTINGS PROCESSING UNIT Single trackable module with Mission 5x6 or equivalent shear pump, l scalper shaker, and approximately 250 bbls fluid storage capacity. BLOWOUT PREVENTION EQUIPMENT Annular Ram #1 Ram #2 Ram #3 Make: Hydnl Hydril Hydril Hydril Model: Type: Size: I1" 11" 11" I1" Working Pressure: SM SM SM SM Connection Type: NACE: ManuaUHydraulic Lock: Ram Size (mm) NA 4" Blind 4" Element Type: Date of Last Shop Inspection: Inspected By: Oilco Oilco Shock Hose: (Between BOP Stack and Choke Manifold) Makke: Flanged ,Pressure Rating 5000 psi (34500 kPa) Date,of Last Shop Inspection: Inspected By: C-3 '~ ~ ~~ • • Accumulator: Make: Oilco Model: 180 Gallon Pressure Rating: 3000 nsi (21000 kPal No. of Bottles 12 at 15 eal. (53.0 Ll Each Precharge Pressure 1000 nsi (7000 kPal Accumulator Pressure Operated by Contractor 3000 nsi (21000 kPal Manifold Pressure I50 psi (1050 kPal No. of Stations 6 Master BOP Controls Accumulator Location Remote BOP Cortrols Doehouse Location, Type PLC Electric No. of Press. Regulators 2 .Make: PacSeal Model: 11]0-3100 .Location: Accumulator No. of N2 Bottles 4 .Size: 13 eal. (SOLI. Mm. Press. 14000 kPa Pump #1: Make: Bear .Model: 3001-5100 . Type: Pressuue Rating 3000 nsi (21000 kPal. Pump Rate 11.4 enm (43.21nm1 pump #2: Make: Bear .Model: 3010-0100 Type: Air (2) Pressure Rating 3000 nsi (21000 kPal. Pump Rate 4 earn (15.1 lnml (21 HCR Valves: Make: FMC .Model: Gate .NACE Trim es No. 1 .Size: 3 I/8" (76mm1. Pressure Rating 5000 nsi (34500 kPal Choke Manifold Valves: Make: McEvov .Model: Gate . NACE Trim Yes No. Valves 8 .Size: 3 1/8" (76mm1. Pressure Rating 5000 nsi (34500 kPal Make: McEvoy .Model: Gate NACE True Yes No. Valves 1 .Size: 21/16" (SZmml Pressise Rating 5000 Qsi (34500 kPal Choke #1 Make: Willis .Model: M2 .NACE Trim Yes Size: 3 1(8" (76mm1. Pressure Rating SOOOpsi (34500 kPal Choke #2 Make: Willis .Model: M2 .NACE Trim Yes Size: 3 I/8" (76mm1. Pressure Rating 5000 nsi (34500 kPa) Choke #3 Make: .Model: .NACE Trim Size: _ mm, Pressure Rating _ kPa Upper Kelly Cock: Make: Hi-Kalibre .Model: Kell~ock .NACE Trim Size: 6 5/S Ree L.H.. Pressure Rating 5000 nsi (34500 kPa) Lower Kelly Cock: Make: Ai-Kalibre .Model: Kellvcock .NACE Trim Size: TBD Pressure Rating 5000 nsi (34500 kPal Stabbing Valve: Make: Hi-Kalibre .Model: Kellvcock . NACE Trun No. 1 Size: TBD Pressure Rating 5000 nsi (34500 kPa) Inside BOP: Make: Hi-Kalibre .Model: 4 'h XH NACE Trim No. 1 .Size: TBD .Pressure Rating 5000 nsi (34500 kPal Kill Lines: No. 1 .Size: 3 1/8" (76mm1. Pressure Rating 5000 nsi (34500 kPa) NACE Trun Yes Check Valve: Make: Hi-Kalibre .Model: 3' - 3000 No. .Size: 31/8" (76mm1. Pressure Rating 5000 nsi (34500 kPa) Mud Gas Separator #1: Type: Closed bottom, U tube Mud Gas Separator #2: Type: N/A Location Vessel OD: mm Inlet Size: mm Outlet Size: mm, Line Size to Flare Pit _ mm OverallHeiglrt meters Distance Above Bottom of Tank cm Design Level Drilling Degasser: Make: _ Type: Capacity: fpm DRILL PIPE NOTE: Drill pipe is graded premium at time of last inspection: None HEVIWATE None DRILL COLLARS AND SUBS None LIGHT PLANTS Plant #1 Output 635 Hn (400 kWl. Volts 600 Make Detroit Diesel Model 60Series Plant #2 Output 635Hn(400kW1.Volts 600 Make Detroit Diesel Model 60Series Power and Outlets to Run 5 Additional Wellsite Units Power Available to Run Rental Equipment 0 kW (_ Amps, _ Volts, _ Phase) GENERAL TM71'no Instrumentation Totco BBL With 7° Clock & 14° Clock Clinner Deadline Weieht Indicator ~' Basic Pason Svstem (Rentall Martin Decker Tone Tomue - RotaN Torque Guagg C-4 • PV`T and Flow show Pason (Rental) Automatic Driller Gauee Plus High Pressure Wash Guns Hawk 700 Electric Sump Circulating Pump Flvet 4" Kelly Spirmer Pipe Spinner Snimrer Hawk Kelly Hose: Make: Reliance Size: 4" x 55' Working Pressure 4000 psi (27950 kPa) " Make Up Tongs: Make: Woolley (120mm-300mm) Size: AAX Jaws Available 4'/z" -12 Break Out Tongs: Make: Woolley Size: AAX Jaws Available 4'/z" -12" (120mm-300mm) Drill Pipe Elevators; Make: MGG Size: 4 x 18° Drill Collar Elevators: Make: M & W Size: 6 Y, x 90° Matting: No. 36 Size: 8'x 40' (2 42 x 12.19) Fuel Storage 9500 gal (36000 L) Water Storage 860 barrels (140 m' ) Water Pumps: No. 2 Size 2=kW Output 200ernn BOILER Power Rating 100 Hn (75kW) Operating Pressure Rating 125 psi (860 kPa) Boiler Certificate (Posted in Boiler House) Certificate Number: Date of Inspection: Power Rating 100 Hn (75kW) Operating Pressure Ratirrg 125 psi (860 kPal Boiler Certificate (Posted in Boiler House) Certificate Number: Date of Inspection LOADS Rig 35 TOTAL Winter loads (estimated including drillpipe and spazes) OTHER MAJOR PIECES OF EQUIPMENT Powered Catwalk/Pine Skate (` ~ 2 Smm btu Diesel heater for casin¢ sheds/oine ban \_ _ _ _ 966 or egrrivalent Loader with nine erannle 5000 nsi test~umn 50 Hn Tandem Gear Pumn Hydraulic Power Unit Hoistine Wmches• Number 2 Tvoe & Caoacity Pullmaster PL8 - 7000 Ke 2" 30' (Annrox) Cement Standnine line on derrick with hose C-5 ~ ~ •; - _ / ~~.s 8gs~$.. ,~~ .. ~ ~ L O ~ 0 9 C L O U~ C J O 0 : w - opFB3~.a o~< n Y 5 0 0 y o ° a :, . ~ E m ~. c `o ; r w ~ e r Q m °r ~ _ Q ~ _, L.. p,JF X 3 ~,,,, Y U Q J LL Z Q O J J >Q Q Q W_ L__ ~, -~. .,~ ----~~ /------~----------------`--~-=~------------r--------- m m _W f !o eo F f O 7 O~ o s 3 Q O a' ~o d i z ~~ a ~ Z ~ f i ~ r, .~°~~ y ~~ f ~ TO FLAF TO FLARE PITS racK ITEM LIST: 1. MANUAL CHOICE 2. REMOTE CHOKE 3 TO 18.3}"8,000 pel VALVES 18.2i}" 8,000 VALVE anwka ow ~~ zaoz em saam, nre~u aee~m T9E 772 Tal: (780)986-0700 The IMormatlon wMalned In thla drawing is tha aole property o} AKITA Drilling Ltd. Any reproduction In whole or par! wkhout fha expreae written consen! o} AKITA Drilling Ltd. b prohibited. r 04108/05 r r/wv• ~^~ DRN MANIFOLD 3-D w ARCTIC FOX MANIFOLD 3-D SCHEMATIC REV 1,0 ~ VALVE LEGEND 2 3 4 5 6 7 1 BYPASS 2 KILL 3 CHOKE 4 BOTTOM RAMS NNUUR BOP, oM 5 BLIND RAMS 6 TOP PIPE RAMS eom ACCUMULATOR: OILCO, 6 STATION 7 ANNULAR °M TRIPLEX PUMPS: 2/575 VAC, 25 HP 11.4 GPM, 3,000 PSI AIR PUMP: 2/40:1, 8 GPM, 3,000 PSI )PERATORS, FLUID RESERVOIR: 450 GALLON JPERATORS, ML OPEARTORS, fOM ACCUMULATOR MANIFOLD 12 BOTTLES, 15 GALLONS EACH, TOP LOAD 3,000 PSI W.P. 180 GALLON (BLADDER TYPE) O O O O O O O O O U O O O O E 0 O O ~ O O O O E REMOTE PANEL IN DOGHOUSE (TYPICAL) -si va', zooo Psl, MSP HYDRIL BOP/ONERTER SNDDED TOP/FtANOED BOTTOM NITROGEN BACKUP BOTTLES 6 BOTTLES, 337 CU. FT. SPOOL "'~ BOP $Y8TEM AND CONTROL • • 11" 5000 psi BOPS Stack Doyon Akita Arctic Fox Rig #1 4" pipe ram: Blind rams 4" pipe rams ~-y, ~ • • 21-1/4" Diverter Schematic Doyon Akita Arctic Fox Rig #1 12" knife valve (not shown) ~ r ` i 7 j ,z;. _, ,- --}--"~. Y$ ~ -s> ~_ ~ ~„ ~~~ ~ ~, , ~~ .~ ~ ~ r ,i ---°i ~ -- NOTE: 12" Diverter Line runs underneath substructure away from pipe shed (into the page on this diagram) ~ i .11. ~ t' t ~ SHARON K. ALLSUP-DRAKE ~ 11:31 CONOCOPHILLIPS ATO 1:530 DATE ~~~~~~~ V '~`" '" 56-1551/441 700 G ST. ANCHORAGE AK '99501 - [/ /~ J~ ~j, /~/~, ~- PAY TO THE ~~ ~~~ U~ ~L~~,(~i'I 1~ ~ ~ lc/l/. VV 'r ORDER OF _ ' ( / , ~ p, s.o~ov w~ of cal C~'~~ `~c'~j <rtii~~.L; Ud ~D~L~ARS LJ ~~ ,~a~k ~~ JPMorganChase ~ j vaiia up ro sooo sonars e;, JPMorgan Chase Bank, N.A. t J Columbus, OH ~ MEMO - --- - ---- ---- - .. i:044LL55LL~:5.28.?4?L90792Iii'LL3L • ~J TRANSMITTAL LETTER CHECKLIST WELL NAME -~'~ / PTD# [=-~li~ °- ~~ Development Service IJ Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. APINo. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals 111/// through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C: \j ody\transmittal_checkl ist uVtLL PERMIT CHEC LIST Field & Pool KUPARUK RIVER, KUPARUK RV OIL-490100 Well Name: ANTIGUA 1 Program EXP Well bore seg ^ PTD#: 2060190 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType EXP ! PEND GeoArea 890 Unit On/Off Share On Annular Disposal ^ Administration 1 Permitfeeattached_______ ____________________________ _________Yes____ ____ -------------------------------------------------------------- 2 Lease number appropriate- _ _ , , _ , - _ _ . _ _ No_ - _ _ - _ _ . Correct lease is_ADL_3.90484, issued 511!2004. WIOs are CPAI_and Unocal. - - 3 Uniquewell.nameandnumber -- --- - ----- ----- -- -- - -. Yes------- -- -- --------... - --- ------ --- -- ------ - ----------------- 4 Well located in_a_definedpool _ - - _ - . _ - _ - , _ . _ Yes - _ _ - _ - - Lease lies outside of_KRU, but inside of the CO 4320 affected area (Kuparuk Oil Poo_I), _ , - - - _ _ . 5 Well located proper distance_from drilling unit_boundary_ - .. - - - . - . - - Yes - - _ - . - - Located 3510'_from_ lease ADL 38968$ to_south,_where-ownership changes. _ 6 Well located proper distance from other wells- _ _ _ . - _ _ - , _ Yes . _ _ _ _ Nearest wells are Winter Trails_t& WS 26, both are about 1.9 miles_away-- - - - - - - - - - - - - - - - - - - - - 7 Sufficient acreageayailablein_d_rillingunit______________________ __ ______Yes_______ _______________-._-.__-,_____.-_______----_________---.___________ 8 If deviated,is_wellboreplat_included__________________________ _________ NA____-- Vertical well--__,________-___--______.---_______--_-___ ----------------- 9 Operator only affected party - - Yes - - - 10 Ope[atorhasappropriate_bondinforce________________________ _________Yes-._-_._ ._....-.._-------------_.--_----.... ------------------------------- 11 Permiteanbeissuedwithoutconservationorder___________________ _________Yes_______ ________-___-__.-_____.__-__.______--______---__._______-._. __- Appr Date 12 Permit_canbeissuedwithoutadministr-ativ_e_approval________________ _________Yes_-___-- -,__---_--__.____________--_____-.._________--.,______---,-___--- SFD 216!2006 13 Can permit be approved before 15-day wait Yes 14 Well located within area 2nd-strataauthQrizedby_InjectionOrder#(put10#in-comments)_(For_ NA_______ _____________________________---_..--__-_-__---.--_--__._..-._--_. 15 All wells within 114_mile area_of review identified (For service well only)- - - - - - - - - - - - - - - NA.. _ . _ . _ .. _ - - _ _ _ _ _ _ _ _ - _ _ - - ------------------------------------------------- 16 Pre-produced injector; duration of preproduction less than 3 months_(For service well only) N_A- - - - - - - - - - - - - - - - - - - - - - ACMP-Findingof Consistency_hasbeenissued-for_thispr_ojecl----------- ----------N_A________ ____________-----._____________________,-______ _---______._-___ Engineering 18 Conductorstring_provided - - - - - Yes - - - - - - 19 Surface casing_protectsallknownUSDWS______________________ _________ NA______ _ Allaquifersexempted,40CFR_147.102(b~(3).-_____-________.-_________----____ -- 20 _C_MT_v_ol_adequate-tgcirculate-onconductor_&surf.csg------- ------- ---------Yes_____-- _.-__._ - ... - - 21 CMT_v_ol_ adequate_to tie-in long string to surf csg_ _ . - _ - - - - . N_o, _ , _ _ _ All hyd[ocarbon zones will_ be_coyered. Annular disposal may. be_proposed, _ ------------------ 22 CMT_willcoyerallknown_productiyehorizons__ -_______________ __-,-----Yes_______ __._________________________________________ 23 Casing designs adequate fo[ G, T B &_permafrost - Yes - - - - - - 24 Adequate tankage-or reserve pit . - - _ _ - - - _ _ - - - _ _ .Yes _ Rig is_equipped with steel-pjts.. No reserve_p_itplanned, All waste to-approved disposal wells._ 25 If_a_re-drill,has_a1.0-403 for abandonment been approved---.________ _________NA______-- _.-__ ___________ - - - - - 26 Adequatewellboresep2ration-proposed________________________ _________Yes-._-.-- Nearest wells are-1,9miles distant.._.___-_.__.-.---_---.--_--_----_-_------.----_ 27 If_diverterrequired, does it meet regulatigns_ _ _ - - . _ Yes - - - - - - - - - - - - --- - - Appr Date 28 Drilling fluid_program sehem2tic & equip list adequate_ - . _ - . _ - _ _ Yes - - - - - - - M2ximum expected formation pressu[e 9,4_EMW._ MW planned up to 19.2 pP9•- - TEM 21712006 29 BOPES,dotheymeetregulation____-.._._______._ - - _. ___-Yes_______ _________ _--_____----_______-___ ___.__---__ __.-- ~ 30 _B_OPE_press rating appropriate; test to_(put prig in comments). - _ - Yes - _ - - _ .. MA$P calculated at 2605 psi, 3500-psi_appropriate. CPAI usually tests to 5000_psi. - - - - - _ ~ ~"~~, 31 Choke-manjfoldc4mplies w/API_RP-53 (May 84)_____ ___________- -_-_--__.Yes___.___ _____ (((999" 32 Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ Yes _ _ _ _ _ _ _ _ _ - - 33 Is presence, of H2S gas probable _ , - _ _ .. - - - - - - - - - - No_ _ H2S has notbeen reported in_ offset wells. -Rig is equipped with sensors and_alarms. - - _ . - _ - . 34 Mechanical condition of wells within AOR verified (Forservice well only - . - - NA_ _ _ - - -- - Geology 35 Permit can be issued wlo hydrogen_sul_fide measures _ _ . _ . _ _ - -Yes - - . - - - . Not expected, but H2$ sensors will be employed._ _ - . . - - - 36 Data_presented on potential overPressur_e zones_ - - _ - - _ - - . - _ - -Yes - - - - - . _ No indications_of shallow hazards observed in seismic orv_elocity_datasets._ Pressure-expcted_to be $.5ppg Appr Date 37 Seismic analysis-of shallow gas_zones_ - . _ _ _ , - - Yes _ _ _ _ _ _ _ - EMW_to 5200', khan graduaDy riseto X9.7 ppg at permitted TD of 7175'._ Will_be drilled with 9.4 to 10.2 ppg_ _ - - - SFD 21612006 38 Seabed cond~ion curve . rf_ off-shore _ - . _ _ _ . NA_ _ _ - mud. _Hydrates ma be resent near base of ermafrost zone at 1400 Mi4 aUon measures discussed in 39 Contact namelphone for weekly_progress reports_ [exploratory only] - - Yes - _ - - _ - - Drilling Hazards_Summa_ry. _Contact; PaUI Mazzolini at 907,263-4603- _ - - _ - - Geologic Engineering Commissioner: Date: Commission r: Date m ssi a Date ~~1-~-a.~ a -~. -© • C, Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history ale. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-sun DRILLING SERVICES ~.(~onocoPhillips Alaska, Inc. A. . END OF WELL REPORT ~ , _ ~ -~ Antigua-1 ~: _ C'~~ ~DGrCL' ~~ 20~- otq TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Bit Record 4. Hole Summary 5. Mud Reports 6. Survey Report 7. Days vs Depth 8. Morning Reports 9. Show Reports 10. Logs /Data CD speri~y-sun ^RILLIRIG 5ERLtICES GENERAL WELL INFORMATION ' Company: Rig: Well: ' Field: Borough: State: i Country: API Number: ' Sperry-Sun Job Number: Job Start Date: Job End Date (TD): ' North Reference: Declination: Dip Angle: ' Total Field Strength: Date Of Magnetic Data: Wellhead Coordinates ' Wellhead Coordinates Location: SDL Engineers: Company Geologist: SSDS Unit Number: ConocoPhillips Petroleum Alaska, Inc. Doyon Akita Arctic Fox #1 Antigua-1 Antigua North Slope Alaska United States 50-029-23299-00 AK-AM-0004299296 29tH March 2006 11 April 2006 True 24.10 deg 80.715 deg 57559 NT January 28, 2005 X= 558,553.8 Y= 5,915,642.0 1771' FNL, 2358' FWL Section 35 Township T10N, Range R10E Mark Lindloff Doug Wilson Eugene Payne Tom Mansfield A. Andreou (office), C. Goddard (wellsite) 107 ' sperl~~-sun ^RILLING 5ERVIGE5 r Antigua 1 -Diary of Events 27th March 2006 Rig up Arctic Fox #1 rig on Antigua-1 location. ' 28th March 2006 Rig up Arctic Fox #1 ri on Anti ua-1 location g g 29th March 2006 Rig up Arctic Fox #1 rig on Antigua-1 location 30th March 2006 Pickup bit # 1 , a 12 1/4" HTC MXL-1 with jets (3x15, lx 13) TFA= ' 0.628 and Spud Antigua-1 well at 100' MD at 2135 hrs. Drill from 100' to 211' MD. The cuttings samples consisted of interbedded pea gravels and sands in predominately clay. Mud was a spud mud of 9.8 ppg with a viscosity of 180. Average ROP was 84 ft/hr. No gas or methane hydrates were noted in this section. 