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Home My WebLink About202-027 Image 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. .Q O~ D n Well History File Identifier m,TALDATA V" Diskettes. No. D Other. Norrype ~~scan Needed OVERSIZED (Scannable) Organizing 1"rll1' \ R7'CAN \ P Color items: 0 Grayscale items: 0 Two-Siued I 0 Maps: D Other items scannable by large scanner 0 Poor Quality Originals: 0 Other: OVERSIZED (Non-Scannable) .£ Logs of various kinds NOTES: D Other 8(. BEVERL'r' ROBIN VINCENT SHER,(~)VIND'" DATE: Ie 1 ~ O~SI !11 P Project Proofing B'(. BEVERL'( ROBIN VINCENT SHERY~YVINDý , DATE"b ß ól' /s/ Scanning Preparation 6 x 30 = I »0 + d-- = TOTAL PAGES liY'~ I >]>.;}- 11/1 j BY, BEVERL y ROßIN VINCENT SHER'(~If-JD ( DA1Eb. Iff aLl' 151 Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ) ('¿ B--.. - / PAGE COUNT MATCHES NUMBER IN SCANNIN;PREPARATION: fL:::- YES NO BEVERL'! ROBIN VINCENT SIIER'«~IND! DA TE?) ,3/ Dl- 's/ Vl i V B", I, Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO B(: BEVERL y' ROBII~ VIIJCEHT SHER'(L MARIA, WIND ( DATE /Sl (SCPoP/P/III(: IS CO'1PLETE AT THIS POINT U~LESS SPECIAL AI IENlIor¡ IS REOUIREO orl A~II~IDIV1DUAL PAGE BASIS OUE TO ~UAl! rv. GRA (SCALE OR COLOR IMAGES) ReScanned 1/'1," III,"'" >; -/"/,'''..11,1111 ,';1',,/' '., ',1'1/.'::, ,"'wp/,",d! RESCANNED S't: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE. /51 General Noles or Comments auoullhls file. Quality Checked 1.1 '", I 12/1 Q/02l1ev3NO T Scanned wpd • Lo 2 o Z"7 P "ILS 6 PHIL IPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Pos t Office Box 100360 Anchorage, Alaska 99510 -0360 'I C *�T1 F f+l December 6, 2001 NOI`I -GQ 4 Daniel J. Seamount, Jr., Commissioner DEC Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 NON-CONFIDENTIAL Anchorage, AK 99501 DEC 2 2010 Re: NPRA Pore Pressure Prediction Dear Commissioner Seamount, Phillips Alaska, Inc. is submitting under separate cover two co ie of the seismic pore prediction analysis for nine different NPRA wells. They are: ookout #2 Mitre #1, Nova #1, Nova #2, Oxbow #1, Rendezvous #3, Spark #6, Spark #7, and Spark #8. PAI may not permit all of these wells this year, but the data is being forwarded as one package and will be referenced as being previously submitted in future applications for permits to drill. If you have any questions or require further information, please contact me at 265 -6377 or Paul Mazzolini at 263 -4603. Sincerely, Tom Brassfield JAN Senior Drilling Engineer Cc: CONFIDENTIAL -NPRA Well File Paul Mazzolini ATO -1570 P ECE' Aft gj� 1 A Ca D'o • . PHILLIPS PHILLIPS PETROLEUM COMPANY To: Jerry Veldhuis ATO -792 Tom Brassfield ATO -1550 From: Kathy Heinlein ATO -1346 Subject: Pre -Drill Seismic Pore Pressure Prediction for NPRA Proposed Wells: Lookout #2, Mitre #1, Nova #1, Nova #2, Oxbow #1, Rendezvous #3, Spark #6, Spark #7, Spark #8 CONFIDENTIAL RECEIVED Date: October 23, 2001 DEC 0 6 2001 s. ; • n A'. ,t Summary Seismic velocity data was used to predict pore pressures likely to