31St March 2006 Drill 12 '/4' hole from 211' to 1395' MD. Drilling parameters were WOB 10-12 klbs, RPM 85 (surface) RPM 90 (mud motor), pump pressure 800-2000 psi with a flow rate of 470 to 490 gpm. Mud weight used was 10.1 ppg. The formation drilled consisted of primarily clay and minor sands down to 370 feet, where pea gravels with some large (5") minor wood fragments were encountered unti1490' MD. The formation from 490' to 1364' MD consisted of predominately clay with minor interbedded sands and traces of gravels. Some apparent traces of methane (above 100 ppm C1) (methanehydrates?) were noted in the depths (240- 350' MD, 415-473' MD, 1020-1082' MD, and 1132-1140' MD).. the first continuous methane readings were ~ .found at the depth of 1258' MD. Average ROP in this interval was 73 ft/hr. 1St Anri12006 Drill 12 I/4" hole from 1395' to 2347' MD. A zone of woody lignite was encountered at 1465 to 1490' MD which yield a maximum gas of 2898 units gas in air (28.98%). A flow check was performed at 1491' MD which was found that the well was static. Bottoms up was circulated at 1523' MD with a maximum gas of 756 units 7.56%) noted. 2"d Apri12006 Short trip to DC's @ 500' , RIH, CBU- maximum gas 4378 UNITS with MW cut 10.1 to 9.6 ppg, 3rd Apri12006 Drill 12 1/4" hole from 2347' to 2505, Short trip to 1500' MD, RIH, CBU- maximum gas on BU - 395 units, Drill 12 1/4" hole from 2505 to 3302' MD. Oil sheen and free oil in samples from 2730' MD. I,I ~ 4th Apri12006 Drill 12 1/4" hole from 3302' to 3493, Short trip 16 stds to 2500', RIH, CBU- maximum gas on. BU - 558 units, Drill 12 1/4" hole from 3493 to 4053' MD, CBU, pump 50 bbl hi vis sweep- no significant cuttings to surface, pump slug, TOOH to '~,' HWDP (26 stds) (hole took 9.6 bbls more than calc.). TIH. Oil sheen and free oil in samples from 3459' to 4053' MD. . th A - ~ 5 pri12006 TIH for wiper trip, wash down f/ 4015 4053 ,CBU- 3 peaks seen- 1 st- ' 275 units (2300 stks~21001ag depth- lignite), 2nd- 325 units (.6000 stks~3500' lag depth- sand, 3rd- 290 units bottoms up, pump hi vis sweep to circ hole clean, run water to reduce MW after trip, TOOH-( hole fill took 4.6 bbls more than calc), rig up to run 9 5/8" casing, run 9 5/8" casing to jt 50 tight CBU and work through (BU yielded large amt 3" pieces of lignite/wood fragments and clay ). ' 6th Anri12006 Run 9 5/8" casing to 4044', total lost mud by sperry= 11 bbls, CBU- max BU gas = 104 units (average circ gas = 46 units ), circulate 11900 strokes, rig up to cement, dump pits, cement 9 5/8" casing per plan, rig down cement equip, nipple up BOP's. 7th Anri12006 Nipple up BOP's, test BOP's, fill pits with new mud. ' 8th Anri12006 Finish testing BOP's, P/U BHA #2 and RIH, drlg cement. \ 9th Apri12006 Drill cement rathole and 20' 8 1/2" hole new formation to 4073' MD, displace mud with 9.4 ppg new mud, perform Formation Integrity Test to 15.9 ppg EMW, Continue drilling 8 1/2" hole from 4073' to 4822 PWD at 4822' 10.7 ppg clean ' hole ECD ~ 10.3 with 9.5 ppg MW at 485 GPM * * Note: some polymer plugging of gas trap at shaker header box. *** saw flow increase from 30% to 50% at 4608'- check flow- static- due to clay on flow sensor? ' 10th Aari12006 Drill 8 1/2" hole from 4822-5014' MD, perform 15 std short trip to 9 5/8" casing shoe (4021' MD), CBU maximum short trip gas 270 units, no fill on bottom, ' resume drlg from 5014 to 5622' MD PWD at 5600' 11.1 ppg clean hole ECD ~ 10.65 with 10.0 ppg MW at 490 GPM ** Note: large amount of clay returns on bottoms up after short trip -dumped and diluted mud. * * * Incr MW to 10.0 ppg and reduced water loss for HRZ. EST Pore Pressure = 9.1 ppg. 11th Apri12006 Dri118 1/2" hole from 5622'-6291' MD, perform 15 std short trip, CBU with maximum short trip gas of 375 units. Resume drlg from 6291' to 6322'. PWD at 6322', 11.0 ppg ECD with 10.3 ppg MW at 486 GPM. 12th Anri12006 Drill 8 1/2" hole from 6322' to 6535' MD. Perform Formation Integrity Test to 13.0 ppg. Drill ahead from 6535' to 6850' MD and TD well. Circulate and sweep hole. Short trip 15 stands, CBU with short trip gas of 881 units. Sweep hole, pump slug ' and POOH. Sperry- ~~~ WELL NAME: Antigua 1 LOCATION: North Slope OPERATOR: ConocoPhillips Petroleum Alaska AREA: Antigua Area G R I L L I N G S E R V I C E S CONTRACTOR: Doyon/Akita Arctic Fox #1 STATE Alaska BIT RECORD BIT # Bit Type Bit Size Depth IN Depth OUT Footage Bit Hours TFA AVG ROP WOB RPM PUMP Press PUMP GPM TORQUE ftlKlbs MW ppg Krevs Bit Grade Remarks 1 HTC MxL-1 12.25" 100:0 4053.0 3953.0 51.6 0.6280 112.0 16 86 1854 450 10 10 2 HC/DS619S-A-9 8.5" 4053.0 6850.0 2795.0 51.9 1.1800 78.0 s 91 2459 427 14 10 1-1-CT-A-X-I-NO-TD No Problems 3 4 spry-sun ior~~~~,.~ruc~ ~~r~v~c~s HOLE SUMMARY WELL NAME: OPERATOR: CONTRACTOR: Section MD TVDSS CASING MD Depth TVDSS LOT 16" Conductor 100' 31' N/A 121/4" 4053' 3922' 9 5l8" 4044' 3913' 15.9 FIT 8 1l2" 6850' 6719' N?A Well was plugged and abandonded Note: A deep FIT was conducted above the Kuparuk Reservoir in the Kalubik fprmation. An FIT of 13.2 was attained. Antigua 1 LOCATION: North Slope ConocoPhillips Petroleum Alaska AREA: Antigua Area Doyon/Akita Arctic Fox #t STATE Alaska a O m .~ O Q ~ ~ ~ d d d d C y L ~ ~ 'O L L L L ~ d U d d d Q ~ ~ y ~ ~ ~ ~ ~ N ~ L L L ~ P O ~ R r r NN U a ~[! fV fV (V 7 R c C C C ~ ~ ~ Of C) C ao a0 R N ~ d = .` .=_ = o = a d d ~ ~ o ?~ d N ~ ~J = R v ~ v v v ~ ~ v N N O COD a°o ao a00 p U ~- oe i U ~ O~ 0 0 0 0 0 0 0 0 0 0 0 0 t ~ o 0 0 0 o o o o o u~ o o 0 u~ 0 o 0 o V a co rn r m ~n ~ u~ ~n rn co rn aD ao oo ao n "' o M o 0 o ~ n o co 0 co 0 v ,~ O 0 co ~ ao 0 r N 0 r Q M er O O O O q ~ M O O ~ ~ r a ~ O O O O O O O O N 0 ~ N g O O 0 0 0 0 0 0 0 0 0 ~ O O O O C O O O 0 0 0 0 N N N N rn r ee r r "' •' N O in ~ 4n Y 10 S o O N o O O aD V' V' ~ r r tn O ~ O N Q ~ . rn a oo 0 rn rn rn rn 0 ao aD 0 ao 0 m ~ N ~ ~ O O N O s aE N o N 0 ~ 0 ~ 0 N O g 0 0 O o N 0 3 N ~ ~ ~t4r Q~ Q 'C7 ° N O ~ O O M r C O O ~n O O O O O O q N ICJ N M1 N O N ~ N C O Y Q Z QN~ V1 C `^ r O r g 0 0 g 0 0 0 0 0 d No p p ~ CA P O g W a00 ~ 4~ O O M ~ N ~ ++ R ° ° N 3 CD 00 M T O W ~ O ~ d fq ~p Z'CD d ~ o C W ~ o° aD ~ r ca ao oi ao oi M o O o M ~ M r 0 ~ri 0 ui 0 ui 0 ~ 0 ao 0 ao 4) ao .G ~ a ~w~ ~ Y R c N N M M N N N N r r N N N N (~ ~ ~ a ~ C °i~ ~ ~ a ~ ~ C C °~ C ~ ~ C C ~ ~ C L° C P K c ~ ~ g+ t6 ~ m m _ A ~ ~ ~ ~ ~ N £~ g ~ ~ ~ ° ~ ~ ^ ~ ~ ~^ ~ a O ro V ~ N N O ~ N m N v V ~ ~C O ~ b a ~ s W A ro a3 ~ m ~ ~ ~ g g e ~ a i N I R C1 rc m m m m M M ~ ~ m m m Q ~ ~ V ~ O LL M g O O W M CO N CP N P r O CO V (,p ~ N OD N CO <Y U' CO » ~ st N v at ~ G Q L ~ Y a Q V 7 ~ M N N O C'O ~ p C~ d' <O ~ M W r r a` p O O ~ _r C ~ TO (~y 47 aD ~ N Y N r N i O ~ cp r n r W O C O R N M er M r ~ r U Q o m C d ~ O aD r OD O N CO ID CO N ~ N ~ M O d }~ O O M M M M N N r r N N N N N a V ~ d C7p (,) j ~~ ~ y ~ M M N 'tt N ~ N Q1 N N M M M O r cT r O) r N N N N } N O W U7 40 M CD r O ~ r 1f) fO ~ CO ~ In N ~ CO M ~ O ~ to M p N u~ r v fn ~ 0 3 Q 0 O 0 ao 0 r 0 g 0 O 0 O 0 r 0 r 0 ~ 0 .* 0 v 0 0 0 r) 0 N 0 M V Q O ~ O O O Cj 0 0 0 C7) O O p 0 0 ~ • ~ ~ ~ L Q Q~ ~ Q~ O O O ~ P O O O O O M M M ~ M O M ~ M O O O O O O ~ ~ ~ /~ d ~- N M N O 0 0 0 0 CO ~ N CO CO N Y/ R ~ L N N l6 ~ i ~ ~ ~ i ~ ~ ~ ~ ~ ~ w R ~ ~ ~ Q Q Q Q Q Q Q Q Q Q Q Q ~ M r N M ~ ~ A f 0 f ~ CO p O r N Q ,~ N M Halliburton Company Survey Report D~,-i~voTavE ~~ ('on,papy: ConocoPhillips Alaska Inc. Dater 5/10/2006 Time: 09:25:53 Pager Field: Exploration2006 Co-ordinate(NE) Reference: Wel l: Antigua #1, Tr ue North Site: Antigua Vertical (TVD) Refer ence:. Antigua#1: 130.8. ~~ Nell: Antigua #1 ~ ' Section (VS) Reference: Wel l (QOON,O.OOE,O-OOAzi) i Wellpath: Antigua #1 Survec calculation Method: Min imum Curvature Db: Oracle Field: Exploration 2006 Map System:US State Plane Coordinate System 19 27 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Well Centre Sys Datum: Mean Sea Level Geomagnetic Mo del: bggm2005 Well: Antigua #1 Slot Name: Well Position: +N/-S 0.00 ft Northing: 5915642.12 ft Latitude: 70 10 48.476 N +E/-W 0.00 ft Easting : 558553.73 ft Longitude: 149 31 42.704 W Position Uncertainty: 0.00 ft _ . Wellpath: Antigua #1 Drilled From: Well Ref. Point ' ' 500292329900 Tie-on Depth: 20.00 ft Current Datum: Antigua# 1: Height 130.80 ft Above System Datum: Mean Sea Level Magnetic Data: 3/27/2006 Declination: 24.10 deg ' Field Strength: 57559 nT Mag Dip Angle: 80.71 deg Vertical Section: Depth Fro m (TVD) +N/-S +E/-W Direct ion ft ft ft deg 20.00 0.00 0.00 0.00 Survey Program f'or Definitive Wellpath Date: 3/21/2006 Va lidated: No Version: 1 Actual From To Survey Toolcode Tool Name i ft ft 100.00 6731.71 Antigua #1 (100.00-6731 .71) MWD MWD -Standard Survey - - - -- - - - ~-- N-D Licl A -- zim TVD S}~s TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft __ ft _ __ 00 0.00 20 _- 0.00 _ 20.00 -110.80 0.00 0.00 5915642.12 558553.73 TIE LINE . 00 0.00 100 0.00 100.00 -30.80 0.00 0.00 5915642.12 558553.73 MWD ' . 00 0.19 141 61.51 141.00 10.20 0.03 0.06 5915642.15 558553.79 MWD . 00 0.26 239 77.31 239.00 108.20 0.16 0.42 5915642.28 558554.15 MWD . 331.00 0.19 89.86 331.00 200.20 0.21 0.78 5915642.33 558554.50 MWD 60 0.14 422 59.82 422.60 291.80 0.26 1.02 5915642.39 558554.75 MWD . 40 0.25 518 101.44 518.40 387.60 0.28 1.33 5915642.41 558555.06 MWD . 82 0.22 608 48.77 608.82 478.02 0.35 1.65 5915642.49 558555.38 MWD . 32 0.17 701 60.69 701.32 570.52 0.54 1.91 5915642.67 558555.63 MWD ' . 794.69 0.12 30.16 794.69 663.89 0.69 2.08 5915642.83 558555.80 MWD 18 0.22 887 75.38 887.18 756.38 0.82 2.30 5915642.96 558556.02 MWD . 60 0.20 978 121.40 978.60 847.80 0.78 2.60 5915642.92 558556.33 MWD . 53 0.28 1073 128.77 1073.52 942.72 0.55 2.93 5915642.69 558556.65 MWD . 22 72 0 1165 136.99 1165.71 1034.91 0.28 3.22 5915642.42 558556.95 MWD . . 1261.41 0.38 145.92 1261.40 1130.60 -0.12 3.53 5915642.03 558557.26 MWD 10 0.37 1359 165.65 1359.09 1228.29 -0.69 3.79 5915641.46 558557.52 MWD . 45 0.44 1453 158.47 1453.44 1322.64 -1.32 3.99 5915640.83 558557.73 MWD . 04 0.67 1547 155.33 1547.02 1416.22 -2.16 4.35 5915640.00 558558.10 MWD . 64 50 0 1643 155.65 1643.48 1512.68 -3.16 4.81 5915639.00 558558.57 MWD . . 1739.30 0.63 190.14 1739.27 1608.47 -4.17 4.94 .5915637.99 558558.70 MWD 00 0.70 1836 172.18 1835.96 1705.16 -5.27 4.93 5915636.88 558558.70 MWD . 82 19 0 1931 173.45 1931.15 1800.35 -6.53 5.08 5915635.63 558558.86 MWD . . 72 17 0 2025 181.79 2025.12 1894.32 -7.78 5.14 5915634.38 558558.93 MWD . . 69 67 0 2119 181.69 2119.61 1988.81 -8.95 5.11 5915633.21 558558.90 MWD . . 2215.51 0.80 183.32 2215.44 2084.64 -10.19 5.05 5915631.97 558558.86 MWD 10 41 1 2309 184.66 2309.33 2178.53 -11.74 4.94 5915630.42 558558.76 MWD . . 17 96 1 2403 185.96 2403.86 2273.06 -13.61 4.77 5915628.55 558558.60 MWD . . 31 24gg g7 1 184.38 2498.85 2368.05 -15.66 4.58 5915626.50 558558.43 MWD . . 13 58 1 2595 189.18 2595.44 2464.64 -17.70 4.35 5915624.46 558558.21 MWD . . 2691.53 1.21 194.73 2691.37 2560.57 -19.61 3.94 5915622.54 558557.82 MWD Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 5/10/2006 Time: 09:25:53 Pa~ca ~ 2 P'~cld: Ex ploration 2006 Co-ord inate(NE) Re ference: W ell: Antigua #1, True North Site: .An tigua. Vertical (TV"D) Refe rence: An tigua#1: 130.8 ~ Well: An tigua #1 Seetio^ (VS) Referen ce: W ell (O.OON,O. OOE ,000AzI) ~Vcllpatl~: An tigua #1 Survey Calculafion tilethod: Mi nimum Curvatur e _ Db: Oracle Survey ~ 1bID Incl ?~zim 1'VD Sys TVD \'/S __ E/VV _ _ b1apN -- - 31apE --- 'fool ft eg deg ft ff ft ft ft ft 2787.08 1.15 196. 11 2786. 90 2656, 10 -21.51 3.41 5915620 .64 558557 .31 MWD 2884.01 1.06 196. 06 2883. 81 2753. 01 -23.31 2.90 5915618 .84 558556 .81 MWD 2980.05 0.79 190. 05 2979. 84 2849. 04 -24.81 2.53 5915617 .33 558556 .46 MWD 3076.15 0.70 185. 02 3075. 93 2945. 13 -26.05 2.37 5915616 .09 558556 .30 MWD 3169.03 0.69 155. 23 3168. 80 3038. 00 -27.12 2.55 5915615 .02 558556 .49 MWD 3263.90 0.67 139. 80 3263. 66 3132. 86 -28.06 3.15 5915614. 08 558557 .10 MWD 3361.23 0.39 143. 78 3360. 99 3230. 19 -28.77 3.71 5915613. 39 558557 .66 MWD 3455.18 0.20 174. 37 3454. 94 3324. 14 -29.19 3.92 5915612. 97 558557 .87 MWD 3551.69 0.31 203. 32 3551. 45 3420. 65 -29.59 3.83 5915612. 56 558557 .79 MWD 3647.23 0.45 209. 07 3646. 99 3516. 19 -30.16 3.55 5915611. 99 558557 .51 MWD 3742.37 0.41 206. 74 3742. 12 3611. 32 -30.79 3.21 5915611. 36 558557 .18 MWD 3836.46 0.33 202. 40 3836. 21 3705. 41 -31.34 2.96 5915610. 81 558556. 93 MWD 3930.24 0.37 177. 40 3929. 99 3799. 19 -31.89 2.87 5915610. 25 558556 .84 MWD 3981.35 0.39 174. 34 3981. 10 3850. 30 -32.23 2.89 5915609. 92 558556 .87 MWD ~ 4092.56 0.38 176. 62 4092. 31 3961. 51 -32.98 2.95 5915609. 17 558556 .94 MWD 4154.76 0.40 172. 40 4154. 51 4023. 71 -33.40 2.99 5915608. 75 558556. 98 MWD 4241.13 0.38 167. 79 4240. 87 4110. 07 -33.98 3.09 5915608. 17 558557. 09 MWD 4342.21 0.39 166. 94 4341. 95 4211. 15 -34.64 3.24 5915607. 51 558557. 24 MWD 4438.77 0.37 172. 35 4438. 51 4307. 71 -35.27 3.36 5915606. 88 558557. 36 MWD 4536.88 0.31 189. 41 4536. 62 4405. 82 -35.84 3.36 5915606. 31 558557. 36 MWD 4628.19 0.22 184. 42 4627. 93 4497. 13 -36.26 3.30 5915605. 89 558557. 31 MWD 4727.71 0.25 :200. 84 4727. 45 4596. 65 -36.65 3.21 5915605. 49 558557. 22 MWD 4822.66 0.36 226. 79 4822. 39 4691. 59 -37.05 2.92 5915605. 09 558556. 94 MWD 4918.02 0.53 220. 07 4917. 75 4786. 95 -37.60 2.42 5915604. 55 558556. 44 MWD 5009.82 0.57 227. 26 5009. 55 4878. 75 -38.23 1.81 5915603. 91 558555. 83 MWD 5106.32 0.57 230. 27 5106. 04 4975. 24 -38.86 1.09 5915603. 27 558555. 12 MWD 5202.74 0.62 237. 66 5202. 46 5071. 66 -39.45 0.28 5915602. 68 558554. 31 MWD 5299.34 0.70 244. 61 5299. 05 5168. 25 -39.98 -0.70 5915602. 14 558553. 34 MWD 5394.99 0.68 249. 01 5394. 69 5263. 89 -40.43 -1.76 5915601. 68 558552. 29 MWD 5490.19 0.57 254. 97 5489. 89 5359. 09 -40.76 -2.74 5915601. 34 558551. 31 MWD 5591.19 0.47 248. 08 5590. 88 5460. 08 -41.04 -3.61 5915601. 05 558550. 44 MWD 5682.91 0.53 246. 20 5682. 60 5551. 80 -41.36 -4.35 5915600. 73 558549. 70 MWD 5780.55 0.53 249. 75 5780. 24 5649. 44 -41.70 -5.18 5915600. 39 558548. 87 MWD 5875.49 0.58 256. 73 5875. 17 5744. 37 -41.96 -6.06 5915600. 12 558547. 99 MWD 5968.14 0.55 263. 11 5967. 82 5837. 02 -42.12 -6.96 5915599. 95 558547. 10 MWD 6063.60 0.69 265. 23 6063. 27 5932. 47 -42.22 -7.99 5915599. 84 558546. 07 MWD 6159.44 0.61 263. 36 6159. 11 6028. 31 -42.33 -9.07 5915599. 73 558544. 99 MWD 6259.79 0.62 265. 26 6259. 45 6128. 65 -42.43 -10.14 5915599. 61 558543. 92 MWD 6354.16 0.53 273. 91 6353. 81 6223. 01 -42.45 -11.09 5915599. 59 558542. 97 MWD 6451.20 0.50 283. 04 6450. 85 6320. 05 -42.32 -11.95 5915599. 71 558542. 11 MWD 6543.32 0.50 287. 71 6542. 97 6412. 17 -42.11 -12.72 5915599. 92 558541. 34 MWD 6637.41 0.45 285. 73 6637. 05 6506. 25 -41.88 -13.47 5915600. 14 558540. 59 MWD 6731.71 0.51 286. 18 6731. 35 6600. 55 -41.67 -14.23 5915600. 35 558539. 83 MWD 6850.00 0.51 286. 18 6849. 64 6718. 84 -41.37 -15.24 5915600. 63 558538. 81 PROJECTED to TD ANTIGUAZ_SURVEYS_FULL.tXt Survey Survey Survey N/S E/W Vertical DogLe~ Depth Inclination Azimuth TVD D eparture Departure Sec Severity (ft) (deg) (deg) (ft) (ft) (ft) (ft) (dphf) 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 141.00 0.19 61.51 141.00 0.03 0.06 -0.05 0.48 239.00 0.26 77.31 239.00 0.16 0.43 -0.30 0.09 331.00 0.19 89.86 331.00 0.21 0.79 -0.47 0.09 422.60 0.14 59.82 422.60 0.26 1.04 -0.61 0.11 518.40 0.25 101.44 518.40 0.28 1.34 -0.73 0.18 608.82 0.22 48.77 608.82 0.36 1.66 -0.91 0.23 701.32 0.17 60.69 701.32 0.55 1.92 -1.18 0.07 794.69 0.12 30.16 794.69 0.70 2.09 -1.38 0.10 887.18 0.22 75.38 887.18 0.83 2.32 -1.58 0.17 978.60 0.20 121.40 978.60 0.80 2.62 -1.65 0.18 1073.53 0.28 128.77 1073.52 0.57 2.94 -1.55 0.09 1165.72 0.22 136.99 1165.71 0.30 3.23 -1.40 0.07 1261.41 0.38 145.92 1261.40 -0.10 3.54 -1.13 0.17 1359.10 0.37 165.65 1359.09 -0.67 3.79 -0.69 0.13 1453.45 0.44 158.47 1453.44 -1.30 4.00 -0.17 0.09 1547.04 0.67 155.33 1547.02 -2.12 4.36 0.48 0.25 1643.50 0.64 155.65 1643.48 -3.13 4.82 1.27 0.02 1739.30 0.63 190.14 1739.27 -4.14 4.95 2.17 0.40 1836.00 0.70 172.18 1835.96 -5.25 4.93 3.22 0.23 1931.19 0.82 173.45 1931.15 -6.51 5.09 4.35 0.13 2025.17 p.72 181.79 2025.12 -7.77 5.15 5.51 0.16 2119.67 0.69 181.69 2119.61 -8.94 5.11 6.62 0.03 2215.51 0.80 183.32 2215.44 -10.18 5.06 7.81 0.12 2309.41 1.10 184.66 2309.33 -11.74 4.95 9.30 0.32 2403.96 1.17 185.96 2403.86 -13.60 4.77 11.11 0.08 2498.97 1.31 184.38 2498.85 -15.65 4.59 13.1p 0.15 2595.58 1.13 189.18 2595.44 -17.69 4.35 15.10 0.21 2691.53 1.21 194.73 2691.37 -19.61 3.94 17.p4 0.14 2787.08 1.15 196.11 2786.90 -21.51 3.42 19.00 0.07 2884.01 1.06 196.06 2883.81 -23.30 2.90 20.86 0.10 2980.05 0.79 190.05 2979.84 -24.81 2.54 22.40 0.29 3076.15 0.70 185.02 3075.93 -26.05 2.37 23.62 0.11 3169.03 0.69 155.23 3168.80 -27.12 2.56 24.56 0.39 3263.90 0.67 139.80 3263.66 -28.06 3.15 25.24 0.19 3361.23 0.39 143.78 3360.99 -28.76 3.71 25.70 0.29 3455.18 0.20 174.37 3454.94 -29.18 3.92 26.02 0.26 3551.69 0.31 203.32 3551.45 -29.58 3.83 26.43 0.17 3647.23 0.45 209.07 3646.99 -30.14 3.55 27.06 0.15 3742.37 0.41 206.74 3742.12 -30.78 3.21 27.77 0.04 3836.46 0.33 202.40 3836.21 -31.33 2.96 28.38 0.09 3930.24 0.37 177.4Q 3929.99 -31.89 2.87 2$.93 0.17 3981.35 0.39 174.34 3981.10 -32.23 2.89 29.24 0.06 4092.56 0.38 176.62 4092.31 -32.97 2.95 29.92 0.02 4154.76 0.40 172.40 4154.50 -33.39 2.99 30.29 0.06 4241.13 0.38 167.79 4240.87 -33.96 3.09 30.80 0.04 4342.21 0.39 166.94 4341.95 -34.62 3.24 31.36 0.02 4438.77 0.37 172.35 4438.51 -35.25 3.35 31.91 0.04 4536.88 0.31 189.41 4536.62 -35.82 3.35 32.45 0.12 4628.19 0.22 184.42 4627.93 -36.24 3.30 32.87 0.10 4727.71 0.25 200.84 4727.44 -36.64 3.21 33.27 0.08 4822.66 0.36 226.79 4822.39 -37.04 2.91 33.75 0.18 4918.02 0.53 220.07 4917.75 -37.59 2.41 34.44 0.19 5009.82 0.57 227.26 5009.55 -38.22 1.80 35.24 0.09 5106.32 0.57 230.27 5106.04 -38.85 1.08 36.08 0.03 5202.74 0.62 237.66 5202.46 -39.44 0.27 36.91 0.09 5299.34 0.70 244.61 5299.05 -39.97 -0.70 37.75 0.12 Page 1 ' ANTIGUAZ SURVEYS FULL tXt 5394.99 0.68 249.01 _ 5394.69 _ . -40.43 -1.76 38.54 0.06 5490.19 0.57 254.97 5489.89 -40.75 -2.75 39.19 0.14 5591.19 0.47 248.08 5590.88 -41.04 -3.62 39.76 0.12 ' 5682.91 0.53 246.20 5682.60 -41.35 -4.36 40.31 0.07 5780.55 0.53 249.75 5780.24 -41.69 -5.19 40.91 0.03 5875.49 0.58 256.73 5875.17 -41.95 -6.08 41.47 0.09 5968.14 0.55 263.11 5967.82 -42.11 -6.98 41.93 0.08 ' 6063.60 0.69 265.23 6063.27 -42.22 -8.01 42.38 0.15 6159.44 0.61 263.36 6159.10 -42.32 -9.09 42.86 0.09 6259.79 0.62 265.26 6259.45 -42.43 -10.16 43.32 0.02 6354.16 0.53 273.91 6353.81 -42.44 -11.10 43.66 0.13 6451.20 0.50 283.04 6450.85 -42.32 -11.96 43.84 0.09 6543.32 0.50 287.71 6542.97 -42.10 -12.73 43.91 0.04 6637.41 0.45 285.73 6637.05 -41.88 -13.47 43.95 0.05 6731.71 0.51 286.18 6731.35 -41.66 -14.23 44.01 0.06 6850.00 0.51 286.18 6849.64 -41.37 -15.24 44.09 0.00 J 7 1 Page 2 n ConocoPhillips Alaska, Inc Days Antigua 1 0 5 10 15 20 25 30 0 1 udwellat110 ' D 1000 1 - ~ . ~ ~ ~ __ 12 1/4" Hole 2000 FT 3000 ~._ Actual 4000 '~, ~_ - 9 5/8" CSG at 4053 ft MD ~I 5000 - I -Af2" Hole. i `J i ~. Pro nosed ?-T 9 i 6000 - - '- - ' TD 6850 MD ~ 6850 TVD ` Abandon Cal 6850' (68 hrs) ~ 7000 ~ ~ 8000 : 1 Customer: ConocoPhilli ort No s Re ~" . p p Well: Antigua-1 Date: 3/31/2006 Sperry E7r91[~ng services Area: North Slope Depth 401 udlogger's Morning Report Lease: Exploration Footage. Last 24 hrs: 301 ~ Rig: Doyon Akita AF1 Rig Activity:_ Drill 12 1/4" j Job No.: AK-AM-4299296 Report For: Winfree / Springer ', Current 24 hr Avg 24 hr Max R.O.P. 156 ft/hr 83.6 ft/hr ( 261 ft/hr @ 380 ) Gas* 2 units 0-1 unit: ( 3 units @ 380 ) ( ) Pump and Flow Data Pumps 184 spm Flow rate. 525 gpm; Pump Capacity 2.849 gps j Pump Liner & Strk 6X8 in. Pump Pres 1550 psi Mud Wt In 9.80 ppg Visc 180 secs API filt 8.6 ml HTHP ml Mud Wt at Max Gas 9.8 ppg Mud Wt Out 9.80 ppg PV 28 cP YP 58 Ibs/100ft2 Gels 38 \ 45 \ pH 8.2 Sd 0.25 % Bit No.: 1 Type: HTC MXL-1 Bit Size: 12 1/4 Jets: 1 x 12 3 x 15 x TFA: 0.6280 `;^Jt On Bit: 5 RPM: 87/MM90 Hrs. On Bit: 3.6 Total Revs on Bit: 0 Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: - ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft l.U~r~llC!I~~1C J~I,i. '.!! ~?fl(j ~'~) ~ S: ~~_'~ ~ '~I,l i~~ ~ ~~L'._~.~ Connection Gas and Mud Cut. ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units .ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to to ~ ~ to to 24 hr Rec Pickup BN 1, MWD and Bha and spud well at 100' MD, Drilling 12 1/4" hole from 100' to 401' MD. Cutting samples consist of interbedded gravels and sands in predominately clay. Logging Engineer: Doug Wilson /Eugene Payne 10000 units = 100% Gas In Air 1 : 2 Customer: ConocoPhillips Report No '° ~ . Well: Antigua-1 Date: 4/1/2006 Sperry G'3rilling Services Area: North Slope Depth 1523 udlogger's Morning Report Lease: Exploration Footage Last 24 hrs: 1122 ~ Rig: Doyon Akita AF1 Rig Activity:.,, Short trip Job No.: AK-AM-4299296 Report For: Winfree / Springer Current 24 hr Avg 24 hr Max R.O.P. 140 ft/hr 73.3 ft/hr ( 285 ft/hr @ 410 ) Gases 150 units 45 unit; ( 2898 units @ 1473 ) ( ) Pump and Flow Data Pumps 171 spm Flow rate 487 gpm Pump Capacity 2.849 gps Pump Liner & Strk 6X8 in. Pump Pres 2000 psi Mud Wt In 10.10 ppg Visc 85 secs API filt 8.3 ml HTHP ml Mud Wt at Max Gas 10.1 ppg Mud Wt Out 10.10 ppg PV 24 cP YP 37 Ibs/100ft2 Gels 45 \ 65 \ pH 8.0 Sd 1.5 l Bit No.: 1 Type: HTC MXL-1 Bit Size: 12 1/4 Jets: 1 x 12 3 x 15 x _TFA: 0.6280 !:'','I On Bit: 10 RPM: 85/MM90 Hrs. On Bit: 18.9 Total Revs on Bit: 0 Footage for Bit Run 142` Trip Depth: 1523 ft Trip Gas: NCU Mud Cut: ppg Trip CI: - ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ff ~un~ ~, _iGr r:~ - IFI_ ~i; ~L-;`, ~-~u '_I~_f]I i r ..,~,L f.l Connection• Gas and Mud Cut NONE ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas iri units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot 1376 to 1395 101 40 6247 0 0 0 0 1432 to 1445 175 55 15025 0 0 0 0 1467 to 1490 2898 60 254114 0 0 0 0 to ~ 24 hr Rec~ Drill from 401' to 1523' MD, CBU- max gas 756 u on bottoms up, prepare to short trip. MAXIMUM GAS OF 2898 UNITS AT 1473' MD FROM LIGNITE COAL Cutting sample at 1500' MD consist of lignite coal in clay. i i Logging Engineer: Doug Wilson /Eugene Payne 10000 units = 100% Gas Ih Air .: - : 3 Customer: ConocoPhilli s Re ort No - I: ~ T~ "' . p p Well: Antigua-1 Date: 4/2/2006 Sperry nr~~r~n~ services Area: North Slope Depth 2474 ~', udlogger's Morning Report Lease: Exploration Footage_ Last 24 hrs: 951 ~ Rig: Doyon Akita AF1 Rig Activity:... Drilling 12 1/4" Job No.: AK-AM-4299296 Report For: Winfree / Springer 'I Current 24 hr Avg 24 hr Max R.O.P. 102 ft/hr 81.3 ft/hr ( 285 ft/hr @ 410 ) Gas* 79 units 100 unit: ( 1586 units @ 1543 ) ( ) Pump and Flow Data Pumps 159 spm Flow rate 481 gpml Pump Capacity 2.849 gps Pump Liner & Strk 6X8 in. Pump Pres 1785 psi Mud Wt In 10.00 ppg Visc 83 secs API filt 8.2 ml HTHP ml Mud Wt at Max Gas 9.6 ppg j Mud Wt Out 10.00 ppg PV 24 cP YP 38 Ibs/100ft2 Gels 32 \ 48 \ pH 8.0 Sd 1 ° Bit No.: 1 Type: HTC MXL-1 Bit Size: 12 1/4 Jets: 1 x 12 3 x 15 x TFA: 0.6280 !:'Jt On Bit: 10-15 RPM: 95/MM85 Hrs. On Bit: 30.6 Total Revs on Bit: 0 Footage for Bit Run 2~~ ? i Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: - ppm Short Trip Depth 1523 ft Short Trip Gas: 4378 Mud Cut: 9.6 ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft ~;urn_~nlLiih~~~~;~.~: _ ~~r-,'E~ 45 % ~;L,~.Y 50 ~ SANG ~I_~~:.1 ~ Connection Gas and Mud Cut NONE ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot 1508 to 1558 1610 200 142819 0 0 0 0 1573 to 1583 405 200 42942 0 0 0 0 1727 to 1741 365 120 34069 0 0 0 0 to 24 hr Rec< Short trip to DC's @ 500' , RIH, CBU- maximum gas 4378 UNITS with MW cut 10.1 to 9.6 ppg, Drill 12 1/4" hole from 1523' to 2474' MD. Cutting sample at 2430' MD consists of unconsolidated sand m-vcgr with clay interbeds. Logging Engineer: Doug Wilson /Eugene Payne 10000 units = 100% Gas In Air : 4 1 Customer: ConocoPhilli s Report No W . p Well; Antigua-1 Date: 4/3/2006 Sperry Qr91[ing services Area: North Slope Depth 3459 I udlogger's Morning Report Lease: Exploration Footage, Last 24 hrs: 985 ~ Rig: Doyon Akita AF1 Rig Activity: _ Drilling 12 1/4" Job No.: AK-AM-4299296 Report For: Winfree / Springer . I Current 24 hr Avg 24 hr Max R.O.P. 85 ft/hr 81.3 ft/hr ( 473 ft/hr @ 2499 ) Gas" 205 units 125 unit: ( 404 units @ 2974 ) ( ) - Pump and Flow Data Pumps 161 spm Flow rate 461 gpm, Pump Capacity 2.849 gpsj Pump Liner & Strk 6X8 in. Pump Pres 2200 psi Mud Wt In 10.00 ppg Visc 67 secs API filt 6.2 ml HTHP ml Mud Wt at Max Gas 10.0 ppg Mud Wt Out 10.00 ppg PV 29 cP YP 30 Ibs/100ft2 Gels 14 \ 33 \ pH 9.8 Sd 0.75 Bit No.: 1 Type: HTC MXL-1 Bit Size: 12 1/4 Jets: 1 x 12 3 x 15 x _TFA: 0.6280 ''i On Bit: 15-20 RPM: 95/MM80 Hrs. On Bit: 45.3 Total Revs on Bit: 0 Footage for Bit Run -" Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth 2505 ft Short Trip Gas: 395 Mud Cut: 9.9 ppg Short Trip CI: ppm Tight Spots: 1560 to 1640 2030 to 2260 to ~ Feet of Fill on Bottom: - ~ - i ~.u~~~-r~-iU~,~l r.~ ~ "~r~~ a ~~ I .~ _ ~~Jli ~~i`_1 Connection• Gas and Mud Cut NONE ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg. ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot 2775 to 2825 308 110 24540 0 0 0 0 2963 to 3018 404 105 37462 0 0 0 0 3077 to 3095 357 195 32476 0 0 0 0 3370 to 3425 381 105 35126 12 0 0 0 ~ i j 24 hr Rec< Drill 12 1/4" hole from 2474' to 2505, Short trip to 1500' MD, RIH, CBU- maximum gas on i BU - 395 units, Drill 12 1/4" hole from 2505 to 3459' MD Oil sheen and free oil in samples from 2730' MD Cutting sample at 3430' MD consists of 20% unconsolidated sand in clay . ~, Logging Engineer: Doug Wilson /Eugene Payne 10000 units = 100% Gas In Air .;,~ ~ : 5 ort No Customer: ConocoPhilli s Re _ "'` 1 . p p Well: Antigua-1 Date: 4/4/2006 Sperry Qr9iling sar.noes Area: North Slope Depth 4053 udlogger s Morning Report Lease: Exploration Footage Last 24 hrs: 594 -+ Rig: Doyon Akita AF1 Rig Activity:... Wiper trip Job No.: AK-AM-4299296 Report For: Winfree / Springer Current 24 hr Avg 24 hr Max R.O.P. ft/hr 56 ft/hr ( 262 ft/hr @ 3613 ) Gasp units 180 unit: ( 290 units @ 3610 ) ( ) Pump and Flow Data Pumps 145 spm Flow rate 412 gpm ii Pump Capacity 2.849 gps', Pump Liner & Strk 6X8 in.. Pump Pres 1975 psi -~ Mud Wt In 10.00 ppg Visc 72 secs API filt 6.1 ml HTHP ~ ml Mud Wt at Max Gas 10.0 ppg Mud Wt Out 10.00 ppg PV 32 cP YP 32 Ibs/100ft2 Gels 15 ~ 28 ~ 35 pH 9.4 Sd 1 Bit No.: 1 Type: HTC MXL-1 Bit Size: 12 1/4 Jets: 1 x 12 3 x 15 x _ TFA: 0.6280 ' i On Bit: 15-25 RPM: 95/MM80 Hrs. On Bit: 55.9 Total Revs on Bit: 0 Footage for Bit Run 3' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth 3493 ft Short Trip Gas: 558 Mud Cut: na ppg Short Trip CI: ppm Tight Spots: 3277 3075 to 3081 3068 2939 Feet of Fill on Bottom: ft -~~rr, niLiihci ~ iii ~ ~.- ~.~ ,•.l ~ ?gill; % _ I ~ ..i -~ Connection• Gas and Mud Cut NONE ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot 3575 to 3623 290 180 26031 15 0 0 0 3840 to 3875 250 150 21725 27 0 0 0 to to ~ 24 hr Rec Drill 12 1/4" hole from 3459' to 3493, Short trip 15 stds to 2500", RIH, CBU- maximum gas on BU - 558 units, Drill 12 1/4" hole from 3493 to 4053' MD, CBU, pump 50 bbl hi vis sweep- no significant cuttings to surface, pump slug, TOOH to HWDP (46 stds) (hole took 9.6 bbls more than talc.). TIN Oil sheen and free oii in samples from 3459' to 4053' MD Cutting sample at 4053' MD consists of 60% claystone, 30% clay and 10% unconsolidated sand in clay . i Logging Engineer: Doug Wilson /Eugene Payne 10000 units = 100% Gas In Air j -. t ~' Customer: ConocoPhillips Report No.: 6 Well: Antigua-1 Date: 4/5/2006 Sperry drilling services Area: North Slope Depth 4053 i Mudlogger's Morning Report Lease: Exploration Footage, Last 24 hrs: 0 -~ Rig: Doyon Akita AF1 Rig Activity:_ Run 9 5/8 CSG Job No.: AK-AM-4299296 Report For: Winfree / Springer Current 24 hr Avg 24 hr Max R.O.P. ft/hr ft/hr ( ft/hr @ ) Gasp units 90 unit; ( 325CBU units @ ) ( ) Pump and Flow Data Pumps 145 spm Flow rate 412 gpm Pump Capacity 2.849 gps Pump Liner & Strk 6X8 in. Pump Pres 1975 psi Mud Wt In 10.10 ppg Visc 65 secs API filt 4.8 ml HTHP ml Mud Wt at Max Gas 10.0 ppg ~ Mud Wt Out 10.10 ppg PV 31 cP YP 28 Ibs/100ft2 Gels 12 \ 17 \ 25 pH 9.4 Sd 0.5 °' - - ~ ~ No.: Type: Bit Size: Jets: x x _ x _ TFA: I'>` - r Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: "~ see below Mud Cut: ppg Trip CL ppm Short Trip Depth 4053 ft Short Trip Gas: 290 ** Mud Cut: na ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft ~irr n~ L[tl~~ i ri, >!i ~ :ne, ~~ii ~~ ~-;1" L) ~ ,. -i1D _ i,l Connection Gas and Mud Cut NONE ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg i GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to to to to I 24 hr Rec TIH for wiper trip, wash down f/ 4015-4053', CBU- 3 peaks seen- 1st- 275 units (2300 stks-2100 lag depth- Vignite), 2nd- 325 units (6000 stks-3500' lag depth-sand, 3rd- 290 units bottoms up, pump hi vis sweep to circ hole clean, run water to reduce MW after trip, TOOH-( hole fill took 4.6 bbls more than calc), rig up to run 9 5/8" casing, run 9 5/8" casing to jt 50 tight CBU and work through (BU yielded large amt 3" pieces of lignite/wood fragments and clay ) continue to run 9 5/8" casing at report time. Logging Engineer: Doug Wilson /Eugene Payne 10000 units = 100% Gas In Air ' : 7 Customer: ConocoPhillips Report No `"' . Well: Antigua-1 Date: 4/6/2006 Sperry nrilr~ng services .Area: North Slope Depth 4053 udlogger's Morning Report Lease: Exploration Footage Last 24 hrs: 0 ~ Rig: Doyon Akita AF1 Rig Activity:... Nipple Up Job No.: AK-AM-4299296 Report For: Winfree I Springer Current 24 hr Avg 24 hr Max R.O.P. ft/hr ft/hr ( ft/hr @ ) Gas° units 46 unit: ( 104CBU units @ ) ( ) Pump and Flow Data circ BU csg Pumps 132 spm Flow rate 377 gpm Pump Capacity 2.849 gps Pump Liner & Strk 6X8 in. Pump Pres 615 psi Mud Wt In 10.10 ppg Visc 65 secs API filt 4.8 ml HTHP ml Mud Wt at Max Gas 10.0 ppg Mud Wt Out 10.10 ppg PV 31 cP YP 28 Ibs/100ft2 Gels 12 \ 17 \ 25 pH 9.4 Sd 0.5 ~ Bit No.: Type: Bit Size: Jets: x x _x _TFA: ~Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run _~ Trip Depth: ft Trip Gas: Mud Cut: - ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: na ppg Short Trip CI: ppm Tight Spots: to !Feet of Fill on Bottom: ft ~~irr_~n~ Lii!