be encountered in eight proposed well locations. A local compaction trend and a local velocity to pressure gradient translation trend model were established using control from seven offset wells, West Fish Creek #1, Spark #1A, Rendezvous A, Clover A, Lookout #1, Rendezvous #2, and Mooses Tooth C. The local compaction trend and translation trend model established from the existing wells was applied to velocities from the NPR99E 3D seismic survey to predict pore pressures. The predictions show no apparent shallow hazards or large pressure anomalies at the proposed well locations. Seismic Processing: — The accuracy of seismic geopressure analysis depends critically on the accuracy of the input velocity field. The velocities used here were generated using Phillips' AVEL program, an automated high - resolution velocity analysis program developed by ARCO Exploration and Production Technology. This process produces a very accurate velocity field defined at every sample in time and laterally along each seismic line. The output RMS velocities were smoothed over 9 CDPs to minimize instabilities in the velocity field that might result from noise, lack of signal or variations in CDP fold. • • Pressure Prediction Procedure: Phillip's PPFG software (developed by ARCO Exploration and Production Technology) was used to calculate the predicted pore pressures. Seven existing NPRA wells (W Fish Creek #1, Rendezvous A, Rendezvous #2, Spark #1A, Clover A, Lookout #1, Moosestooth C) were used to establish both a local normal compaction trend line and a local velocity vs. pressure translation trend model. The normal compaction trend previously used for pressure prediction (slope = -5 " intercept = 165, Heinlein 2000) was updated based upon 2001 drilling results (slope = intercept = 152 -159). The pressure translation trend model used in previous years fit the 2001 drilling results. The local model, based on the seven wells above, is valid for all proposed well locations. Procedure 1.) A Normal Compaction Trend Line (NCTL) was determined for each seismic line. The individual NCTLs did not vary significantly from the NCTL model developed at the wells. The slope of this line (- 4.5e -05) fit the NCTL calculated from each seismic line, with the seismic intercepts varying slightly from 150 - 155. 2.) The difference between interval transit times (ITT), recorded by wireline sonic logs (OT) in the existing wells or by seismic velocities in the proposed wells, and the Interval transit times predicted by a downward extension of the NCTL were measured. These values are the travel time differences, MT. 3.) A translation trend model was established by comparing transit time differences (MT) to mud weights. This model calculates pressure gradients (PP) using the equation PP = C2 *MT * *2 + C1 *MT + CO Where C2 = 8.01e-5, C1 = .0019, CO = .465 4.) Fracture gradients were calculated using the Eaton Method. Inputs are the bulk density, the calculated pore pressure gradient profile, and a Poisson's Ratio profile (from