~, I ~ ,, ~ ri ~~~ ;~_, L~;~: 1~1 ~ -~.f1C~ ~ °~, C:~.l Connection• Gas and Mud Cut I NONE ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg i GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to to to to 24 hr Rec< Run 9 5/8" casing to 4053', total lost mud by sperry= 11 bbls, CBU- max BU gas = 104 units (average circ gas = 46 units ), circulate 11900 strokes, rig up to cement, dump pits, cement 9 5/8" casing per plan, rig down cement equip, nipple up BOP's. I I I Logging Engineer: Doug Wilson /Eugene Payne 10000 units = 100% Gas In Air - : 8 ~ Customer: ConocoPhillips Report No '" . ` " . Well: Antigua-1 Date: 4/7/2006 Sperry L?riEting serv7cas Area: North Slope Depth 4053 udlogger's Morning Report Lease: Exploration Footage. Last 24 hrs: 0 ~ Rig: Doyon Akita AF1 Rig Activity:... Nipple Up Job No.: AK-AM-4299296 Report For: Winfree / Springer Current 24 hr Avg 24 hr Max R.O.P. ft/hr ft/hr ( ft/hr @ ) Gas* units unit: ( units @ ) ( ) Pump and Flow Data circ BU csg '~~ Pumps spm Flow rate gpm j Pump Capacity 2.849 gps Pump Liner & Strk 6X8 in. Pump Pres psi Mud Wt In 9.40 ppg Visc 54 secs API filt 6.2 ml HTHP ml Mud Wt at Max Gas 9.4 ppg Mud Wt Out 9.40 ppg PV 10 cP YP 18 Ibs/100ft2 Gels 6 \ 8 \ pH 8.1 Sd ° i F i ~ No.: Type: Bit Size: Jets: x x x _ TFA: I On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: na ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft ~nrent Litholog~,. ~ i >~~~: '~~! % CLAY 10 % ~.Pll=~ ~~ ~I ~ .. Connection Gas and Mud Cut ~ NONE ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg i GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to to ~ I to to 24 hr Rec< Nipple up BOP's, test BOP's, fill pits with new mud. i I Logging Engineer: Doug Wilson /Mark Lindloff 10000 units = 100% Gas In Air ,~ Customer: ConocoPhilli s : 9 j ort No Re "` Well: p Antigua-1 . p Date: 4/8/2006 Sperry ari!ling Services Area: North Slope Depth 4053 udlogger's Morning Report Lease: °~ Rig: Job No.: Exploration Doyon Akita AF1 AK-AM-4299296 Footage. Last 24 hrs: 0 Rig Activity:... Drill rathole/cmt Report For: Winfree / Springer ~ Current 24 hr Avg R.O.P. ft/hr ft/hr ( Gas* units unit: ( 11 ( 24 hr Max ft/hr @ units @ 4053 ) ) ) Pump and Flow Data Pumps 195 spm Flow rate 385 gpm Pump Capacity 1.979 gps' Pump Liner & Strk 5X8 in., Pump Pres 1054 psi Mud Wt In 9.40 ppg Visc 52 secs API filt 6.2 ml HTHP ml Mud Wt at Max Gas 9.4 ppg Mud Wt Out 9.40 ppg PV 9 cP YP 18 Ibs/100ft2 Gels 8 \ 9 \ _ pH 8.1 Sd 0 l J Bit No.: 2 Type: HC/DS619S-A-9 Bit Size: Wt On Bit: RPM: Hrs. On Bit: 8 1/2 Jets: 6 x 16 x _x _TFA: 1.1780 Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to Mud Cut: ppg Trip CI: ppm Mud Cut: na ppg Short Trip CI: ppm Feet of Fill on Bottom: ft ~ '~.rn ~r,t L!~i~;~ I ~:r.- ~ ~~ ~ ~ ~n~ ~ ~ Lam, l i_i ~ ;f~1D ~ I l I Connection Gas and Mud Cut NONE ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units pp~ Depth Gas in units Max Background to to to to GAS PEAKS Chromatograph in ppm C1 C2 C3 C4 Tot C5 Tot ~ 24 hr Rec, Finish testing BOP's, P/U BHA #2 an d RIH, drlg cement. i i Logging Engineer: Doug Wilson /Mark Lindloff ~ 10000 units = 100% Gas In Air --- Customer: ConocoPhillips Report No.: 10 FIALLIBUlRTO1V Well: Antigua-1 Date: 4/9/2006 Sp®rry Grilling services Area: North Slope Depth 4970 Lease: Exploration Footage Last 24 hrs: 917 Rig: Doyon Akita AF1 Rig Activity: Drill 8 1/2" hole Job No.: AK-AM-4299296 Report For: Winfree / Springer Mudlogger's Morning Report Current 24 hr Avg 24 hr Max Pump and Flow Data " R.O.P. 50 ft/hr 64 ft/hr ( 300 ft/hr @ 4148 ) Pumps 242 spm Flow rate 485 gpm ;; := Gas'' 14 units 19 unit: ( 68 units @ 4089 ) Pump Capacity 1.979 gps `: ( ) Pump Liner & Strk 5X8 in. ~'~ . ,. Pump Pres 2420 psi } ;t = 4, ~. f_ ,. F _ Mud Wt In 9.40 ppg Visc 52 secs API felt 6.2 ml HTHP ml Mud Wt at Max Gas 9.4 ppg ''~ ~: Mud Wt Out 9.40 ppg PV 9 cP YP 18 Ibs/100ft2 Gels 8 \ 9 \ _ pH 8.1 Sd 0 r~ - , A ;K !r ~:'.fr fY, ~ i ..S +' ~ c' ~-_ w.~c` ~ , .F ,; tiz ~a . }r- Bit No.: 2 Type: HC/DS619S-A-9 Bit Size: 8 1/2 Jets: 6 x 16 x x TFA: 1.1780 Wt On Bit: 8-12 RPM: 86/mm137 Hrs. On Bit: 14.6 Total Revs on Bit: Footage for Bit Run y ~ r Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: na ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft '; Current Lithology: 70 % Siltstone 30 % Claystone % % %LCM ". . t '.~.K~ i . Connection Gas and Mud Cut '~ NONE ft units ppg ft units ppg ft units ppg fi~ ft units ppg ft units ppg ft units ppg ~_`- ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ~< ~ ~~ 1 4 5,~'~~'~~{~ ~-~1F :y.~x=r t.'J ~. f', .-(~~v, a Y~F.?. ~?1a.. ~ ~~~~.~ }';.._,. ,1 Y _ _ 'f~i ~ Y" ~ i~l . GAS PEAKS . '~~ Depth Gas in units Chromatograph in ppm t ~< Max Background C1 C2 C3 C4 Tot C5 Tot `~' 4078 to 4092 68 25 5483 12 3 0 0 ~=' ~,~ ~'~~ to '~` to ~~ to 1. ~ >;7~ ~~ lr« rf i:'?_ s ~ ~ ~~. rt T^~ i~l~ ~~;?. ~~,~ i~lA{ ~''.F.~ ~'.~ - ~ t F ~kr ~~ ,P ~ ~ t . ~ .. '3' , ~` Rec~ Drill cement rathole and 20' 8 1/2" hole new formation to 4073' MD, displace mud with 9.4 pp new mud, 24 hr erform F.I.T. to 13.2 pp EMW, Continue drillin 8 1/2" hole from 4073' to 4970 ' PWD at 4970' 10.7 ppg clean hole ECD - 10.3 with 9.5 ppg MW at 485 GPM ~~ *" Note: some polymer plugging of gas trap at shaker header box. "` "** saw flow increase from 30% to 50% at 4608'- check flow-static- due to clay on flow sensor? Logging Engineer: Doug Wilson /Mark Lindloff 10000 units = 100% Gas In Air ~~' r - -- : 11 ort No Customer: ConocoPhillips Re ~°"°° . p Well: Antigua-1 Date: 4/10/2006 Sperry or,ttt„s services Area: North Slope Depth 5763 ' Mudlogger's Morning Report Lease: Exploration Footage. Last 24 hrs: 793 -~ Rig: Doyon Akita AF1 Rig Activity:... Drill 8 1/2" hole Job No.: AK-AM-4299296 Report For: Winfree / Springer Current 24 hr Avg 24 hr Max 'R.O.P. 50 ft/hr 55 ft/hr ( 144 ft/hr @ 5212 ) Gas* 45 units 30 unit: ( 64 units @ 5588 ) i ( } ~i ~ Pump and Flow Data Pumps 247 spm Flow rate 485 gpm Pump Capacity 1.979 gps Pump Liner & Strk 5X8 in. Pump Pres 2790 .psi _~ Mud Wt In 10.00 ppg Visc 54 secs API filt 4.8 ml HTHP ml Mud Wt at Max Gas 10.0 ppg ~I Mud Wt Out 10.00 ppg PV 19 cP YP 22 Ibs/100ft2 Gels 7 \ 9 \ pH 9.0 Sd 0.25 L i C i~ No.: 2 Type: HCIDS619S-A-9 Bit Size: 8 1/2 Jets: 6 x 16 x x TFA: 1.1780 ! -; r. Bit: 7-11 RPM: 86/mm137 Hrs. On Bit: i4.6 Total Revs on Bit: Footage for Bit Run 1710 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: - ppm I, Short Trip Depth 5015 ft Short Trip Gas: 270 Mud Cut: na ppg Short Trip CI: ppm ~ Tight Spots: to Feet of Fill on Bottom: ft _~ Connection Gas and Mud Cut NONE ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units pp~ ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot 5296 to 5381 46 19 3579 49 4 0 0 5514 to 5646 64 35 4930 30 12 4 0 to to j _-~ 24 hr Rec~ Drill 8 1/2" hole from 4970-5015' MD, perform 15 std short trip to 9 5/8" casing shoe (4021' MD), C_ BU_ maximum short trip gas 270 units, no fill on bottom, resume drlg from 5015 to 5763' MD PWD at 5750' 11.1 ppg clean hole ECD ~ 10.65 with 10.0 ppg MW at 490 GPM '* Note: large amount of clay returns on bottoms up after short trip -dumped and diluted mud. ** Incr MW to 10.0 ppgand reduced water loss for HRZ EST Pore Pressure = 9.1 ppg Logging Engineer: Doug Wilson /Mark Lindloff 10000 units = 100°!o Gas In Air ~, r - -- _ `® Customer: Well: ConocoPhillips Antigua-1 Report No.: 12 Date: 4/11 /2006 I Sperry C3ritring sar.goes Area: North Slope Depth 6452 udiogger's Morning Report Lease: ~ Rig: Job No.: Exploration Doyon Akita AF1 AK-AM-4299296 Footage Last 24 hrs: 689 ' Rig Activity:.. Drill 8 1/2" hole Report For: Winfree / Springer j I Current 24 hr Avg R.O.P. 34 ft/hr 38.5 ft/hr ( 150 Gas* 96 units 70 unit: ( 140 ( 24 hr Max ft/hr @ 6012 units @ 6397 ) ) ) Pump and Flow Data Pumps 247 spm Flow rate 486 gpm Pump Capacity 1.979 gps Pump Liner & Strk 5X8 in. Pump Pres 2960 psi Mud Wt In 10.30 ppg Visc 54 secs API filt 4.4 ml HTHP 10.6 ml Mud Wt at Max Gas 10.3 ppg Mud Wt Out 10.30 ppg PV 22 cP YP 24 Ibs/100ft2 Gels 7 \ 10 \ pH 8.4 Sd 0.25 °~ i - ~ ~ J Eir No.: 2 Type: HC/DS619S-A-9 Bit Size: '.'t - ~, Bit: 12-Oct RPM: 86/mm137 Hrs. On Bit: 8 1/2 Jets: 6 x 16 x x _TFA: 1.1780 43.7 Totai Revs on Bit: Footage for Bit Run 239 Trip Depth: ft Trip Gas: Short Trip Depth 6291 ft Short Trip Gas: Tight Spots: to Mud Cut: ppg Trip CI: ppm 375 Mud Cut: na ppg Short Trip CI: ppm Feet of Fill on Bottom: ft >,irr~ nt Liti~uiogy: ~! ~i ~ ;'Ir~~l~_~ ~ ~ I ~. ~ 1 _~ Connection Gas and Mud Cut i NONE ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Depth Gas in units Max Background 6220 to 6240 120 95 6365 to 6410 140 110 to to GAS PEAKS Chromatograph in ppm I C1 C2 C3 C4 Tot C5 Tot 8229 560 184 53 8 8920 677 270 90 18 ~ '~ 24 hr Rec~ Drill 8 1/2" hole from 5015'-6291' MD, perform 15 std short trip, CBU, maximum short trip gas 375 units. Resume drlg from 6291' to 6452' MD PWD at 6452' 11.0 ppg ECD with 10.3 ppg. MW at 486 GPM i EST Pore Pressure = 9.1 ppg Logging Engineer: Tom Mansfield /Mark Lindloff 10000 units = 100% Gas In Air Customer: ConocoPhillips Report No.: 13 HALLIBUF~TOIV Well: Antigua-1 Date: 4/12/2006 s~p®rry drilling Ssrvfass Area: North Slope Depth 6850 Lease: Exploration Footage Last 24 hrs: 398 Rig: Doyon Akita AF1 Rig Activity: TD, UD BHA t Mudlogger's Morning Report Job No.: AK-AM-4299296 Report For: Winfree / Springer Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. na ft/hr 48.5 ft/hr ( 150 ft/hr @ 6012 ) Pumps spm Flow rate 486 gpm Gas" na units 70 unit: ( 140 units @ 6397 ) Pump Capacity 1.979 gps ' ( ) Pump Liner & Strk 5X8 in. . Pump Pres psi r_- , E ~ ~ Mud Wt In 10.20 ppg Visc 53 secs API felt 4.2 ml HTHP 10.4 ml Mud Wt at Max Gas 10.2 ppg Mud Wt Out 10.20 ppg PV 21 cP YP 23 Ibs/100ft2 Gels 7 \ 9 \ pH 9.0 Sd 0.25 Bit No.: 2 Type: HC/DS619S-A-9 Bit Size: 8 1/2 Jets: 6 x 16 x x TFA: 1.1780 Wt On Bit: 12 RPM: 86/mm137 Hrs. On Bit: 51.9 Total Revs on Bit: Footage for Bit Run 2797 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth 6850 ft Short Trip Gas: 881 Mud Cut: na ppg Short Trip CI: ppm Tight Spots: to Feet of Fill on Bottom: ft Current Lithology: 95 % Shale 5 % Siltstone % % %LCM -...:• ~ Connection Gas and Mud Cut NONE ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units pP9 ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot 6620 to 6645 123 50 7150 682 282 97 24 6670 to 6700 135 80 8730 831 346 124 35 to to 24 hr Rec< Drill 8 1/2" hole from 6452' to 6535' MD. Perform F.I.T. to 12.9 p .Drill ahead from 6535' to 6850' MD, TD. Circ and sweep hole. Short tri 15 stands, CBU, short trip as 881 units. Swee hole, pump slu and POOH. EST Pore Pressure = 9.1 ppg Logging Engineer: Tom Mansfield /Mark Lindloff 10000 units = 100% Gas In Air -~. ,. -- Customer: ConocoPhillips Report No.; 14 __ _ _ Well: Antigua-1 Date: 4/13/2006 Sperry o.-~n~ng serv~oas Area: North Slope Depth 6850 Lease: Exploration Footage Last 24 hrs: 0 ~ Rig: Doyon Akita AF1 Rig Activity: _ POOH Job No.: AK-AM-4299296 Report For: Winfree / Springer Mudlogger's Morning Report Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. na ft/hr na ft/hr ( ft/hr @ ) Pumps spm Flow rate 486 gpm i Gasp na units 25 unit: ( 645 units @ 6850 ) Pump Capacity 1.979 gps ~ ( ) i Pump Liner & Strk 5X8 in.', Pump Pres psi Mud Wt In 10.30 ppg Visc 52 secs API filt 4.4 ml HTHP 10.6 ml Mud Wt at Max Gas 10.3 ppg Mud Wt Out 10.30 ppg PV 21 cP YP 20 Ibs/100ft2 Gels 6 \ 7 \ _ pH 9.2 Sd ` 025 x _TFA: 1.1780 Bit No.: 2 Type: HC/DS619S-A-9 Bit Size: 8 1/2 Jets: 6 x 16 x _ `. i On Bit: 12 RPM: 86/mm137 Hrs. On Bit: 51.9 Total Revs on Bit: Footage for Bit Run 2797 Trip Depth: 6850 ft Trip Gas: 645 Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: na ppg Short Trip CI: ppm I Tight Spots: to Feet of Fill on Bottom: ft ~rr~.,n~ kith- I ~ ~_~ ~ ; ~h~i;, - ~ i i;;~,,_ ~ ~ ~ i-I ~ Connection~Gas and Mud Cut NONE ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ! ft units ppg ft units ppg ft units ppg GAS PEAKS Depth Gas in units Chromatograph in ppm ~ Max Background C1 C2 C3 C4 Tot C5 Tot to to to to j -~ 24 hr Rec< Finished POOH. L/D MWD tools and rig up for wireiine logs. Unable to get logging tool past bridge at 3826'. POOH w/ logging toot. Cleaned clay from tool. RIH w/ logging tool. Hit bridge at 4841'. POOH w/ logging tool. -RIH w/ clean out assembly. Circ and Cond hole. Trip gas of 645 units. Prep to POOH at report time. ', Logging Engineer: Tom Mansfield /Mark Lindloff 10000 units = 100% Gas In Air - -- ~°°' ~"` Customer: ConocoPhillips Report No.: 15 Well: Antigua-1 Date: 4/14/2006 Sperry c3.->>r~n~ s~rvicas Area: North Slope Depth. 6850 ~, Mudlogger's Morning Report Lease: Exploration Footage, Last 24 hrs: 0 -~ Rig: Doyon Akita AF1 Rig Activity: _ Prep to CMT Job No.: AK-AM-4299296 Report For: Winfree / Springer Current 24 hr Avg 24 hr Max R.O.P. na ft/hr na ft/hr ( ft/hr @ ) Gas* 10 units 20 unit: ( 87 units @ 6850 bu ) ( ) Pump and Flow Data ~ Pumps spm Flow rate 486 gpm Pump Capacity 1.979 gps; Pump Liner & Strk 5X8 in. Pump Pres psi Mud Wt In 10.20 ppg Visc 52 secs API filt 4.2 ml HTHP 10.0 ml Mud Wt at Max Gas 10.2 ppg Mud Wt Out 10.20 ppg PV 18 cP YP 16 Ibs/100ft2 Gels 5 \ 6 \ pH 9.2 Sd 0.25 °~ Bit No.: 2 Type: HC/DS619S-A-9 Bit Size: 8 1/2 Jets: 6 x 16 x x _TFA: 1.1780 ';"."t On Bit: 12 RPM: 86/mm137 Hrs. On Bit: 51.9 Total Revs on Bit: Footage for Bit Run 2-^- ~ Trip Depth: 6850 ft Trip Gas: 87 Mud Cut: ppg Trip CI: ppm ~ i Short Trip Depth ft Short Trip Gas: Mud Cut: na ppg Short Trip CI: ppm ! Tight Spots: to Feet of Fill on Bottom: ft I in ll _iii~~ I ,~. i-i - ~~ir i ~r ~ ~_:f.l ConnectiomGas and Mud Cut NONE ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ~ GAS PEAKS Depth Gas in units Chromatograph in ppm Max Background C1 C2 C3 C4 Tot C5 Tot to ~ i to ~ to to 24 hr Rec< Pumped sweep around. POOH. Ran wireline logs, Dipole Sonic and Rotary Cores. 71H open ended to set cement plug. Circulated on bottom with Trip Gas of 87 units, background of 20 units. Prepare to CMT. I Logging Engineer: Tom Mansfield /Mark Lindloff 10000 units = 100% Gas In Air - -- _~ .7r~ ~r ~: ~; $ pe r~~$ u n DRILLING SERVICES Show Report ,. :, a,~ n ~ ~ >,~ Well Name: Antigua-1 Depth (MD) 2960 to 3050 ft Location: NORTH SLOPE (ND) 2960 to 3050 ft ` Operator: CONOCOPHILLIPS ALASKA, INC. Show Report No. 1 y' Report Prepared By: Doug Wilson/ Eugene Payne Datelrime: 4/2/2006 Report Delivered To: A. Andreou Interpretation: Gas show corresponds to sand in Ugnu A. Sand: clear to white, fine to medium grain, subangular to angular, ~~. unconsolidated, well sorted, non calcareous, 10% orange yellow natural fluorescence, fair white green cut fluorescense. Oil sheen and free oil noted in mixed clay and unconsolidated sands, faint oil odor noted. . GAS : Before / Max /After 50 units / 523 units /120 units No pixler plots due to non presence of C2-C5's in chromatograms r ., , . .,. ..: .. ,,. _ ~.: ,. ~... . 1 % Depth 2974 ft Gas x Units # # 399 Mud Chlorides (ppm) = NA --Flowline------ Suction ----- Show ----------°-^------------------------------° Hydrocarbon Ratios C1 C1 C1 C1 - - - C2 C3 C4 C5 ppm ppm ppm (Steam Still PPM's in 1000'x) Hydrocarbon Ratios 1000 0 C1 37 5 - 0 00 37 5 1/C2 =## . -- - . . . ### G _ _ C2 0.00 - 0.00 = 0.00 C1/C3 =##### - - ' ' ~ C3 0.00 - 0.00 = 0.00 C1/C4 =#>%### _ C4 0.00 - 0.00 = 0.00 C1/C5 = 1973.7 NPH __ C5 0.02 - 0.00 = 0.02 --------------°---------------------°------------------------------------°------- Production 100.0 - _ - -- ~.-„ ~ ~~ - .. Analysis Gas Oil Water xNon-Producible Hydrocarbons _ - 2 % _ ~ - --- Depth # 2992 ft Gas x Units 350 Mud Chlorides (ppm) = NA - ` - ~, ------------------------------ Flowline Suction - ---- --------------------------------------°---- Show Gas pPm ppm pPm (Steam Still PPM's in 1000'x) Hydrocarbon Ratios 0.0 __--- - _ _ _ .. - --- - - --------- ' G1 31 7 - 0 00 = 31 7 C1/C2 =##### - . . . C2 0 00 _ _____ ___ . - 0.00 = 0.00 C1/C3 =##### _-_ '. C3 0.00 - 0.00 = 0 00 C1/C4 =##### Oil -- . C4 0.00 - 0.00 = 0 00 C1/C5 =##### . C5 0.00 - 0.00 = 0.00 - ---------------------------------------------------------------- ---------------- p NPH 1 0 Y roduction Analysis Gas Od Water xNon-Producible H drocarbons . s % _ Depth 3028 ft Gas x Units 266 Mud Chlorides (ppm) = NA Flowline Suction Show Hydrocarbon Ratios C1 C1 C1 C1 - `' C2 C3 C4 C5 ppm ppm ppm (Steam Still PPM's in 1000'x) Hydrocarbon Ratios 1000 0 ~ C1 15.4 0 00 = 15 4 C1/C2 =##### . - . . ' _ ` C2 0.00 - 0.00 = 0.00 C1/C3 =##### C3 0.00 - 0.00 = 0.00 C1/C4 =>%#### NPH - ~ C4 0.00 0.00 = 0.00 C1/C5 = '! C5 0.00 - 0.00 = 0.00 - ---°--------------------------------------------------------------------------°- production 100.0 __ -- ,• -~--- -- ~~ ----------- Analysis Gas pil Water xNon-Producible Hydrocarbons -- -- Depth ft Gas x Units Mud Chlorides (ppm) = NA Gas _ _ --F~owlirie------Suction ----- Show'---------°----------------------------------- ~ - 5 ppm PPm PPm (Steam Still PPM's in 1000'x) Hydrocarbon Ratios 10.0 _ _ ~ _ .. - - - - --- ---------- C1 0.0 - 0 00 = 0 0 C1/C2 =##### _ - ----- . . -~ C2 0 00 0 0 Oil ---- - . - . 0 = 0.00 C1/C3 =##### C3 0.00 - 0.00 = 0.00 C1/C4 =##### C4 0.00 - 0.00 = 0 00 C1/C5 =#>!### . C5 0.00 - 0.00 = 0.00 ---------°------------------- ---------------------------------------°---- NPH 1 0 `-` Production Analysis Gas Oil Water xNon-Producible Hydrocarbons . L Sper~~sun DRILLING SERVICES Show Report Well Name: Antigua-1 Depth (MD) 3050 to 3460 ft Location: NORTH SLOPE (TVD) 3049 to 3059 ft e Operator: CONOCOPHILLIPS ALASKA, INC. Show Report No. 2 Report Prepared By: Doug Wilson/ Eugene Payne Date/Time: 4/3/2006 Report Delivered To: A. Andreou Interpretation: Gas show corresponds to sand in Ugnu A. Sand: clear to white, fine to medium grain, subangular to angular, unconsolidated, well sorted, non calcareous, 10-20% orange yellow natural fluorescence, fair-good white-gold cut fluorescence. Free oil and oil sheen noted on mixed clay and sand samples, sands interbedded and imbedded with clay, very faint oil odor noted. GAS : Before / Max /After 105 units / 383 units /200 units No pixler plots due to nonpresence of C2-C5 gases in chromatograms 1 % Depth 3088 ft Gas x Units # # 358 Mud Chlorides (ppm) = NA ----------------°---------------- ------------------------------------------------- Flowline Suction Show Hydrocarbon Ratios C1 C1 C1 C1 C2 C3 C4 C5 ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 1000 0 ~'! C1 32 4 - 0 00 = 32 4 C1/C2 =## . . . . ### __ C2 0.00 - 0.00 = 0.00 C1/C3 =##### - C3 0.00 - 0.00 = 0.00 C1/C4 =##### C4 0.00 - 0.00 = 0.00 C1/C5 = 1705.3 NPH _ C5 0.02 - 0.00 = 0.02 -----------------------°----------------------------------------°----------------- Production 100.0 -_- - --- ~. ' ~~ - Analysis Gas pil Water xNon-Producible Hydrocarbons ;, 2 % , _ Depth # 3284 ft Gas x Units 142 Mud Chlorides (ppm) = NA Flowline Suction - _ Show Gas PPm PPm PPm (Steam Still PPM's in 1000's) Hydrocarbon Ratios ` 10.0 _ __ --- __ - - - - - ---------- _ _ ----------- C1 12 0 - 0 00 = 12 0 C1/C2 =##### --- - . . . _ G2 0 00 0 - __ . - .00 = 0.00 C1/C3 =a>'#### j G3 0.00 - 0.00 = 0 00 C1/C4 =##### Oil _ . ~' G4 0.00 - 0.00 = 0 00 C1/C5 =a;## - . G5 0.00 - 0.00 = 0.00 " ~-----°--------------°---°-------------°---------------------------------------- NPH 1 0 Production Analysis Gas Oil Water xNon-Producible Hydrocarbons . 3 % Depth 3375 ft Gas x Units 231 Mud Chlorides (ppm) = NA ' Flowline----'- Suction ---'- Show T-"-------"----------------'-------- C C Hydroca 1 C 2 C rbon Ratios 1 C1 C 3 C4 C 1 5 ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 1000 0 C1 20.1 - 0 00 = 20 1 C1/C2 =# . - . . _ C2 0.00 - 0.00 = 0.00 C1/C3 =#il### __ - - __ C3 0.00 - 0.00 = 0.00 C1/C4 =##### NPH --- C4 0.00 - 0.00 = 0.00 C1/C5 =!# ___ _ ------ --- C5 0.00 - 0.00 = 0.00 Production 100.0 ---~~ ~~ ----------------- Analysis Gas Oil Water x Npn-Producible Hydrocarbons - - _ ___-- _ 4 % -- Depth 3411 ft Gas x Units 383 Mud Chlorides (ppm) = NA Gas - Flowline §uction §how _- - ,_ PPn- Ppm PP-n (Steam Still PPM's in 1000's) Hydrocarbon Ratios 10.0 _ _ _ ~ ___ - -- _ _ --- `~ C1 35.1 - 0 00 = 35 1 C1/C2 = 3510 0 _ . . . __ C2 0 01 0 00 Oil . - . = 0.01 C1/C3 = C3 0.00 - 0.00 = 0.00 C1/C4 =/•# C4 0.00 - 0.00 = 0.00 C1/C5 =##### - - ~- - '' C5 0.00 - 0.00 = 0.00 --------°-------------------- --------------------------------------------- NPH 1 0 - Production Analysis Gas Oil Water xNon-Producible Hydrocarbons q N.t N7<i 1' . _~ :, ;ii 1 ' I~; I ~ ~ , i ~~` spert"~/-sun : ?. : ,. , ; ~;;i;; 1?nIi ~ r;iwiliuy nf~.. , Well Name: Antigua-1 Depth (MD) 6619 to 6700 ft ~'' DRILLING SERVICES Show Report Location: NORTH SLOPE (TVD) 6618 to 6699 ft Operator: CONOCOPHILLIPS ALASKA, INC. Show Report No. 3 Report Prepared By: Tom Mansfield / Mark Lindloff Date/Time: 4/11/2006 Report Delivered To: A. Andreou rt~ Interpretation: Gas show corresponds to sand in Kuparuk C Sandstone: clear to black, green, gray, brown, very fine to fine grain "II with occasional medium gram, subangular to subrounded, moderate to poorly sorted, abundant glauconite, friable to well cemented quartz ~~ cement, occasional) sli ht to moderate) calcareous, n oint oil stainin 5% moderate) bri ht el sam le fluorescence, fair fast Y 9 Y Pi P 9, Y 9 Y p yellow cut fluorescence. GAS : Before / Max /After 105 units / 383 units /200 units 1 % Hydrocarbon Ratios Depth 6618 ft Gas x Units 54 Mud Chlorides (ppm) = NA --Flowline------ Suction ----- Show ---------------------------------------------- C1 C1 C1 C1 - - - - C2 C3 C4 C5 ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 1000 0 C1 71 5 - 0 00 = 71 5 C1/C2 = 10 5 ~ . . . . . I _ - _ C2 6.82 - 0.00 = 6.82 C1/C3 = 25 4 _- . - - C3 2.82 - 0.00 = 2.82 C1/C4 = 73.7 - _ - C4 0.97 - 0.00 = 0.97 C1/C5 = 297.9 NPH C5 0.24 - 0.00 = 0.24 Producton 100.0 a ~ ' q Analysis Gas Oil Water xNon-Producible Hydrocarbons ~ ~ ~ __ - _____ 2 % ~ - __ 1 Depth 6629 ft Gas __ ' Flowline°----Suction ----- x Units_ 96 Mud Chlorides - m - ----------------- Show ------------------------ PP as _ __ _ - PPm PPm PPm _ - - - ~ - _ 1 (Steam Still PPM's in 1000's) Hydrocarbon Ratios 10.0 J ' C1 101.9 - 0.00 = 101.9 C1/C2 = 9.3 - ~ C2 11.00 - 0.00 = 11.00 C1/C3 = 21.1 ~ - j C3 4.83 - 0.00 = 4.83 C1/C4 = 63 7 I Oil . C4 1.60 - 0.00 = 1.60 C1/C5 = 248 6 - - - - - - - - . C5 0.41 - 0.00 = 0.41 - -------------------------------------------------------------------- -°----------- P d i NPH 1 0 ro uct on . Analysis Gas Uil Water xNon-Producible Hydrocarbons s % Hydrocarbon Ratios Depth 6672 ft Gas x Units 107 Mud Chlorides (ppm) = NA --Flowline------Suction ------$how ---------------------------------------------- C1 C1 C1 C1 - - - - C2 C3 C4 C5 ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios 1000 0 C1 64.6 - 0.00 = 64.6 C1/C2 = 10 6 . . C , - 2 6.09 - 0.00 = 6.09 C1/C3 = 24.6 _ C3 2.63 - 0.00 = 2.63 C1/C4 = 66.6 NPH - C4 0.97 - 0.00 = 0.97 C1/C5 = 248.5 --- C5 0.26 - 0.00 = 0.26 _ _ Production i~; Analysis Gas Oil Water xNon-Producible Hydrocarbons 100.0 _ ~ - ~ . - _ - -: _ 4 % -__ Depth 6691 ft Gas x Units 143 Mud Chlorides (ppm) = NA Gas __ Flowline suction dhow _ _ _ - - PPm PPm PPm - - _ _ (Steam Still PPM's in 1000's) Hydrocarbon Ratios 10.0 C1 87.3 - 0.00 = 87.3 C1/C2 = 10.5 _ _.-_ ; C2 8.31 - 0.00 = 8.31 C1/C3 = 25.2 Oil - - - C3 3.46 - 0.00 = 3.46 C1 /C4 = 70.4 - -- - - '' C4 1.24 - 0.00 = 1.24 C1/C5 = 249.5 €,: - ^ - - - - ~ - C5 0.35 - 0.00 = 0.35 NF ~ --- ---------------- ------ --------------------------------------------- P d i 0 ro uct on , „~ Analysis Gas Uil Water ~` „~: ,::::, . , ~„ ,, :..:. ~; ~` !=1!li "~ xNon-Producible Hydrocarbons , ,::: ; ~ , a;i;e!:' i ~ ?; '~; iii ;r - : ; t . , , ,. ~perry~vun ConocoPhillips Alaska, Inc. Antigua-1 API# 50-029-23299-00 2"1100' FORMATION MUD LOG o~ o~ Q w 0 V Z Q J m V G a 0 0 rn Sperry-.'run ConocoPhillips Alaska, Inc. Antigua-1 API# 50-029-23299-00 2"/100' DRILLING DYNAMICS LOG rn rn Y 4 w 0 x v z Q 0 J m V_ Q O O O~ ~O Y a W 0 x V Z Q O J m U G a 0 0 o, .o ~perry~~un ConocoPhillips Alaska, Inc. Antigua-1 API# 50-029-23299-00 2"/100' LWD FORMATION LOG ~~ Y a w 0 U Z Q J m V G a 0 0 rn ~perry~~un ConocoPhillips Alaska, Inc. Antigua-1 API# 50-029-23299-00 2"/100' GAS RATIO SHOW LOG rn rn Y Q w O T V Z Q J m U G a 0 0 o~ '~~ Sperry-dun ConocoPhillips Alaska, Inc. Antigua-1 API# 50-029-23299-00 EOWR DATA CD • 1~/ilk IZE SUMMARY - ConocoPhilli s Alaska Anti ua #1 KRU CON FI DEN 1 ~~L. GRAINS p 9 Depth (ft) 6620.0 6621.0 6622.0 6624.0 6625.0 6626.0 6627.0 6628.0 6629.0 6630.0 6631.0 6632.0 Mean (phi) 6.581 2.120 2.217 1.947 2.172 2.111 2.115 2.082 2.137 2.023 1.865 1.986 Mean (mm) 0.010 0.230 0.215 0.259 0.222 0.232 0.231 0.236 0.227 0.246 0.275 0.252 Mean (Sieve Equivalent) (phi) 6.524 2.357 2.447 2.195 2.405 2.348 2.352 2.321 2.372 2.266 2.118 2.232 Mean (Sieve Equivalent) (mm) 0.011 0.195 0.183 0.218 0.189 0.196 0.196 0.200 0.193 0.208 0.230 0.213 Std. Dev. (phi) 4.071 0.507 1.137 0.420 0.352 0.374 0.380 0.390 0.361 0.350 0.453 0.794 Std. Dev. (mm) 0.087 0.083 0.188 0.077 0.055 0.061 0.061 0.065 0.057 0.060 0.088 0.146 Std.Dev. (Sieve Equivalent) (phi) 3.706 0.569 1.123 0.492 0.433 0.452 0.457 0.466 0.440 0.431 0.521 0.821 Std.Dev. (Sieve Equivalent) (mm) 0.071 0.079 0.158 0.076 0.057 0.063 0.063 0.066 0.060 0.063 0.085 0.128 Mean of Framework Fract. (>30Nm) (phi) 1.669 2.120 2.090 1.947 2.172 2.111 2.115 2.082 2.137 2.023 1.865 1.944 Mean of Framework Fract. (>30pm) (mm) 0.314 0.230 0.235 0.259 0.222 0.232 0.231 0.236 0.227 0.246 0.275 0.260 Std. Dev. of Framework Fract. (>30Nm) (phi) 0.553 0.506 0.473 0.419 0.351 0.373 0.379 0.389 0.360 0.349 0.451 0.521 Std. Dev. of Framework Fract. (>30Nm) (mm) 0.123 0.082 0.078 0.076 0.055 0.061 0.061 0.064 0.057 0.060 0.087 0.096 Minimum Size Value (phi) 11.396 3.523 11.396 3.060 3.277 2.971 2.942 3.001 2.999 2.830 2.776 10.396 Minimum Size Value (mm) 0.0004 0.0870 0.0004 0.1199 0.1032 0.1275 0.1301 0.1249 0.1251 0.1406 0.1460 0.0007 Maxiumum Size Value (phi) 0.264 0.267 0.644 0.367 1.014 0.779 0.683 0.866 1.053 0.272 -0.234 -0.848 Maxiumum Size Value (mm) 0.833 0.831 0.640 0.776 0.495 0.583 0.623 0.549 0.482 0.828 1.176 1.800 Depth (ft) 6633.0 6634.0 6635.0 6637.0 6639.0 6640.0 6641.0 6642.0 6672.0 6675.0 6693.0 6694.0 Mean (phi) 2.012 1.887 6.971 5.383 4.966 5.580 5.820 6.426 8.542 9.031 6.315 7.262 Mean (mm) 0.248 0.270 0.008 0.024 0.032 0.021 0.018 0.012 0.003 0.002 0.013 0.007 Mean (Sieve Equivalent) (phi) 2.256 2.139 6.888 5.405 5.015 5.589 5.813 6.379 8.356 8.813 6.276 7.160 Mean (Sieve Equivalent) (mm) 0.209 0.227 0.008 0.024 0.031 0.021 0.018 0.012 0.003 0.002 0.013 0.007 Std. Dev. (phi) 0.462 1.242 4.106 3.434 3.250 3.300 3.540 3.884 3.524 3.826 3.824 3.511 .Std. Dev. (mm) 0.081 0.263 0.068 0.128 0.151 0.102 0.102 0.085 0.015 0.013 0.088 0.037 Std.Dev. (Sieve Equivalent) (phi) 0.529 1.216 3.737 3.145 2.984 3.027 3.239 3.542 3.225 3.491 3.489 3.213 Std.Dev. (Sieve Equivalent) (mm) 0.079 0.215 0.056 0.103 0.120 0.083 0.083 0.069 0.014 0.012 0.072 0.032 Mean of Framework Fract. (>30Nm) (phi) 2.012 1.801 2.945 3.214 3.313 3.708 3.574 3.377 3.823 3.435 3.448 4.347 Mean of Framework Fract. (>30pm) (mm) 0.248 0.287 0.130 0.108 0.101 0.077 0.084 0.096 0.071 0.092 0.092 0.049 Std. Dev. of Framework Fract. (>30Nm) (phi) 0.461 0.899 0.469 0.373 0.287 0.374 0.362 0.324 0.339 0.429 0.329 0.362 Std. Dev. of Framework Fract. (>30Nm) (mm) 0.081 0.191 0.043 0.028 0.020 0.020 0.021 0.022 0.017 0.028 0.021 0.012 Minimum Size Value (phi) 2.904 10.396 12.397 12.397 12.397 12.397 12.397 12.397 12.397 12.397 12.397 12.397 Minimum Size Value (mm) 0.1336 0.0007 0.0002 0.0002 0.0002 0.0002 0.0002 0.0002 0.0002 0.0002 0.0002 0.0002 Maxiumum Size Value (phi) -0.094 -3.392 1.444 1.843 2.652 2.724 2.550 2.672 3.052 2.361 2.494 3.138 Maxiumum Size Value (mm) 1.067 10.500 0.368 0.279 0.159 0.151 0.171 0.157 0.121 0.195 0.177 0.114 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: ConocoPhillips Alaska Antigua #1 KRU Age/Strat. Unit Designation: Kuparuk C Depth/Sample I.D.: 6624.0 Mean size = 0.259mm (1.95 Phi) Sorting = .419 Phi Porosity = 12.2 Permeability (md) _ .003 Total Counts = 300 Lithology: Medium-grained well sorted pellet-rich quartzose sandstone cemented by siderite Special Comment: Size and sorting values are measured values and apply to framework fraction only. Porosit Filename: 66240 .PCT Date: 08-14-2006 Formula Filename.ext: LCRETFRM.WK1 COMPONENT FRAMEWORK COMPONENT Monocrystalline Quartz Quartz Coated by siderite Potassium Feldspar Glauconite Clay/Mud Peloid (non-glauconitic) Coated Glauconite Pellet Sideritic Mud/Silt/Mudst/Sltst. Fragment PORES PORE-FILLERS Rhomb siderite (coarsely xline >.06mm) Rhomb siderite (finely xline <.06mm) Radially-extincting siderite Dead Oil Ferroan Calcite REPLACEMENT COMPONENTS Mud/clay Peloid/Glau. repl. by siderite Nan-glauconitic Peloid replaced by Ankeri FRACTURES/SHALE LAMINAE/BURROWS OVERSIZE GRAINS (>10 TIMES AV. GR. SIZE) SUMMARY CALCULATIONS DESCRIPTIONS COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cnts) (X fraction) 10 3.3 6.2 3.3 5.3 30 10.0 18.6 10.0 15.9 1 0.3 0.6 0.3 0.5 5 1.7 3.1 1.7 2.6 108 36.0 67.1 45.3 72.0 5 1.7 3.1 1.7 2.6 2 0.7 1.2 0.7 1.1 6 2.0 5.4 2.0 5.4 71 23.7 64.0 23.7 64.0 31 10.3 27.9 10.3 27.9 2 0.7 1.8 0.7 1.8 1 0.3 0.9 0.3 0.9 27 9.0 96.4 0.0 0.0 1 0.3 3.6 0.0 0.0 Total Framework Grains (% Total Rock) Total framework - Unknowns (XTota7 Rock) Q - quartzose Components (XFrmwork - Unknown) F - Feldspathic.Components (XFrmwrk - Unknwn) L - Lithic Components (X Framework Unknwn) Total framework-Unkn.(Dickinson-TotQtFL Cts) Qt - Quartzose Comp. (Dickinson)(%Total QtFL) F - Feldspathic.Comp.(Dickinson)(XTotal QtFL) L - Lithic Compon. (Dickinson)(XTotal QtFL) Tat. Framework-Unkn.(Dickinson-TotQmFLt Cts) Qm - Monocryst.Qtz. (Dickinson)(XTotal QmFLt) F - Feldspath. Comp.