a West Cameron model). Rendezvous #2: Figure #1 is the pore pressure gradient calculation for the Rendezvous #2 well. The left side is the wireline sonic DT (black curve) with the NCTL (red line). The right side is the pore pressure gradient calculation (blue curve) and the actual mud weight (green curve). Casing points and lithology changes are as labeled. Note the predicted pressure at 7300 ft is slightly higher than the actual pressure as measured by mud weight. This change reflects a decrease in velocity due to the presence of a kerogen -rich shale. Although it appears as an increase in pressure it is instead a lithology effect, and is noted on the seismic lines used for this analysis. Similarly, a silt zone begins at approximately 8150 ft. The NCTL used is based on shales containing only minor amounts of silt. Because silts are slower than shales, the velocity of the silty layer is lower than the velocity predicted for low silt shales at the same depth. The velocity difference generated by the lithology change shows up on the plot as a false increase in pressure. Seismic Pore Pressure Prediction (No Shallow Hazards Observed): Pressure gradients were predicted at each well location from 3D seismic velocities. This report includes displays of pressure gradient predictions on all 3D inlines, both in time and in depth. Predicted Pore Pressure Gradient Displays in Depth: Figure # Seismic Line Well Name 2 IL49450 LOOKOUT 2 4 IL49567 MITRE 1 6 IL49546 NOVA 1 . 8 IL49495 NOVA 2 10 I L49471 OXBOW 1 12 IL49607 RENDEZVOUS 3 14 IL49800 SPARK 6 16 IL49912 SPARK 7 18 IL49993 SPARK 8 Predicted Pore Pressure Gradient Displays in Time with Migrated Time Overlay: Figure # Seismic Line Well Name 3 IL49450 LOOKOUT2 5 IL49567 MITRE 1 7 IL49546 NOVA 1 9 IL49495 NOVA 2 11 IL49471 OXBOW 1 13 IL49607 RENDEZVOUS 3 15 IL49800 SPARK 6 17 IL49912 SPARK 7 19 IL49993 SPARK 8 • • Warmer colors indicate higher predicted mud weights (pore pressure gradients). Seismic velocities indicate the potential of a high pressure zone on inline 49567 (8400 ft — 8800 ft SSTVD, CDP 10690 — 10712) near the TD location of Mitre #1 and inline 49546 (8400 — 8700 ft SSTVD, CDP 10550 — 10570) near the TD location of Nova #1 (Figures 4 - 7). The apparent pressure increases at these depths are most likely due to lithology effects within the Kingak shale. It should also be noted that the normal compaction trend used for the pressure modelling is based upon shales above the Kingak and might not be applicable within the Kingak. There is not enough well data available to accurately measure compaction trends within the Kingak. Pore Pressure Gradient Prediction at Proposed Well Locations: Figure # Seismic Line Well Name 20 IL49540 LOOKOUT 2 21 IL49567 MITRE 1 22 IL49546 NOVA 1 23 IL49495 NOVA 2 24 I L49471 OXBOW 1 25 IL49607 RENDEZVOUS 3 26 IL49800 SPARK 6 27 IL49912 SPARK 7 28 IL49993 SPARK 8 Conclusions: 1.) There are no apparent shallow hazards at the proposed locations for Lookout 2, Mitre 1, Nova 1, Nova 2, Oxbow 1, Rendezvous 3, Spark 6, Spark 7, and Spark 8. 2.) The NCTL and Translational Trend Models used in previous NPRA studies are very close to the those observed at existing wells in this study. The models were updated to incorporate the 2000 NPRA drilling results. 3.) By comparison with the West Fish Creek #1 and Rendezvous #2 wells, pore pressure gradient increases predicted by seismic analysis between 7000 ft and 10000 ft are likely due to local seismic velocity changes caused by kerogen and silt lithologies rather than by high fluid pressures. It is likely that mud weights will range between 10.5 to 11.3 ppg in this interval. • • ist 4.) Seismic velocities indicate the possibility of a high pressure zone at 8400 ft - 8800 ft SSTVD on 3D Inline 49567 (Mitre #1 location), and at 8400 ft - 8700 ft SSTVD on 3D Inline 49546 (Nova #1 location). The apparent pressure increases at these depths are most likely due to lithology effects within the Kingak shale, and are essentially below the proposed TDs of the potential well locations. If there are any further questions, please contact feel free to contact me. Kathy Heinlein (907) 263 -4761 PHILLIPS Project: NPRA PHILLIPS PETROLEUM COMPANY .• , 4^ ,, , Well: Rendezvous 2 Pore Pressure and Fracture Gradient System NCTL: 152-4.5e-5 10/13/2001 K. Heinlein Rendezvous 2 DEPTH (Num sotto MSL) HET MSL MSL UFO SNORI- . II_ . _ M 1 El -I- i "- iiii • . .. . Q :,.. . ■ ; 0,_ ---1- , , ...., 1200- - 1 . ,7 : i --- --,-• ._,_. -!.--- f- , 1000 -- • .: 1 , : , T - 1:— ' : -,- — . --, ... 4 ...‘ : 7:1 T '-• BEW ' A n _ -7.• 2:-.:1..- t •.-- 2000 • . • ..........„..,_,..,.... _ _ I : . .. . _.,_+ ,, . SIDei, -I-- I- . _ 4 _, • t•-•,- --- • -- -ri:: --- _____._ _, 4 ,_,.. . ....-- .._ : , ., • , _.„ • ....-0- ...,.- ..-,•,....._ ...MOO I - - : - ; T - :- i : ii. • •_ .--. • • - i :_ __:' • -- - L • '+' !•• ! • 17--1 ' • 1 , • ; . I Eil 1 • • ! • ....., . . . ,. ;. • - t ■ .. — i -I I x? ,HAKI., -:'=.::- -- - - - - --- - .I RAI - i : - NMI= § arffit' 114111 aill189916" I__ 1 ----- - -i i' . 1 1 _.,.. i.,4 ,._ . 4 gr ; --t -i— __ -4-1- 1- --,-- -1- la ips non 1 .— -- 1- -j : ,4 atilorivumk, . - 1 - i , --i--- 5000 5000 . i IIMI _I . 111111W 1111110111 , i I L____. i ■ JililP 7 1::: . - . . • - 1 - 1 , --.-- - L t i 't " Lei t _ , , . — -••:- NMI tfir...„ RH WI 1-111 i : , 1 6000 r _zom irr lill f 7 ... ):1 _I- i --4-- 4 t . L ., 1 .... _..,_ „..._ ,t.- ...i. ..1 i , ,....\ t . .i_ • 7000 7°13° /1,44Pirrowitrulltlillittilltilli , , I __.; • 11 1111111 IR . . I ----- I i nd 1-1 6911611101 IS __r , ----1-1- 0 MIME - ' : simoromor- .3suion • I ; ..ret MOullOiliV880 DWI .- , ., , • m het -÷- ---,- .