(Dickinson)(XTotal QmFLt) Lt - Lithic Comp. (Dickinson) (XTotal QmFLt) Total Quartz (X Framework) Total Monocrystalline quartz (X Framework) Total Polycrystalline quartz (% Framework) Total Chert (X Framework) Total Sandstone/Siltstone/Qtzite (X Frmwrk) C/Q Ratio Total Feldspar (% Framework) Total Plagioclase (X Framework Total Potassium.Feldspar (X Framework) P/F Ratio Total Ductile (X Framework) Total Clay Peloids (X Framework) Total Nonoxidized Glauconite (X Framework) Total Oxidized Glauconite (X Framework) Total Glauconite (incl. oxidized)(XFramework) Total Nonglauconitic peloids (X Framework) Total Phyllite (X Framework) Total Organic Fragments (X Framework) Total Muscovite and Chlorite (X Framework) Total Chamosite&Iron-rich ooids {XFramework) Total DetritalCarbonate Frags. (X Framework) Total Fossil Fragments (X Framework) Total Calcite and Limest. Frags.(% Framework) Total Dolomite Fragments (X Framework} Total siderite Fragments (X Framework) Total Siliceous Fossil Fragments(X Frmwork) COUNTS PRESENT RECONSTRUCTED (#) COMPOSITION COMPOSITION 161.00 53.67 63.00 161.00 53.67 63.00 40.00 24.84 21.16 1.00 0.62 0.53 120.00 74.53 78.31 41.00 13.67 13.67 40.00 97.56 97.56 1.00 2.44 2.44 0.00 0.00 0.00 41.00 13.67 13.67 40.00 97.56 97.56 1.00 2.44 2.44 0.00 0.00 0.00 40.00 24.84 21.16 40.00 24.84 21.16 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.00 0.62 0.53 0.00 0.00 0.00 1.00 0.62 0.53 0.00 0.00 0-00 118.00 73.29 77.25 118.00 73.29 77.25 10.00 6.21 5.29 0.00 0.00 0.00 10-00 6.21 5.29 108.00 67.08 71.96 o.oo o.oa o.oo 0.00 0.00 0.00 0.00 0.00 0.00 o.oo o.oo o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.00 1.24 1.06 0.00 0.00 0.00 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Nell/Outcrop I.D.: ConocoPhillips Alaska Antigua #1 KRU Age/Stmt. Unit Designation: Kuparuk C Depth/Sample I.D.: 6624.0 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Tot.Rock (Tot.Cts minus Artif.Pores&Plucked) 300.00 100.00 100.00 Tot.Disprs.Mtx+Clay Lam.&Burrows (X Total Rk) 0.00 0.00 0.00 Total Clay Laminae & Burrows (X Total Rk.) 0.00 0.00 0.00 Total Dispersed Matrix (XTotal Rock) 0.00 0.00 0.00 Total Carbonate Cements (X Total Rock) 109.00 36.33 36.33 Total Siderite Cements (X Total Rock) 108.00 36.00 36.00 Total AnkeriteCement (X Total Rock) 0.00 0.00 0.00 Total Kaolinite (X Tot.Rock) 0.00 0.00 0.00 Total Chlorite (X Tot.Rock) 0.00 0.00 0.00 Total Authigenic Clays (X Tot.Rock) 0.00 0.00 0.00 Total Detrital Clay Rims (X Tot. Rock) 0.00 0.00 0.00 Total Oil Stain (X Tot. Rock) 2.00 0.67 0.67 Total Quartz Overgrowths (X Tot. Rock) 0.00 0.00 0.00 Total Chert & Microxl. Quartz (X Tot. Rock) 0.00 0.00 0.00 Total Pyrite/Marcasite (X Tot.Rock) 0.00 0.00 0.00 Total Other Cements (X Tot. Rock) 0.00 0.00 0.00 Tot. Dissolved Carbonate Cement (X Tot. Rock) 0.00 0.00 0.00 Total Carb.Cem.+Mtx.+Other Cem.(Total Counts) 109.00 36.33 36.33 C - Carbonate Cem.(X Carb.Cem+Mtx.+Other Cem) 109.00 100.00 100.00 M - Matrix (X Carb.Cem+Mtx+Other Cements) 0.00 0.00 0.00 0 - Other Cem.(X Carb.Cem.+Mtx.+Other Cem.) 0.00 0.00 0.00 Total Counts (Tot.counts - artificial pores) 300.00 100.00 100.00 Total Fracture Fill (X Total Counts) 0.00 0.00 0.00 Total Oversize Grains (X Tot. Counts) 0.00 0.00 0.00 Total Plucked Grains (X TotalCounts) 0.00 0.00 0.00 Total Visible Porosity (X Total Rock) 0.00 0.00 0.00 Tot. Calc. Intergran. Porosity(X Total Rock) 0.00 0.00 0.00 Tot. Calc. Intragran. Porosity(X Total Rock) 35.25 11.75 14.55 Tot. Shrinkage Porosity (X Total Rock) 0.00 0.00 0.00 Total Calc. Porosity(incl.lam.mtx)(X Tot. Rk) 35.25 11.75 14.55 Total Calculated Microporosity(X Total Rock) 35.25 11.75 14.55 Calculated Secondary Porosity (X Total Rock) 0.00 0.00 0.00 Tot.Intergranular Cements incl.Clays(XTot.Rk) 109.00 36.33 36.33 Total Solid Components (Total Counts) 263.60 0.00 0.00 Calculated Grain Density 841.06 3.19 3.08 Tot. Framework+Intergranular Compon.(Tot.Cts) 300.00 0.00 0.00 Total Intergranular Volume {XFrame+Intergrn) 111.00 37.00 37.00 Compaction Loss(X Framework+Intergran. Comp.) 1.44 Bulk Volume Corrected Compaction Loss 2.29 Calculated Initial Porosity 38.44 **~-x***:tx:r***~~-x*:t~~~*~x~-x:t~*:~-,tom*~x:~* COMMENTS :r+~,t~ *~**,t-k~x~xrr*~x:~~x~r,fx,r** The thin section was prepared from a 1 inch diameter plug and is stained for potassium feldspar and dual carbo Hates. It is difficult to differentiate Siderite that replaces clay pellets and Siderite that laps over the edges of clay pellets and does not replace the pellet... Many glauconitic and non-glauconitic clay pellets are extensively stained by unextracted heavy oil. The carbonate counted as ferroan calcite has a pale to dark blue stain and appears to have a radial fibrous st ructure. The coated glauconite pellets have phosphatic coats. POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: ConocoPhillips Alaska Antigua #1 KRU AgelStrat. Unit Designation: Kuparuk C Depth/Sample I.D.: 6626.0 Mean size = 0.232mm (2.11 Phi) Sorting = .373 Phi Porosity s 18.2 Permeability (md) _ .247 Total Counts = 300 Lithology: Fine-grained well sorted glauconite-rich sandstone cemented by siderite Special Comment: Size and sorting values are measured values and apply to framework fraction only. Porosit Filename: 66260 .PCT Date: 08.14-2006 Formula Filename.ext: LCRETFRM.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cnts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 36 12.0 26.1 12.0 25.2 Quartz Coated by siderite 16 5.3 11.6 5.3 11.2 Glauconite 52 17.3 37.7 17.3 36.4 Clay/Mud Peloid (non-glauconitic) 13 4.3 9.4 6.0 12.6 Coated Glauconite Pellet 10 3.3 7.2 3.3 7.0 Sideritic Mud/Silt/Mudst/Sltst. Fragment 11 3.7 8.0 3.7 7.7 PORES PORE-FILLERS Rhomb siderite (coarsely xline >.06mm} 18 6.0 11.6 6.0 11.6 Rhomb siderite (finely xline <.06mm) 124 41.3 80.0 41.3 80.0 Radially-extincting siderite 13 4.3 8.4 4.3 8.4 REPLACEMENT COMPONENTS Dissolution Pore in siderite Cement 2 0.7 28.6 0.7 100.0 Mud/clay Peloid/Glau. repl. by siderite 5 1.7 71.4 0.0 0.0 FRACTURES/SHALE LAMINAE/BURROWS OVERSIZE GRAINS (>10 TIMES AV. GR. SIZE) SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total Framework Grains (X Total Rock) 138.00 46.00 47.67 Total Framework - Unknowns (XTotal Rock) 138.00 46.00 47.67 Q - Quartzose Components (XFrmwork Unknown) 52.00 37.68 36.36 F - Feldspathic.Components (XFrmwrk - Unknwn) 0.00 0.00 0.00 L - Lithic Components (X Framework Unknwn) 86.00 62.32 63.64 Total Framework•Unkn.(Dickinson-TotQtFL Cts} 52.00 17.33 17.33 Qt - Quartzose Comp. (Dickinson)(XTotal QtFL) 52.00 100.00 100.00 F - Feldspathic.Comp.(Dickinson)(XTotal QtFL) 0.00 0.00 0.00 L Lithic Gompon. (Dickinson)(XTotal QtFL) 0.00 0.00 0.00 Tot. Framework-Unkn.tDickinson-TotQmFLt Cts) 52.00 17.33 17.33 Qm - Monocryst.Qtz. (Dickinson)(XTotal QmFLt) 52.00 100.00 100.00 F - Feldspath. Comp.(Dickinson)(XTotal QmFLt) 0.00 0.00 0.00 Lt - Lithic Comp. (Dickinson) (XTotal QmFLt) 0.00 0.00 0.00 Total Quartz (X Framework) 52.00 37.68 36.36 Total Monocrystalline quartz (X Framework) 52.00 37.68 36.36 Total Polycrystalline quartz (X Framework) 0.00 0.00 0.00 Total Chert (X Framework) 0.00 0.00 0.00 Total Sandstone/Siltstone/Qtzite (X Frmwrk) 0.00 0.00 0.00 C/Q Ratio 0.00 0.00 0.00 Total Feldspar (X framework) 0.00 0.00 0.00 Total Plagioclase (X Framework 0.00 0.00 0.00 Total Potassium.Feldspar (X Framework) 0.00 0.00 0.00 P/F Ratio 0.00 0.00 0.00 Total Ductile (X Framework) 75.00 54.35 55.94 Total Clay Peloids (X Framework) 75.00 54.35 55.94 Total Nonoxidized Glauconite (X Framework) 62.00 44.93 43.36 Total Oxidized Glauconite (X Framework) 0.00 0.00 0.00 Total Glauconite (incl. oxidized)(XFramework) 62.00 44.93 43.36 Total Nonglauconitic peloids (X Framework) 13.00 9.42 12.59 Total Phyllite (X Framework) 0.00 0.00 0.00 Total Organic Fragments (X framework) 0.00 0.00 0.00 Total Muscovite and Chlorite (X Framework) 0.00 0.00 0.00 Total Chamosite&Iron-rich ooids (XFramework) 0.00 0.00 0.00 Total DetritalCarbonate Frags. (X Framework} 0.00 0.00 0.00 Total Fossil Fragments (X Framework) 0.00 0.00 0.00 Total Calcite and Limest. Frags.(X Framework) 0.00 0.00 0.00 Total Dolomite Fragments (X Framework) 0.00 0.00 0.00 Total siderite Fragments (X Framework} 11.00 7.97 7.69 Total Siliceous Fossil Fragments(X Frmwork) 0.00 0.00 0.00 Tot.Rock (Tot.Cts minus Artif.Pores&Plucked) 300.00 100.00 100.00 Tot.Disprs.Mtx+Clay Lam.&Burrows (X Total Rk) 0.00 0.00 0.00 Total Clay Laminae & Burrows (X Total Rk.) 0.00 0.00 0.00 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: ConocoPhillips Alaska Antigua #1 KRU Age/Strat. Unit Designation: Kuparuk C Depth/Sample I.D.: 6626.0 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total Dispersed Matrix (XTotal Rock) 0.00 0.00 0.00 Total Carbonate Cements (X Total Rock) 155.00 51.67 51.67 Total Siderite Cements (X Total Rock) 155.00 51.67 51.67 Total AnkeriteCement (X Totai Rock) 0.00 0.00 0.00 Total Kaolinite (X Tot.Rock) 0.00 0.00 0.00 Total Chlorite (X Tot.Rock) 0.00 0.00 0.00 Total Authigenic Clays (X Tot.Rock) 0.00 0.00 0.00 Total Detrital Clay Rims (X Tot. Rock) 0.00 0.00 0.00 Total Oil Stain (X Tot. Rock) 0.00 0.00 0.00 Total Quartz Overgrowths (X Tot. Rock) 0.00 0.00 0.00 Total Chert & Microxl. Quartz (X Tot. Rock) 0.00 0.00 0.00 Total Pyrite/Marcasite (X Tot.Rock) 0.00 0.00 0.00 Total Other Cements (X Tot. Rock) 0.00 0.00 0.00 Tot. Dissolved Carbonate Cement (% Tot. Rock) 2.00 0.67 0.67 Total Carb.Cem.+Mtx.+Other Cem.(Total Counts) 155.00 51.67 51.67 C - Carbonate Cem.(X Carb.Cem+Mtx.+Other Cem) 155.00 100.00 100.00 M - Matrix (X Carb.Cem+Mtx+Other Cements) 0.00 0.00 0.00 0 - Other Cem.(X Carb.Cem.+Mtx.+Other Cem J 0.00 0.00 0.00 Total Counts (Tot.counts - artificial pores) 300.00 100.00 100.00 Total Fracture Fill (X Total Counts) 0.00 0.00 0.00 Total Oversize Grains (X Tot. Counts) 0.00 0.00 0.00 Total Plucked Grains (X TotalCounts) 0.00 0.00 0.00 Total Visible Porosity (X Total Rock) 2.00 0.67 0.67 Tot. Calc. Intergran. Porosity(X Total Rock) 2.00 0.67 0.67 Tot. Calc. Intragran. Porosity(X Total Rock) 22.20 7.40 7.90 Tot. Shrinkage Porosity (X Total Rock) 0.00 0.00 0.00 Total Calc. Porosity(incl.lam.mtx)(X Tot. Rk) 24.20 8.07 8.57 Total Calculated Microporosity(X Total Rock) 22.20 7.40 7.90 Calculated Secondary Porosity (X Total Rock) 2.00 0.67 0.67 Tot.Intergranular Cements incl.Clays(%Tot.Rk) 155.00 51.67 51.67 Total Solid Components (Total Counts) 275.50 0.00 0.00 Calculated Grain Density 895.28 3.25 3.23 Tot. Framework+Intergranular Compon.(Tot.Cts) 300.00 0.00 0.00 Total Intergranular Volume (XFrame+Intergrn) 157.00 52.33 52.33 Compaction Loss(X Framework+Intergran. Comp.) •13.62 Bulk Volume Corrected Compaction Loss •28.58 Calculated Initial Porosity 38.71 ~*~~x~,~tr~:~x*,t*~rx*~,t COMMENTS **~x~t**:t~*:r~-t****~****,t-k-k~x:~x**:~x~x*~:,~x The thin section was prepared from a 1 inch diameter plug and is stained for potassium feldspar and dual carbo Hates. The cores of some non-glauconitic clay pellets are plucked. It is difficult to differentiate Siderite that replaces clay pellets and Siderite that laps over the edges of clay pellets and does not replace the pellet. The coated glauconite pellets are coated by phosphatic rims or sideritic rims. A few of the counts recorded as Siderite replacing non-glauconitic pellets may be replacing partially glauconi tized pellets. POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: ConocoPhillips Alaska Antigua #1 KRU Age/Strat. Unit Designation: Kuparuk C Depth/Sample I.D.: 6630.0 Mean size = 0.246mm (2.02 Phi) Sorting = .349 Phi Porosity = 34.2 Permeability (md) = 4240 Total Counts = 300 Lithology: Fine-grained very well sorted glauconite-rich quartzose sandstone cemented by siderite Special Comment: Size and sorting values are measured values and apply to framework fraction only. Porosit filename: 66300 .PCT Date: OS-14-2006 Formula Filename:ext: LCRETFRM.WK1 COMPONENT FRAMEWORK COMPONENT Monocrystalline Quartz Nondescript Polycryst.Qtz (2-5 subunits) Potassium feldspar Glauconite Clay/Mud Peloid (non-glauconitic) Sideritic Mud/Silt/Mudst/Sltst. Fragment Unknown Framework Grain PORES Rim Moldic and Shrinkage Pores PORE-FILLERS Rhomb siderite (coarsely xline >.06mm) Rhomb siderite (finely xline <.06mm) Radially-extincting siderite Pyrite/Marcasite REPLACEMENT COMPONENTS Dissolution Pore in Plagioclase Intraparticle Pore in Unknown Dissolution Pore in siderite Cement Mud/clay Peloid/Glau. repl. by siderite Glauconite replaced by Kaolinite FRACTURES/SHALE LAMINAE/BURROWS Ankerite Fracture Fill OVERSIZE GRAINS (>10 TIMES AV. GR. SIZE) SUMMARY CALCULATIONS DESCRIPTIONS COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cnts) (X fraction) 68 22.7 47.6 22.7 44.4 2 0.7 1.4 0.7 1.3 2 0.7 1.4 0.7 1.3 66 22.0 46.2 22.7 44.4 0 0.0 0.0 2.0 3.9 5 1.7 3.5 1.7 3.3 0 0.0 0.0 0.7 1.3 9 3.0 100.0 3.0 100.0 23 7.7 18.4 7.7 18.4 67 22.3 53.6 22.3 53.6 34 11.3 27.2 11.3 27.2 1 0.3 0.8 0.3 0.8 1 0.3 4.5 0.3 8.3 2 0.7 9.1 0.0 0.0 11 3.7 50.0 3.7 91.7 6 2.0 27.3 0.0 0.0 2 0.7 9.1 0.0 0.0 1 0.3 100.0 0.3 100.0 Total Framework Grains (X Total Rock) Total Framework - Unknowns (XTotal Rock) Q - Quartzose Components (XFrmwork - Unknown) F - Feldspathic.Components (XFrmwrk - Unknwn) L - Lithic Components (X Framework - Unknwn) Total Framework•Unkn.(Dickinson-TotQtFL Cts) Qt - Quartzose Comp. (Dickinson)(XTotal QtFL) F - Feldspathic.Comp.(Dickinson)(XTotal QtFL) L - Lithic Compon. (Dickinson)(XTotal QtFL) Tot. Framework-Unkn.(Dickinson•TotQmFLt Cts) Qm - Monocryst.Qtz. (Dickinson)(XTotal QIIIFLt) F - Feldspath. Comp.(Dickinson)(XTotal QmFLt) Lt - Lithic Comp. (Dickinson) (XTotal QmFLt) Total Quartz (X Framework) Total Monocrystalline quartz (X Framework) Total Polycrystalline quartz (X Framework) Total Chert (X Framework) Total Sandstone/Siltstone/Qtzite (X Frmwrk) C/Q Ratio Total Feldspar (X Framework) Total Plagioclase (X Framework Total Potassium.Feldspar (X Framework) P/F Ratio Total Ductile (X Framework) Total Clay Peloids (X Framework) Total Nonoxidized Glauconite (X Framework) Total Oxidized Glauconite (X Framework) Total Glauconite (incl. oxidized)(XFramework) Total Nonglauconitic peloids (X Framework) Total Phyllite (X Framework) Total Organic Fragments (X Framework) Total Muscovite and Chlorite (X Framework) Total Chamosite&Iron-rich ooids (%Framework) Total DetritalCarbonate Frags. (% Framework) Total Fossil Fragments (X Framework) COUNTS PRESENT RECONSTRUCTED (#) COMPOSITION COMPOSITION 143.00 143.00 70.00 2.00 71.00 72.00 70.00 2.00 0.00 72.00 68.00 2.00 2.00 70.00 68.00 2.00 0.00 0.00 2.00 2.00 0.00 2.00 0.00 66.00 b6.00 66.00 0.00 66.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 --47.67--•- 47.67 48.95 1.40 49.65 24.00 97.22 2.78 0.00 24.00 94.44 2.78 2.7s 48.95 47.55 1.40 0.00 0.00 0.03 1.40 0.00 1.40 0.00 46.15 46.15 46.15 0.00 46.15 0.00 0.00 0.00 0.00 0.00 0.00 0.00 51.00 50.33 46.36 1.32 52.32 24.00 97.22 2.78 0.00 24.00 94.44 2.78 2.78 45.75 44.44 1.31 0.00 0.00 0.03 1.31 0.00 1.31 0.00 48.37 48.37 44.44 0.00 44.44 3.92 0.00 0.00 0.00 0.00 0.00 0.00 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska WelllOutcrop I.D.: ConocoPhillips Alaska Antigua #i KRU AgelStrat. Unit Designation: Kuparuk C Depth/Sample I.D.: 6630.0 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total Calcite and Limest. Frags.