-r- ISNIEREIngi II' I I , I • , -: I - ” - 8650 40 80 80 100 120 140 160 180 8 9 10 11 12 13 14 16 16 NCTL intercept at GL o SUN Logarithmic Slope o -41.58112e-OS -9-152-400sT PPTC (Sonic RCTL:192-46E-5 UDEF, Top Trend Model:OFFSHORE_TEXASMORTH SEA) —Mud Weight: DRILLERS REPORT • Casing Depth M Wok Mew + Roped Wood's§ Test X Drill Stem Tut Figure 1 L Production Pressure el Lealt-ell Telt m Led Simian Zones - Ferman Top ... Stook Pipe Loodion % Siletresk Location X Freeform PHILLIPS I~Il�ei�IP PET ROLEUM COMPANY Project: NPNA Fore Pressure and Fracture Gradient Syst Well: Lookout 5e- 5 10/1 K. He i n lein NC 155- 4.5e -5 Lookout 2: PPG Predicted from Seismic (Inline 49 (depth) • 155- aS -S08 PPE_2 LU i SW pp p 5 1 ,, 7 � yy '' '' o o b 7 a ' 1 NE it CDP 2 66 iSQ 7777 7 7 7 7 0777 00. 888888 9 ' @ 0 0 9 0 99 0 8 0 999 99998 0 1 0 6 0 r 6 r 7 0 8 ggr Y�U20 5 3 S 3 5 0 55 a 80 g 5 gp 4 4 0 5 0 8 9 9 9... 6 9 � 4 5 5� � 0 5 0 2 4 4 � � � 8 8 : 8 P I! MSL 0,0 - „ n. r .00 tnr!F r t �, 8.50 v �rt,� 3 980 10008 1 ,. �4 a, ,• , � "hw.r' " , ;p� S0 Nr w 10,00 ' ° , .x � -- ,� �` Wi n. -, 11$ ` 10.60 i., .pP.yi 'p X a .' i , � 11.00 • 20008 - g.. ... 4 . -.— ----- 0 v � � � "'4„f � ` 1. ,� +� *, '�' 4 � t x � , ! .. �' s...., � 1280 0 • ra { x ✓ 1 2.6 SOOOA � � " - 1 3 . 00 ' V . i � L - 13.50 a " ... :� w.. .. r° '�,^�, -'4 uc :' . . f^ 14.00 x , D 4 008 8 ,, 4 �t rt -w' a p f L 16.00 . - P # i' ° >,t a � ,ar " *_�� 15.50 - 'S - .- ,, , .'..-.T.-1-.,.;:".., •+ t Y' 16.00 T � .. ; H _ +a. -.r... , , sir • 16.50 IX 500 .bc� ri. 17.00 '' - ' ¢- , , I • _ " rae ' 17.60 u . k sz^ = �L rr4 ,� ' A a .'` y r c, • 1880 ' ` , P 7 - - ;, , ^ 3 . - rv• :- s. r - _ - 18.60 60008 3 r ,b%r, x� , 1 ! to r'" ., ,,. — , -" -. .�?' a `� ..."'7,.5'1117,7-'° c ro 18,00 mot' -'-' �# N �eY. .' i" a " ' . # Tt - - Awf b x .r. 3 �a l" 3 `1 1 9 $ Rb 7000.0 2. }' ilgk .4 . ;.e r j e* — - + � a .-,,,„,......., * _ .... 8000.0 _ 4* '- � - - — 90008 e rf.,w , . . at .. _ .. _ Iligi ,_,.. , , 100000 ... - s,.�x'"� < ..,,.. I CDP Spacing =110 ft Figure 2 PHILLIPS �€i : : 5 C OMPANY Project: NPRA Pore Pressur and Fracture Gradient System Well: Lookout 2 10/13 /2001 K. Heinlein NCTL: 155- 4.5e -5 Lookout 2: PPG Predicted from Seismic Online 49540) (time) 155- 4S - SOE PPG _T LOOKOUT 2 Etis�i UWIE A Si r NE C1): 1111111182 0o 0 0 0 p 0D007p 00 b'QQ b bbbb b b0 00D00 r 0p r 0p0 1 p0p 000p0p "h88178."" bb 88pp 00000bb bbb bbo 0 0011 1 ioso 411 6 6 g 6 6 6 6 6 6 7 1 7 T 7 7 7 7 7 7 7 7 7 7 7 7 7 7 8 8 8 8 8 8 8 8 $ 0 9 9 9 9 9 0 g 9 g 8 : 0 0 gg g gg 7 7 8 8 9 9 1 6�tt 1 1 2 222222 3 8g 4 1 5 5 6 6 7 7 8 8 999888 90 0 0 1, 2 2 gg 3 4 44 5 gg 9 0 0 111 1 2 2 3 3 4 g44 5 5 6 gggg g77 g g 8 0 , ? 6 0 5 0 5 0 b 0 6 0 5 0 5 0 5 0 5 0 5 0 6 0 5 0 5 0 5 0 5 0 6 0 5 0 5 0 5 0 5 0 5 0 6 0 6 0 5 0 5 5 0 5 5 0 5 0 6 5 IP! i111111illlllh 1I1II ii 11 u1111i �� I ! 1111111111IIii1 �I�� IIi1III i III 11IIII1 it I ,° i ii 111 1 1 iM lii I I i i lii �1 i i i � 1 i j I � I 11 i 19.50 • 400 �lllii * I . ! 111 1 i fill i �� 11 11 I i1 1 � ° [ {t $iii # J ! y jj # j $ $ #$$$ $ $ 111111111 11 0I Viii II II1 111 liilli1111i1i # # { $I$li $$ 12 A0 600.0 1 ii11 ■d D '�i h1 11ii 111 110 1 11 1 1111$1 1111N111 11N Ii 1C 11$11t111 II111i11 - 7 50 T�.O;iii i 1111111111111 11111 1111111 1$11 1* i$il 1111 111 iillillii111 11 1 1 1111 lllll #IIL IIII 3 ,4.60 606.6 � ## 111111 11. Ii 1. 1 #11111 oh 11 11111! 111 #11 # 1 11� 111 1i1 ,4.50 T d R!