(X Framework) 0.00 0.00 0.00 Total Dolomite Fragments (X Framework) 0.00 0.00 0.00 Total Siderite Fragments (X Framework) 5.00 3.50 3.27 Total Siliceous Fossil Fragments(X Frmwork) 0.00 0.00 0.00 Tot.Rock (Tot.Cts minus Artif.Pores&Plucked) 300.00 100.00 100.00 Tot.Disprs.Mtx+Clay Lam.&Burrows (X Total Rk) 0.00 0.00 0.00 Total Clay Laminae & Burrows (X Total Rk.) 0.00 0.00 0.00 Total Dispersed Matrix (XTotal Rock) 0.00 0.00 0.00 Total Carbonate Cements (X Total Rock) 124.00 41.33 41.33 Total Siderite Cements (X Total Rock) 124.00 41.33 41.33 Total AnkeriteCement (X Total Rock) 0.00 0.00 0.00 Total Kaolinite (X Tot.Rock) 0.00 0.00 0.00 Total Chlorite (X Tot.Rock) 0.00 0.00 0.00 Total Authigenic Clays (X Tot.Rock) 0.00 0.00 0.00 Total Detrital Clay Rims (X Tot. Rock) 0.00 0.00 0.00 Total Oil Stain (% Tot. Rock) 0.00 0.00 0.00 Total Quartz Overgrowths (X Tot. Rock) 0.00 0.00 0.00 Total Chert & Microxl. Quartz (X Tot. Rock) 0.00 0.00 0.00 Total Pyrite/Marcasite (X Tot.Rock) 1.00 0.33 0.33 Total Other Cements (X Tot. Rock) 0.00 0.00 0.00 Tot. Dissolved Carbonate Cement (X Tot. Rock) 11.00 3.67 3.67 Total Carb.Cem.+Mtx.+Other Cem.(Total Counts) 125.00 41.67 41.67 C - Carbonate Cem.(% Carb.Cem+Mtx.+Other Cem) 124.00 99.20 99.20 M - Matrix (X Carb.Cem+Mtx+Other Cements) 0.00 0.00 0.00 0 - Other Cem.(X Carb.Cem.+Mtx.+Other Cem.) 1.00 0.80 0.80 Total Counts (Tot counts artificial pores) 300.00 100.00 100.00 Total Fracture Fill (X Total Counts) 1.00 0.33 0.33 Total Oversize Grains (X Tot. Counts) 0.00 0.00 0.00 Total Plucked Grains (X TotalCounts) 0.00 0.00 0.00 Total Visible Porosity (X Total Rock) 22.00 7.33 6.67 Tot. Calc. Intergran. Porosity(X Total Rock) 11.00 3.67 3.67 Tot. Calc. Intragran. Porosity(X Total Rock) 31.60 10.53 10.40 Tot. Shrinkage Porosity (X Total Rock) 9.00 3.00 3.00 Total Calc. Porosity(incl.lam.mtx)(X Tot. Rk) 42.60 14.20 14.07 Total Calculated Microporosity(X Total Rock) 19.80 6.60 7.40 Calculated Secondary Porosity (X Total Rock) 22.80 7.60 6.67 Tot.Intergranular Cements incl.Clays(XTot.Rk) 125.00 41.67 41.67 Total Solid Components (Total Counts) 257.40 0.00 0.00 Calculated Grain Density 807.33 3.14 3.11 Tot. Framework+Intergranular Compon.(Tot.Cts) 299.00 D.00 0.00 Total Intergranular Volume (XFrame+Intergrn) 137.00 45.82 45.82 Compaction Loss(X Framework+Intergran. Comp.) -6.95 Bulk Volume Corrected Compaction Loss -12.83 Calculated Initial Porosity 38.87 **********~*:t*,~-x~x**~,~***~** COMMENTS *~:r~x*~,r~rx*~xt~t~x,~-x:r**~:~x*~x***:~x*~* The thin section was prepared from a 1 inch diameter plug and is stained for potassium feldspar and dual carbo Hates. The counts recorded as Siderite replacing clay pellets are replacing glauconite pellets. It is difficult to differentiate Siderite that replaces clay pellets and Siderite that laps over the edges of clay pellets and does not replace the pellet. The count recorded as ankerite fracture fill is almost certainly ferroan calcite fracture fill. The ferroan calcite fracture fill is highly irregular. It juts around the borders of some grains and cuts acr oss others. POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: ConocoPhillips Alaska Antigua #1 KRU Age/Strat. Unit Designation: Kuparuk B Depth/Sample I.D.: 6635.0 Mean size = 0.130mm (2.94 Phi) Sorting = .469 Phi Porosity = 10.8 Permeability (md) _ .154 Total Counts = 300 Lithology: Laminated shale/mudstone/sandy mudstone/argillaceous siltstone/very fine- and fine-grained well sorted argillaceous quartzose sandstone. The Tatter two are cemented by suturing. Special Comment: Size and sorting values are measured values and apply to framework fraction only. Porosit Filename: 66350 .PCT Date: OS-14-2006 Formula Filename.ext: LCRETFRM.WK1 COMPONENT COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cnts) (X fraction) FRAMEWORK COMPONENT Monocrystalline Quartz 108 36.0 86.4 36.0 84.4 Dense Chert 3 1.0 2.4 1.0 2.3 Nondescript Polycryst.Qtz (2-5 subunits) 4 1.3 3.2 1.3 3.1 Potassium Feldspar 2 0.7 1.6 0.7 1.6 Glauconite 2 0.7 1.6 0.7 1.6 Organic fragment 4 1.3 3.2 1.3 3.1 Muscovite 2 0.7 1.6 0.7 1.6 Unknown Framework Grain 0 0.0 0.0 1.0 2.3 PORES PORE-FILLERS Clay and Mud Matrix 18 6.0 43.9 6.0 43.9 Kaolinite 8 2.7 19.5 2.7 19.5 Pyrite/Marcasite 15 5.0 36.6 5.0 36.6 REPLACEMENT COMPONENTS Unknown Framework Grain replaced by Kaoli 3 1.0 100.0 0.0 0.0 FRACTURES/SHALE LAMINAE/BURROWS Clay Laminae and Burrows 128 42.7 97.7 42.7 97.7 Sideritic Clay/Mud Lamina or Burrow Fill 3 1.0 2.3 1.0 2.3 OVERSIZE GRAINS (>10 TIMES AV. GR. SIZE) SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITI ON COMPOSITION Total Framework Grains (X Total Rock) 125.00 41.67 42.67 Total framework - Unknowns (XTotal Rock) 125.00 41.67 41.67 q - Quartzose Components (%Frmwork - Unknown) 115.00 92.00 92.00 F - Feldspathic.Components (XFrmwrk - Unknwn) 2.00 1.60 1.60 L - Lithic Components (X Framework - Unknwn) 8.00 6.40 6.40 Total Framework-Unkn.(Dickinson-TotQtFL Cts) 117.00 39.00 39.00 Qt - Quartzose Comp. (Dickinson)(XTotal Qt FL) 115.00 98.29 98.29 F - Feldspathic.Comp.(Dickinson)(%Total QtFL) 2.00 1.71 1.71 L - Lithic Compon. (Dickinson)(%Total QtFL) 0.00 0-00 0.00 Tot. Framework-Unkn.(Dickinson-TotQmFLt Cts) 117.00 39.00 39.00 Qm - Monocryst.Qtz. (Dickinson)(XTotal QmFLt) 108.00 92.31 92.31 F - Feldspath. Comp.(Dickinson)(XTotal QmFLt) 2.00 1.71 1.71 Lt - Lithic Comp. (Dickinson) (XTotal QmFLt) 7.00 5.98 5.98 Total Quartz (X Framework). 112.00 89.60 87.50 Total Monocrystalline quartz (X Framework) 108.00 86.40 84.38 Total Polycrystalline quartz (X Framework) 4.00 3.20 3.13 Total Chert (X Framework) 3.00 2.40 2.34 Total Sandstone/siltstone/Qtzite (X Frmwrk) 0.00 0.00 0.00 C!Q Ratio 7.00 0.06 0.06 Total Feldspar (X Framework) 2.00 1.60 1.56 Total Plagioclase (% framework 0.00 0.00 0.00 Total Potassium.Feldspar (X Framework) 2.00 1.60 1.56 P/F Ratio 0.00 0.00 0.00 Total Ductile (X Framework) 8.00 6.40 6.25 Total Clay Peloids (X Framework) 2.00 1.60 1.56 Total Nonoxidized Glauconite (X Framework) 2.00 1.60 1.56 Total Oxidized Glauconite (X Framework) 0.00 0.00 0.00 Total Glauconite (incl. oxidized)(XFramework) 2.00 1.60 1.56 Total Nonglauconitic peloids (X Framework) 0.00 0.00 0.00 Total Phyllite (X Framework) 0.00 0.00 0.00 Total Organic Fragments (X Framework) 4.00 3.20 3.13 Total Muscovite and Chlorite (X Framework) 2.00 1.60 1.56 Total Chamosite&Iron-rich ooids (XFramework) 0.00 0.00 0.00 Total DetritalCarbonate Frags. (X framework) 0.00 0.00 0.00 Total Fossil Fragments (% Framework) 0.00 0.00 0.00 Total Calcite and Limest. Frags.(X Framework) 0.00 0.00 0.00 Total Dolomite Fragments (% Framework) 0.00 0.00 0.00 Total Siderite Fragments (% Framework) 0.00 0.00 0.00 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.O.: ConocoPhillips Alaska Antigua #1 KRU Age/Strat. Unit Designation: Kuparuk B Depth/Sample I.D.: 6635.0 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total Siliceous Fossil Fragments(X Fretwork) 0.00 0.00 0.00 Tot.Rock (Tot.Cts minus Artif.Pores&Plucked) 300.00 100.00 100.00 Tot.Disprs.Mtx+Clay Lam.&Burrows (X Total Rk) 149.00 49.67 49.67 Total Clay Laminae & Burrows (% Total Rk.) 131.00 43.67 43.67 Total Dispersed Matrix (XTatal Rock) 18.00 6.00 6.00 Total Carbonate Cements (X Total Rock) 0.00 0.00 0.00 Total Siderite Cements (X Total Rock) 0.00 0.00 0.00 Total AnkeriteCement (X Total Rock) 0.00 0.00 0.00 Total Kaolinite (X Tot.Rock) 11.00 3.67 2.67 Total Chlorite (% Tot.Rock) 0.00 0.00 0.00 Total Authigenic Clays (% Tot. Rock) 11.00 3.67 2.67 Total Detrital Clay Rims (% Tot. Rock) 0.00 0.00 0.00 Total Oil Stain (X Tot. Rock) 0.00 0.00 0.00 Total Quartz Overgrowths (X Tot. Rock) 0.00 0.00 0.00 Total Chert & Microxl. Quartz (X Tot. Rock) 0.00 0.00 0.00 Total Pyrite/Marcasite (X Tot.Rock) 15.00 5.00 5.00 Total Other Cements (X Tot. Rock) 0.00 0.00 0.00 Tot. Dissolved Carbonate Cement (X Tot. Rock) 0.00 0.00 0.00 Total Carb.Cem.+Mtx.+Other Cem.(Total Counts) 41.00 13.67 13.67 C - Carbonate Cem.(X Carb.Cem+Mtx.+Other Cem) 0.00 0.00 0.00 M - Matrix (X Carb.Cem+Mtx+Other Cements) 18.00 43.90 43.90 0 Other Cem.(% Carb.Cem.+Mtx.+Other Cem.) 23.00 56.10 56.10 Total Counts (Tot counts - artificial pores) 300.00 100.00 100.00 Total Fracture Fill (X Total Counts) 0.00 0.00 0.00 Total Oversize Grains (% Tot. Counts) 0.00 0.00 0.00 Total Plucked Grains (X TotalCounts) 0.00 0.00 0.00 Total Visible Porosity (X Total Rock) 0.00 0.00 0.00 Tot. Calc. Intergran- Porosity(X Total Rock) 14.90 4.97 4.97 Tot. Calc. Intragran. Porosity(% Total Rock) 1.80 0.60 0.20 Tot. Shrinkage Porosity (% Total Rock) 0.00 0.00 0.00 Total Calc. Porosity(incl.lam.mtx)(X Tot. Rk) 101.40 33.80 33.40 Total Calculated Microporosity(X Total Rock) 98.20 32.73 32.33 Calculated Secondary Porosity (X Total Rock) 1.20 0.40 0.00 Tot.Intergranular Cements incl.Clays(XTot.Rk) 23.00 7.67 7.67 Total Solid Components (Total Counts) 198.60 0.00 0.00 Calculated Grain Density 553.64 2.79 2.79 Tot. Framework+Intergranular Compon.(Tot.Cts) 169.00 0.00 0.00 Total Intergranular Volume (XFrame+Intergrn) 41.00 24.26 24.26 Compaction Loss(% Framework+Intergran. Comp.) 13.79 Bulk Volume Corrected Compaction Loss 18.21 Calculated Initial Porosity 38.05 *~-x*~t***~x**~~x~-x*~-~t*~*,t**~*****:t-kt******~x COMMENTS ***~r**~x*~~xrit:t~x*~~r~*~:t*~xr**,tx*:t**,r*~:r~r~:r The thin section was prepared from a 1 inch diameter plug and is stained for potassium feldspar and dual carbo Hates. Plucked areas and artificial grain separation pores have been ignored in the count. The matrix generally contains significant amounts of fine organics and muscovite and pyrite. Disturbed bedding and burrowing are apparent. An arenaceous foram is present. Laminae range in thickness from 0.25 to 5mm. POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: ConocoPhillips Alaska Antigua #1 KRU Age/Strat. Unit Designation: Kuparuk B Depth/Sample I.D.: 6639.0 Mean size = O.lOlmm (3.31 Phi) Sorting = .287 Phi Porosity = 11.7 Permeability (md) _ .339 Total Counts = 300 Lithology: Laminated shale/mudstone/argillaceous siltstone and very well sorted very fine-grained sandston e. The latter two are cemented primarily by suturing. Special Comment: Size and sorting values are measured values and apply to framework fraction only. Porosit filename: 66390 .PCT Date: 08-14.2006 Formula Filename.ext: LCRETFRM.WK1 COMPONENT FRAMEWORK COMPONENT Monocrystalline Quartz Nondescript Polycryst.Qtz (>5 subunits) Dense Chert Nondescript Polycryst.Qtz (2.5 subunits) Plagioclase Potassium Feldspar Organic fragment Muscovite Opaque Heavy Minerals Basic Volcanic Fragment Unknown Framework Grain PORES Intergranular Pores PORE-FILLERS Clay and Mud Matrix Sideritic Matrix (sid.10-33X of matrix) Rhomb Siderite (finely xline <.06mm) Kaolinite Quartz Overgrowth Pyrite/Marcasite REPLACEMENT COMPONENTS Unknown Framework Grain replaced by Kaoli FRACTURES/SHALE LAMINAE/BURROWS Clay laminae and Burrows OVERSIZE GRAINS (>10 TIMES AV. GR. SIZE) SUMMARY CALCULATIONS DESCRIPTIONS COUNTS PRESENT PRESENT RECONSTRUCTED RECONSTRUCTED COMPOSITION COMPOSITION COMPOSITION COMPOSITION (#) (X total cnts) (X fraction) (X total cnts) (X fraction) 177 59.0 83.5 59.0 82.7 2 0.7 0.9 0.7 0.9 5 1.7 2.4 1.7 2.3 5 1.7 2.4 1.7 2.3 4 1.3 1.9 1.3 1.9 9 3.0 4.2 3.0 4.2 4 1.3 1.9 1.3 1.9 2 0.7 0.9 0.7 0.9 3 1.0 1.4 1.0 1.4 1 0.3 0.5 0.3 0.5 0 0.0 0.0 0.7 0.4 4 1.3 100.0 1.3 100.0 19 6.3 45.2 6.3 45.2 16 5.3 38.1 5.3 38.1 1 0.3 2.4 0.3 2.4 3 1.0 7.1 1.0 7.1 2 0.7 4.8 0.7 4.8 1 0.3 2.4 0.3 2.4 2 0.7 100.0 0.0 0.0 40 13.3 100.0 13.3 100.0 Total Framework Grains (X Total Rock) Total Framework - Unknowns (XTotal Rock) Q - Quartzose Components (XFrmwork - Unknown) F - Feldspathic.Components (XFrmwrk - Unknwn) L - Lithic Components (X Framework - Unknwn) Total Framework-Unkn.(Dickinson-TotQtFL Cts) Qt - Quartzose Comp. (Dickinson)(XTotal QtFL) F - Feldspathic.Comp.(Dickinson)(XTotal QtFL) L - Lithic Compon. (Dickinson)(XTotal QtFL) Tot. Framework-Unkn.(Dickinson-TotQmFLt Cts) Qm - Monocryst.Qtz. (Dickinson)(XTotal QmFLt) F - Feldspath. Comp.(Dickinson)(XTotal QmFLt) Lt - Lithic Comp. (Dickinson) (XTotal QmFLt) Total Quartz (X Framework) Total Monocrystalline quartz (X Framework) Total Polycrystalline quartz (X Framework) Total Chert (X Framework) Total Sandstone/siltstone/Qtzite (X Frmwrk) C/Q Ratio Total Feldspar (X Framework) Total Plagioclase (X Framework Total Potassium.Feldspar (X Framework) P/F Ratio Total Ductile (% Framework) Total Clay Peloids (X Framework) Total Nonoxidized Glauconite (X Framework) Total Oxidized Glauconite (X Framework} Total Glauconite (incl. oxidized)(XFramework) Total Nonglauconitic peloids (X Framework) Total Phyllite (X Framework) Total Organic Fragments (% Framework) Total Muscovite and Chlorite (X Framework) COUNTS PRESENT RECONSTRUCTED (#) COMPOSITION COMPOSITION 212.00 70.67 71.33 212.00 70.67 70.67 189.00 89.15 89.15 13.00 6.13 6.13 10.00 4.72 4.72 203.00 67.67 67.67 189.00 93.10 93.10 13.00 6.40 6.40 1.00 0.49 0.49 203.00 67.67 67.67 177.00 87.19 87.19 13.00 6.40 6.40 13.00 6.40 6.40 184.00 86.79 85.98 177.00 83.49 82.71 7.00 3.30 3.27 5.00 2.36 2.34 0.00 0.00 0.00 12.00 0.06 0.06 13.00 6.13 6.07 4.00 1.89 1.87 9.00 4.25 4.21 4.00 0.31 0.31 6.00 2.83 2.80 0.00 0.00 D.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4.00 1.89 1.87 2.00 0.94 0.93 POINT COUNT ANALYSIS Region I.D.: North Slope Alaska Well/Outcrop I.D.: ConocoPhillips Alaska Antigua #1 KRU Age/Strat. Unit Designation: Kuparuk B Depth/Sample I.D.: 6639.0 SUMMARY CALCULATIONS COUNTS PRESENT RECONSTRUCTED DESCRIPTIONS (#) COMPOSITION COMPOSITION Total Chamosite&Iron-rich ooids (XFramework) 0.00 0.00 0.00 Total DetritalCarbonate Frags. (X framework) 0.00 0.00 0.00 Total Fossil Fragments (X Framework) 0.00 0.00 0.00 Total Calcite and Limest. Frags.(X Framework) 0.00 0.00 0.00 Total Dolomite Fragments (X framework) 0.00 0.00 0.00 Total Siderite Fragments (X Framework) 0.00 0.00 0.00 Total Siliceous Fossil Fragments(X Fretwork) 0.00 0.00 0.00 Tot.Rock (Tot.Cts minus Artif.Pores&Plucked) 300.00 100.00 100.00 Tot.Disprs.Mtx+Clay Lam.&Burrows (X Total Rk) 75.00 25.00 25.00 Total Clay Laminae b Burrows (X Total Rk.) 40.00 13.33 13.33 Total Dispersed Matrix (XTotal Rock) 35.00 11.67 11.67 Total Carbonate Cements (X Total Rock) 1.00 0.33 0.33 Total Siderite Cements (X Total Rock) 1.00 0.33 0.33 Total AnkeriteCement (X Total Rock) 0.00 0.00 0.00 Total Kaolinite (X Tot.Rock) 5.00 1.67 1.00 Total Chlorite (X Tot.Rock) 0.00 0.00 0.00 Total Authigenic Clays (X Tot.Rock) 5.00 1.67 1.00 Total Detrital Clay Rims (X Tot. Rock) 0.00 0.00 0.00 Total Oil Stain (X Tot. Rock} 0.00 0.00 0.00 Total Quartz Overgrowths (X Tot. Rock) 2.00 0.67 0.67 Total Chert & Microxl. Quartz (X Tot. Rock) 0.00 0.00 0.00 Total Pyrite/Marcasite (k Tot.Rock) 1.00 0.33 0.33 Total Other Cements (X Tot. Rock) 0.00 0.00 0.00 Tot. Dissolved Carbonate Cement (X Tot. Rock) 0.00 0.00 0.00 Total Carb.Cem.+Mtx.+Other Cem.(Total Counts) 42.00 14.00 14.00 C - Carbonate Cem.(X Carb.Cem+Mtx.+Other Cem) 1.00 2.38 2.38 M - Matrix (% Carb.Cem+Mtx+Other Cements) 35.00 83.33 83.33 0 - Other Cem.(X Carb.Cem.+Mtx.+Other Cem.) 6.00 14.29 14.29 Total Counts (Tot counts artificial pores) 300.00 100.00 100.00 Total Fracture Fill (X Total Counts) 0.00 0.00 0.00 Total Oversize Grains (X Tot. Counts) 0.00 0.00 0.00 Total Plucked Grains (X TotalCounts) 0.00 0.00 0.00 Total Visible Porosity (X Total Rock) 4.00 1.33 1.33 Tot. Calc. Intergran. Porosity(X Total Rock) 25.55 8.52 8.52 Tot. Calc. Intragran. Porosity(% Total Rock) 0.80 0.27 0.00 Tot. Shrinkage Porosity (X Total Rock) 0.00 0.00 0.00 Total Calc. Porosity(incl.lam.mtx)(X Tot. Rk) 52.35 17.45 17.18 Total Calculated Microporosity(X Total Rock) 47.15 15.72 15.45 Calculated Secondary Porosity (X Total Rock) 0.80 0.27 0.00 Tot.Intergranular Cements incl.Clays(%Tot.Rk) 7.00 2.33 2.33 Total Solid Components (Total Counts) 247.65 0.00 0.00 Calculated Grain Density 665.44 2.69 2.69 Tot. Framework+Intergranular Compon.(Tot.Cts) 260.00 0.00 0.00 Total Intergranular Volume (XFrame+Intergrn) 46.00 17.69 17.69 Compaction Loss(X Framework+Intergran. Comp.) 21.47 Bulk Volume Corrected Compaction Loss 26.08 Calculated Initial Porosity 39.16 *~x :~-k:r~~x~t~x*~x:r:~xx,E:t** *** COMMENTS :t:t:~x*~t*:~:.-~x****:t:a*,t~*:rx:F~x,~~*,~x The thin section was prepared from a 1 inch diameter plug and is stained for potassium feldspar and dual carbo Hates. The matrix probably contains significant microporosity. The matrix commonly has large amounts of fine organics and muscovite. Ripple lamination is present. Laminae range in thickness from 0.25 to 6mm. Grading is present in a few sandstone and siltstone laminae. The opaques are altered opaque heavy minerals. The basic volcanic fragment is questionable. The very fine grain size results in extensive overlap of components and makes counting difficult. 111!°1 'a }~f •-ll~ Core Lab HESERVO[A OPTIMIZATIRN ltlI1N30LN0~ CONRSENTIAL ~~F~-~ q~'~t 2~ o/ j ROTARY SIDEWALL CORE ANALYSIS for ConocoPhillips Alaska Antigua-1 KRU Alaska Petroleum Sarvlces 6316 Windfern Houston, Texas 77040 USA TeI: 713-328-2565 Fax: 713-32&2567 www.corelab.com July 22, 2006 HOU-060338 Core Lab AESERVOIA RPiR11UilON ConocoPhillips -Alaska Antigua 1 KRU Alaska CL File No.: HOU-060338 Date: July 22, 2006 Rotary Sidewall Core Analysis ~ ~_ p ~ ~`+ ~_ Z ~ -I r This report is based entirely upon core samples, soils, solids, liduids, or gases, together with related observational data, provided solely by the client The conclusions, inferences, deductions and opinions rendered herein reflect the exarnination, study and testing of these items, and represent the bestjudgement of Core Laboratories. Any reliance on Che information contained herein concerning the profitability or productivity on any well, sand, or drilling activity is at the sole risk of the client, and Core Laboratories, neither extends nor makes any warranty or representation whatsoever with respect to same 'i'bis report has been prepared for die exclusive and confidential use of the client and no other party. PETROLEUM SERVICES 6316 WINDFERN HOUSTON, TEXAS 77040 (713) 328-2565 FAX (713) 328-2567 ConocoPhillips -Alaska Antigua 1 KRU Alaska Care fta~i ![T601[tlT 4[[YtC[[ CMS-300 ROTARY SIDEWALL ANALYSIS CL File No.: Hou-060338 Date: July 22, 2006 Analyst(s): AC-ML-LA-JH Sample Depth Net Confining Porosity Permeabilit Beta Alpha Grain Number stress Klinkenber Kair Density Footnote ft prig % mD mD ft -1 microns /cm3 1 6620.00 Ambient (3) 2 6621.00 Ambient 5.06 .0001 .002 NA NA 3.220 (5) 3 6622.00 2100 15.64 2.97 3.35 1.36E+11 1.29E+03 3.198 (1) 4 6623.00 Ambient 17.07 .217 .386 NA NA 3.192 (5) 58 6624.00 2100 12.17 .003 .006 1.50E+15 1.27E+04 3.281 (5) 5 6625.00 Ambient 10.43 .044 .106 NA NA 3.247 (5) 59 6626.00 Ambient 18.20 .247 .410 NA NA 3.254 (5) 6 6627.00 Ambient 16.58 .012 .039 NA NA 3.312 (5) 7 6628.00 2100 5.81 3.299 (4) 8 6629.00 2100 9.67 1.98 2.13 4.56E+11 2.89E+03 3.214 (1) 60 6630.00 Ambient 34.21 4240 4315 NA NA 3.109 (5) 9 6631.00 2100 28.18 19.0 20.7 5.65E+08 3.44E+01 2.945 (2) 10 6632.00 Ambient 13.86 .508 .803 NA NA 3.000 (5) 11 6633.00 Ambient 17.36 2.71 3.60 NA NA 3.010 (5) 12 6634.00 2100 28.75 41.9 45.6 3.00E+08 4.04E+01 2.771 (2) 61 6635.00 2100 10.79 .154 .217 2.20E+12 1.08E+03 2.693 13 6637.00 Ambient 13.19 .476 .759 NA NA 2.682 (5) 62 6639.00 2100 11.73 .339 .465 1.64E+~ 1 1.78E+02 2.642 14 6640.00 Ambient 18.40 .378 .620 NA NA 2.765 (5) 15 6641.00 2100 13.16 .514 .682 2.06E+11 3.32E+02 2.653 16 6642.00 2100 13.91 .257 .354 1.00E+11 8.05E+01 2.837 17 6660.50 Ambient 7.97 .012 .041 NA NA 2.496 (1),(5) 18 6672.00 2100 12.31 .179 .211 5.10E+09 2.83E+00 2.648 (1) 19 6675.00 Ambient 12.33 .049 .778 NA NA 2.716 (5) 20 6693.00 Ambient 14.38 1.31 1.85 NA NA 2.696 (5) 21 6694.00 2100 12.98 .021 .031 2.29E+12 1.44E+02 2.676 22 6697.50 Ambient 13.53 .349 .580 NA NA 2.618 (5) Footnotes: (1) Fractured sample. Permeability and/or porosity may be optimistic. (2) Short sample. Porosity may be optimistic due to poor conformance of confining sleeve. (3) Fragments only. Unsuitable for analysis. (4) Sample permeability below instrument limits at selected confining stress. (5) Unsuitable for measurement at stress. Ambient He porosity and probe permeability. ConocoPhillips -Alaska CL File No.: Hou-060338 Antigua 1 KRU Date: July 22, 2006 Alaska Analyst(s): AC-ML-LA-JH [a~-e l.~i rcr~zzron zzxnuz CMS-300 ROTARY SIDEWALL ANALYSIS -DEAN STARK FLUID SATURATIONS Sample Depth Net Confining Porosity Permeabili Saturation Grain Number stress Klinkenber Kair Oil Water Density Footnote ft prig % mD mD % Pore Volume /cm3 Descri tion 1 6620.00 Unsuitable for analysis (3) 2 6621.00 Ambient 5.06 .0001 .002 20.7 78.0 3.220 Sst bm of gr dns (5) 3 6622.00 2100 15.64 2.97 3.35 40.6 47.7 3.198 Sst bm of gr pyr (1) 4 6623.00 Ambient 17.07 .217 .386 21.0 48.3 3.192 Sst bm of gr pyr (5) 58 6624.00 2100 12.17 .003 .006 NA NA 3.281 Sst bm of gr pyr 5 6625.00 Ambient 10.43 .044 .106 8.8 85.6 3.247 Sst bm vfff gr pyr (5) 59 6626 Ambient 18.20 .247 .410 NA NA 3.254 Sst brn vfff gr pyr frac (1 ), (5) 6 6627.00 Ambient 16.58 .012 .039 5.2 78.8 3.312 Sst bm vfff gr pyr (5) 7 6628.00 2100 5.81 1.3 95.2 3.299 Sst bm of gr pyr (4) 8 6629.00 2100 9.67 1.98 2.13 6.0 76.6 3.214 Sst bm of gr pyr (1) 60 6630.00 Ambient 34.21 4240 4315 NA NA 3.109 Sst brn f gr pyr frac (1 ), (5) 9 6631.00 2100 28.18 19.0 20.7 17.7 43.6 2.945 Sst bm f/vf gr (2) 10 6632.00 Ambient 13.86 .508 .803 6.6 84.2 3.000 Sst bm of/f gr (5) 11 6633.00 Ambient 17.36 2.71 3.60 4.6 65.0 3.010 Sst bm of/f gr (5) 12 6634.00 2100 28.75 41.9 45.6 20.2 37.5 2.771 Sst bm of/f gr (2) 61 6635.00 2100 10.79 .154 .217 NA NA 2.693 Sst bm of gr sh strk frac (1) 13 6637.00 Ambient 13.19 .476 .759 8.5 78.8 2.682 Sst bm of gr sh strk (5) 62 6639.00 2100 11.73 .339 .465 NA NA 2.642 Sst bm of gr carb strk frac (1) 14 6640.00 Ambient 18.40 .378 .620 23.2 34.1 2.765 Sst bm of gr slty (5) 15 6641.00 2100 13.16 .514 .682 25.3 51.3 2.653 Sst bm of gr sh strk 16 6642.00 2100 13.91 .257 .354 4.6 63.7 2.837 Sst bm of gr sh strk 17 6660.50 Ambient 7.97 .012 .041 24.3 63.0 2.496 Sltst vshy org (1),(5) 18 6672.00 2100 12.31 .179 .211 5.3 87.3 2.648 Sst bm of gr slty shy lam (1) 19 6675.00 Ambient 12.33 .049 .778 18.0 77.9 2.716 Sst bm of gr slty shy lam (5) 20 6693.00 Ambient 14.38 1.31 1.85 33.6 27.8 2.696 Sst bm of gr slty shy lam (5) 21 6694.00 2100 12.98 .021 .031 3.8 73.9 2.676 Sst bm of gr slty shy lam org 22 6697.50 Ambient 13.53 .349 .580 24.2 54.1 2.618 Sst dk bm vslty shy (5) Footnotes: (1) Fractured sample. Permeability and/or porosity may be optimistic. (2) Short sample. Porosity may be optimistic due to poor conformance of confining sleeve. (3) Fragments only. Unsuitable for analysis. (4) Sample permeability below instrument limits at selected confining stress. (5) Unsuitable for measurement at stress. Ambient He porosi ty and probe permeability. Samples 58, 59, 60, 61 & 62 were unpreserved for several days. Saturations were not performed since these data were compromised. ConocoPhillips -Alaska CL File No.: Hou-060338 Antigua 1 KRU Date: July 22, 2006 Alaska ~ ~ Analyst(s): AC-ML-LA-JH rrsnaLrnre scnncxs APPENDIX A: EXPLANATION OF CMS-300 TERMS "b", "Beta, and "Alpha" Km = Equivalent non-reactive liquid permeability, corrected for gas slippage, mD Ka;, = Permeability to Air, calculated using K~ and b, mD b = Klinkenberg slip factor, psi R (Beta) = Forcheimer inertial resistance factor, ft-' a (Alpha) = A factor equal to the product of Beta and K„. This factor is employed in determining the pore level heterogeneity index, H. H; = logo (a0/RQI) a, microns = 3.238E-9 (3K,~ f71 = Porosity, fraction RQI = Reservoir Quality Index, microns RQI = 0.0314(K/a)o.s For further information please refer to: Jones, S.C.: "Two-Point Determination of Permeability and PV vs. Net Confining Stress" SPE Formation Evaluation (March 1988) 235-241. Jones S.C.: "A Rapid Accurate Unsteady-State Klinkenberg Permeameter," Soc. Pet. Eno. J. (Oct. 1972) 383-397. Jones, S.C.: "Using the Inertial Coefficient, R, To Characterize Heterogeneity in Reservoir Rock: SPE 16949 (September 1987). Amaefule, J.O.; Kersey, D.G.; Marschall, D.M.; Powell, J.D.; Valencia, L.E.; Keelan, D.K.: "Reservoir Description: A Practical Synergistic Engineering and Geological Approach Based on Analysis of Core Data,: SPE Technical Conference (Oct. 1988) SPE 18167. Core Lab RCSCRYOIR OPTIM IIATIYM File No.: HOU-060338 ConocoPhillips -Alaska Antigua 1 KRU Alaska Date: June 5, 2006 3 6622.00 2100 15.64 2.97 3.35 1.36E+11 1.29E+03 40.6 47.7 3.198 (1 )' Fractured sample. Permeability and/or porosity may be optimistic. VISIBLE LIGHT e" ~ Y ~ ~ ~ - ~ t G 4 x ~' -1 i ~~w ~ Jr v R,~I ~ ,, 5 -.. f i •~ j,. ~' ~~ ~ ~ f ~ 1 y ~ ` S 4 - ab ~ ;j ,~ z ~, ~ r `'~ ,; ~ d, ~< NI tl ~ 4 ~ ~; ~..y..'t ~ l . }Y. ~: y~ ' `ti. ~ r ~ r'. 3x ~.0 ~.o Sst brn of gr pyr (1) CMS-300 Rotary Sidewall Core Analysis ULTRAVIOLET LIGHT ConocoPhillips -Alaska Antigua 1 KRU Alaska Core Lab RCSCRY~IR 07TIHIZATIOR File No.: HOU-060338 CMS-300 Rotary Sidewall Core Analysis (5) Unsuitable for measurement at stress. Ambient He porosity and probe permeability. VISIBLE LIGHT 3x cm ,.o ~ J o.s i.o Date: June 5, 2006 4 6623.00 Ambient 17.07 .217 .386 NA NA 21.0 48.3 3.192 Sst brn of gr pyr (5) ULTRAVIOLET LIGHT Core Lab flC5CflY0lP OPTIMI2ATI~M ' File No.: HOU-060338 ConocoPhillips -Alaska Antigua 1 KRU Alaska Date: June 5, 2006 9 6631.00 2100 28.18 19.0 20.7 5.65E+08 3.44E+01 17.7 43.6 2.945 (2): Short sample. Porosity may be optimistic due to poor conformance of confining sleeve. 3x .o ~ o.s Sst brn f/vf gr (2) CMS-300 Rotary Sidewall Core Analysis ULTRAVIOLET LIGHT ConocoPhillips -Alaska Antigua 1 KRU Alaska Core Lab RESCRYOIR OPTIMI2AilON -- - - _ _ -- - ~ - -' - - --- - - -- File No.: HOU-060338 CMS-300 Rotary Sidewall Core Analysis (5), Unsuitable for measurement at stress. Ambient He porosity and probe permeability. VISIBLE LIGHT _~ r_~ ~r 4 , ~ ~ ~ .mow ••/ t x~ •.' s s ~ ~' ~ t ~ ni~ ~ f •~ ~^y f t ~ ~~r ~ ~{~ 3a cm 1.0 l- J 0.5 1.0 Date: June 5, 2006 10 6632.00 Ambient 13.86 .508 .803 NA NA 6.6 84.2 3.000 Sst brn vflf gr (5) ULTRAVIOLET LIGHT Core Lab AESCAYAIA OPTIXI2ATIOM File No.: HOU-060338 ConocoPhillips -Alaska Antigua 1 KRU Alaska CMS-300 Rotary Sidewall Core Analysis p ~ g Beta ~ AI ha Saturation Grain De th ~ Net Confinin Permeability ~ p Sample ~ Stress Porosity Klinkenberg Kair I, Oil Water Density i __ -- - No. ft j psig 1 °~ mD mD ~ ft(-1) microns % Pore Volume g/cm3 L 11 6633.00 Ambient 17.36 2.71 3.60 NA NA 4.6 65.0 3.010 (5): Unsuitable for measurement at stress. Ambient He porosity and probe permeability. VISIBLE LIGHT :~-~.r 3x cm T.o ~ Sst brn of/f gr Date: June 5, 2006 (5) ULTRAVIOLET LIGHT Core Lab RLSERYOIR OPi1RIIZAiIOM File No.: HOU-060338 ConocoPhillips -Alaska Antigua 1 KRU Alaska 12 6634.00 2100 28.75 41.9 45.6 3.00E+08 4.04E+01 20.2 37.5 2.771 (2): Short sample. Porosity may be optimistic due to poor conformance of confining sleeve. 3x i .o i.o Date. June 5, 2006 Sst brn vflf gr (2) CMS-300 Rotary Sidewall Core Analysis ULTRAVIOLET LIGHT Cotre Liao NESCNYUIP 02TIM IZhTION File No.: HOU-060338 ConocoPhillips -Alaska Antigua 1 KRU Alaska Date: June 5, 2006 CMS-300 Rotary Sidewall Core Analysis 13 6637.00 Ambient 13.19 .476 .759 NA NA 8.5 78.8 2.682 (5): Unsuitable for measurement at stress. Ambient He porosity and probe permeability. VISIBLE LIGHT 3x ~.o ~ T.o I Sst brn of gr sh strk ULTRAVIOLET LIGHT (5) ConocoPhillips -Alaska Antigua 1 KRU Alaska Core Lab IICSEAYOU OPTIMICATIOM File No.: HOU-060338 CMS-300 Rotary Sidewall Core Analysis 14 6640.00 Ambient 18.40 .378 .620 NA NA 23.2 34.1 2.765 (5): Unsuitable for measurement at stress. Ambient He porosity and probe permeability. VISIBLE LIGHT Date: June 5, 2006 3x cm z.o I i.o Sst brn of gr slty (5) ULTRAVIOLET LIGHT ConocoPhillips -Alaska Antigua 1 KRU Alaska Core Lab flCSCAYBIfl OPTIMIZATI011 -- File No.: HOU-060338 CMS-300 Rotary Sidewall Core Analysis VISIBLE LIGHT 3x n T.o ~ J 0.5 2.0 I Date: June 5, 2006 15 6641.00 2100 13.16 .514 .682 2.06E+11 3.32E+02 25.3 51.3 2.653 Sst brn of gr sh strk ULTRAVIOLET LIGHT Core Lab PCSCA.1'OIA 9PTI11:2AT!OM File No.: HOU-060338 ConocoPhillips -Alaska Antigua 1 KRU Alaska 16 6642.00 2100 13.91 .257 .354 1.00E+11 8.05E+01 4.6 63.7 2.837 VISIBLE LIGHT ~" ~ \.~ ~~~ ~'' 1~ - r ~e _, . .. •,, ; ~ F i . "_ r - R*' ~~ '. ~~'sr ~g M; y1 - ~.3 .. _ _~T+S _ ~ _'~t ~_ ,.'ib ~ - a.a. as t-,~~. _ ~ ~. ~... z, 3x i.o 1.0 ~ Sst brn of gr sh strk ULTRAVIOLET LIGHT Date: June 5, 2006 CMS-300 Rotary Sidewall Core Analysis Core Lab flCSCAYOIfl OPTIMI2NTI~N ConocoPhillips -Alaska Antigua 1 KRU Alaska File No.: HOU-060338 Date: June 5, 2006 -~ CMS-300 Rotary Sidewall Core Analysis Beta Alpha Saturation Grain ft(-1) microns Oil Water % Pore Volume Density glcm3 Description Footnote 19 6675.00 Ambient 12.33 .049 .778 NA NA 18.0 77.9 2.716 (5): Unsuitable for measurement at stress. Ambient He porosity and probe permeability. VISIBLE LIGHT 3x I i .o z.o i Sst brn of gr slty shy lam (5) ULTRAVIOLET LIGHT ConocoPhillips -Alaska Antigua 1 KRU Alaska Core Liao RCSCRYRIR RPTIMI2RTI~M File No.: HOU-060338 Date: June 5, 2006 CMS-300 Rotary Sidewall Core Analysis Depth NetConfining~ Permeability _' Beta Alpha Saturation Grain Sample ~ Stress II Porosity Klinkenberg' Kair Oil Water Density No. ~ ft ~ psig °k mD i mD _ft(-1) microns % Pore Volume g/cm3 20 6693.00 Ambient 14.38 1.31 1.85 NA NA 33.6 27.8 2.696 (5): Unsuitable for measurement at stress. Ambient He porosity and probe permeability. VISIBLE LIGHT ~ A..rs.... e =rax~.:.~ 3 ~~ ~'-.,r , ,q,~yc , . ,,,,,~ .. ~:' ~ ,~ ~ R _. ~ s ~~~x '~a, ~:- ,.,~.: _-.,~ 'w.. -.. 3x cm 1.0 Description Footnote Sst brn of gr slty shy lam (5) ULTRAVIOLET LIGHT ConocoPhillips -Alaska Antigua 1 KRU Alaska Core Lab RLSUYUIR OPPIMI2AT10M - - - - _ -- File No.: HOU-060338 CMS-300 Rotary Sidewall Core Analysis 21 6694.00 2100 12.98 .021 VISIBLE LIGHT 031 2.29E+12 1.44E+02 3.8 73.9 2.676 I ;. t_. Y I r . i _~ a~' f ~~, ;'r y{ f ~~. ~~. 3r cm 1.0 Sst brn of gr slty shy lam org Date: June 5, 2006 ULTRAVIOLET LIGHT