< i � �w � it $1f11 iI i i �R* , � 900.0 i f 000010, i {{ J E i i 1 11 11 Usl 1WO I Magill } i}i _ 1100 j]j 1 t * + `i l li { j �R ii i . $ i + f ( 7r l } R �j }xj j� „dim 17 7200. 111111 111115"j l{ �. i � gi A i Ai i 60 , 300 . ° I �� 4 � $$$$ $$$$$ # $ ## �# � ## $$ $ 1111111110 TIN $ $ il$ # ## # $ # # � ,918.A0 1400 I � �� ._ 4K � � :, .., 3 { � . .. -. _ . �c- ll ; � � �� 1b0 °.0 .$ "'77755, � t .� 1 (41 1 I '' st � ,>i i 1 , P : ye ti.,, - , $ $ �� ,� °, 11 11111# 1111 1 � - ,� . , � � � , _t. �. . 1700.° at 5 1 1 . ,,j. a: .s . 1131 '5�. tr 9 #C 11►�t ai 1 x i tss •:1 1 1 ti Z... �°_ _ '� � .i � '1, x 1 1$ 1 1800.0 3 a s .� 4r@« ra' ..i �i � �.a•� �e � ra,a:e. nr� e z,... d 7 sx m c? f '� di e� rtw ,�a�k�1� , #i1. F E{ " � 2°00.0 � , •eeir � � R A !1 446 ::. / t w < : y a+;+ m�ea 4"1 ? 445 6 CDP Spacing = 110 ft Figure 3 MEMMEMEMMIM PHILLIPS C0i1s'� Project: NPR. Pore Pressure Fracture Grad System Well: Mitre 1 10/13/2001 K. Heinlein and NCTL: 155 -5e -5 Mitre 1: PPG Predicted from Seismic (Inline 49567) (depth) 155 -45 -5EE PPE 2 MI i SW A NE CD 22 844 6 1 1 . 5 i 152A ; 5455 61 5 7 8 88 90 0 1 11 1 4 4 8 . ? 1 889 0 1 b 7 9 9 0 2 ,,, MSL 0,0 , _ 8A0 50 5 � � > V: �. � � ^.E .tYr31 9.00 1000.0 r+w� y +wa- a s 9.50 s * ..� 10.00 s _ `"`;.:- a,e. .` , 10.60 ?� . � " ,, v^ e , _ • ' ... : , , "' f * r q � , . . _ . psi 11 00 2000.0 ae x R. "Y .. . > r+ r . r sr '^"' * { 4 r" �` • }� 4" 3 ` � t ... �, g . � 1 t ' ..:'4 W - - -.. �' s 4 12.00 c I �'" s ."�. _ a Z .`r- . a � � 1250 3000.0 e ` . ,t ` C h s 19. 00 - ; 15.60 . 14.00 � . y �^ . .. .., • 4 4,4 " 14.50 . . D "a° I ®16.00 E P ®1660 1 ,, eK ," v''''', ® 16.00 6000.0 . • .s ' � ,+M 3 xa: , '-^_ MN - _ 17.00 ,._.,ma x , -l " _ ' .-,.'---- --'— ^_-- ._.._... _. � 17.00 .0,.. F t - 17.50 X, Oil - 18,00 6000.0 _,_ _....__�.;,...._ 00 _ 1850 . ,. r f---4 - ' ' #' k-, .. . • y 8000.0 ' $ ,.., g - ,.. ;L -,i,i' ' g,''' - ---,, - __ „ is 5 ." " ;►, �, L »s .a �' '1/4'''''"4 3i s > „ , . , S fit 4or 0000.0 .. � . { �_ 10300. -- CDP Spacing =110 ft Figure 4 PHILLIPS PHR.LIPS PETROLEUM COMPANY Y Project: NPRA Pore Pressure and Fracture Gradient System Well: Mitre 1 10/13/2001 K. Heinlein NCTL: 155 -5e -5 Mitre 1: PPG Predicted from Seismic Online 49567) (time) 155-45-50$ PPG T Mi $ei��ic:ALAUO EI$NIC SW NE 0000 00 00000000o 00000 bbbbb 000 0000p 0000p0000p00 CDP 6 5 6 5 5 5 5 6 6 5 5 5 5 5 5 5 6g 6 6 6 6 6g 6 6 6 6 6 6 6 6 6 6 6 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 8 8 0 8 0 8 8 0 5 0 8 8 8 78 8 8 89 9 9 1 2293415566777 8gg0 112pp3334455667� 99001 223344556677889 3994♦♦♦♦ 01 0.0 2 0 6 0 5 0 5 0 5 0 5 0 5 1 5 0 5 0 5 0 6 0 6 0 0 0 5 0 0 5 0 5 2 0 5 0 5 0 5 0 5 0 5 0 5 0 5 0 0 6 0 5 5 0 5 0 PH ,66.6 I � I L I V1II I 609 1 �,' 900 i hII fl Ill H HIIiI il h i II I IIIll ; E l �.� � f _ � { I h 9.56 1, ' I I 4000 ll111IIIIINIl II:IIII I 11111 11111 IIIII IIII! IIN II 11111111 IIIIIIII III IIII „.50 506.0 ,111. 111!1111111 111111111111 11 I1 l i j1 II t!t hill ! II ! 1 11 I t I I 1 ,200 600.01 11 I MINI I IIIII I Hilo ''I 11 111 1 11 In I I I 111 I Ii 13. 700.0 i 111 111111 ! 1111 I in mil I 1111! 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N 1 IIIII 1 ii NN 11 li 1 .111 1 � t j llll I1111iR � #� 0 111111 I ` t IIN�l 1406 1{ l WW�if l liii111 }} IE . l J 1I I 1 a , �l �Ep�i l $$ ii {{ hh11hlI11ff hIl � # 11 .� 1 h I 11111 h h 1 1606.6 1 11#1111111!111?00101N1111EN1111 1 i t 11 i Mi iill / /1t11i111 1 11 01110 11 111 0.11111 • 1600,0 01111 I11111011IlhI11hhh111l#l1 #1I '-VA111 1.11 X1101 # 11 1 } �1 1111111# i111 #!1f1I1 uilII #11i1ii 111 11111 S311lii 1700,0 >Rk �I€ Ili i�1i 11E ' X11- 1�111�11 1 111 1t _ i z� iiii 1 #111' 1 ti �11�i� 1ii1 1 a' 11111'��..''� A i illliiiiiiliiil Il 1900.0 ii !{ � .�, A .. �'!!'{;� �+��+�4= .� I � '} "� v ,966.6 � l ii y 1 1i i liaitaiinY t �i o 111 # II 1 1 I��111lhh1111 IIII .� 911 11111111111Ii II 2006.0 11111.011 I1 1111 1 i 111 �1 1 I M 1 .7 : 1411.5 1iIII I 19100 + 11 1 0 j / 1 I CDP Spacing = 110 ft Figure 5 PHI LL I PS � �� F ° a COMP t: N 1 • Projec 1 e -5 Pore P ressure and Fracture Gradient System Well N 10/13/2 K Heinle NCTL: 155- 4.5 Nov 1: PPG Predicted from Se (Inlin 495 46) (dep 755- 45 -50E PPG Z N0 1 SW g p p 5 p 5 5 p5 ' 0 0 o og p CDP 77 0 8 9 8 0 0 1 2 2 314 45 5050545 99 0 01 1 2 2 3 344 555 ? 8889 0 2 3 9 900 1 11 2 11! MSL 0.02 U o 0 sr . 0 -,+.+, u1..: t A, ^ " a ; .� +a 8.00 ¢ %Y "` ,'. 1 0 � ,r� �x " 'a , r�, r«rt 900 1000.0 -� 9.50 . .. u t4.+.< . + a ,n ` s ,.4,--:'," „7 , ;:,: , ,,, : " „. 7 �" { - 1000 +pg' p ... x ' a ^ 12 10.50 . � t rt ,dID � F t ; „g':' '4”''' „,,,,„....0'. ::t r2,, c.7, - - 11.00 20 00 . 0 . ,�f �' . .t =S ., + .m.: z . . k +z, "W.� .� ,�, Y 11 :0 j ' 00 ' ti- ..sA rr�i5s ' y :.- G” i 7 i � £ ',� t� Y '� �5 � ^v ,4,.. � �i`i� � � $ ,. ' a '-'4'''';.1:g."'4";"'' `. f t L Ms 3 _ L r � }Y,r Y ,�, ' � � a '" � 4."' e a � �., � ° +ro$�w.. ! � � . 13 , 00 3000.0 ° �v ".' t h«! w;y. r"F + '_ <s �+ ,� - r ': --, zy,,,. r # r �•:. i i ; 13 .11 i �, .r. , 7� '' � ` " ,' a 1400 D l Cc, - , 7 , ."*` .,. , f . ia•'—V i "' '* , , r 1 5 . 00 4000 , ,. 'h ,. . 16b0 r+arr •M,,, ..'*i., a .. " r 7600 H err. i ce _ " 'a .. ^- ". - 76b0 ifil 5000.0 - # .n..,„,^', 7 aR:. :.. a. i+ kE.r.',.�_ .:t ..-+ _ .,rr ' '' ' : - 1700 0 � a q4 �"" c �"" `• "«� 5x �&� ' r � . 1 t.,--..,.,,- . , vwz r A j " 18 -, { h a F- ']:;_s'''' s 18.5 600 '` "•' V. �" ., w �. , � ®190 • 100D.0 - - �: tom+' • w a '"� us'Y ,5z. „` —7,...„, n,a . . ^` w 'it- n-,-.4:,..,7 .0, wir 8000.0 s. r` '7,...:::'''i w - �. h .� �k1.a to � b ,� r u � x ,-,...,:4:-,;:, � �'' a� �. to sc"'.:. r .. w � .3 �� #' 9000.0 " - � � �".; . ., �.:� v - aO�.. .. �°` � _ w .. ..i. .0.— �• 9500.0 . . . CDP Spa c i n g = 110 ft Figure 6 PHILLIPS IP' PETROLEUM ANY Project: NPRA _.., .,.A PI~�lc�I9.6s�S ��,��e� � Project: Pressure and Fracture Gradient System Well: Nova 1 10/13/2001 K. Heinlein NCTL: 155- 4.5e -5 Nova 1: PPG Predicted from Seismic Online 49546) (time) 155- 45 -s0E PPC i NOVA 1 Seismic:M IN EUM SW NE p1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 p 1 p 1 0 0 p 1 p 0 p 1 0 0 0 0 0 p 0 o 0 o 0 0 0 0 0 0 0 0 0 0 p 1 0 0 0 0 0 0 1 pp COP 3 3 3 3 3 3 3 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 5 5 5 5 p 5 p p 5 p 3 5 3 3 5 3 5 5 5 5 5 5 5 5 5 5 5 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 7 7 7 7 7 p 7 7 7 7 7 5 5 2 PP! 7 7 7 g g gg gg 0 0 2 2¢ 4 4 5 5 6 6 7 7 6 6 9 9 0 0 0 0 0 6 0 5 0 t g 6 g 7 7 g 8 9 0 0 6 0{ 5 g g T TT gg gg 9 9 z b 3 4 5 5 0 0 5.1 5 5$ 5 0 5 0 4 b 0 5 0 5 0 5 0 6 0 5 0 5 2 0 5 0 6 0 6 5 5 6 0 5 6 8 5 0 6 6 0 5 0 5 0 0 5 0 0 5 0 + 1 � B � G , R T� i9 100.0 ._. 1 Y. 11 -4 e%i �"74% : 4 k 4« 7 9 .a ._'1' . 1111 4 d !'4 � S 'ii !'g 11 x'' 6.50 j j ,+ �s$f 200. i i. f , " ? 1I - 1 - Ili i li liii l i liil llli 1 i1P 111 9 E' 9.� • i : ! 11 II I Illiii IIIIII Iiili ii iiili i Ell - o 300.0 i ; ' ". � �� i �� ' � �� : �� IIII. 11 00 400.p 1 } ' 1: i�� 1 11 ��I , 1 � I�� ■!. s` f � 10:.5: '� . i t i! i M 1! I1I! II1111E1111 1 506.0 I 111 1 '' ' , i ,1 1 $i j !` i� 1IIII J I 111% 1I1I 111I I t 600,0 � � 1111 ! I1�114ii11 #�� 1. 7 �...._�� ## lii! � I }} ffI I1 i¢¢rr1� #llyr11ssjlll! 1il li Itll1I 11 lj1j111Ililfli1Ii I11111111 j { 111 11 I i 1 §l0uII io: , 1111 111 1111 5 Siw.A: di ?lh 11t11ll1 ■ 1 11 11I Ill ilh1111 111 I 11111 11111!11OOH11 ,500 E 9 M � l n 11i ii l# , 111 E 1 i1 it Ell I l l it it ;: ,.$) ,600,6 .. � , . � ....._ ,.... 7!'�, �� , � -�14 ►� 1� S'�� it ' 1j ' 7�� 4� t jI itt y } s1' 1 ,7,00 . J iiiii ii 1i f ;,�. i „� i _..: ,7 50 „006 1 #lull ##1..��1 �1 #�l�l Il�lill loll i � OWN ii i 1 1 111111 1 ltl i iiii i lE 1 li EII11 i. i Il E 1 ilk . !.. .11 16.0 13000 of �ti'f }j }i i } [ yj -y lti + }� 110 i .. ill 1 }/ 0 h IIjjj111111)111 e$ll!I ,6 ^00 1400 IMINCRI l�S i .7 2 i j Mi le,4 { {{ ! " ` iils {4Al ')] - ' .. i " ^ I JIJI j 1500.0 1iil14i iiilliL 1 111111111.1;1E1 [ ! h1. 1i i 3t, r { it 111111 .ti 7- I t ` I � � 1 • llll liliil,1111 MIIi11III1I111 I±11 IIIIII �i} l#ll ,�ilili 1.1 IIIOI111IIIIi111i1111i11 _ ti* 1600' mss, <.r --- Q<-C 441 wig .r- wa"yJ " ;�.� �lisa��t��41$, aka #�'�t+e� �t ■ AV � iota ,100 ] I1 ' .ar /11/1/1111 16 0 00 3i �.._.. y c. " ' _ t y All 0900.0 �e5 ii ; ij � s 5 � filly ` � . i .S1Kt • f 1 11101 c . i t 1 11i l lillil l 11i111111111111111111111Ilt lllll l 11 MI Dili ll A l i n Ji Iillii i iiliti l o 2000.0 1 '.. CDP Spacing = 110 ft Figure 7 PHILLIPS ®® rIS PETROLEUM COMPANY Project: NPRA t ` f Pore Pressure and Fracture Gradient System Well: Nova 2 10/13/2001 K. Heinlein NCTL: 155- 4.5e -5 Nova 2: PPG Predicted from Seismic (Inline 49495) (depth) 1$5 -45 -505 PPC_Z NOVA 2 A SW NE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 0 0 0 p 0 p 1 0 0 0 0 0 5 g 0 gg0 7 60 5 0 0 0 g 0 0 0 0 0 0 77 5 p 0 5 p p 0 0 0 0 0 0 0 5 0 1 5 0 5 77 7 0 g 0 0 1 0 0 0 0 7 0 q 0 p 0 g 0 0 0 071 ? 0 0 0 7 0 0 0 0 1 0 0 0 p 0 0 5 CDP 4 122 4 gg05 4 { 5 4 5g0 444 00 4 0506 "6 U 5050505? 010 7 7 8 8 06050 „, 6 MSL0,0 6 T , 606 0605 , , - 5 8.00 8.50 1000.0 99 ,5p • '%-'-'''..*-' { . r '- r 10.00 3 a &r �� *� s +r^*a' 10.50 ' C,. F" " ,¢ ;F" w ., - 11.66 s , 6` , 4 �I y ' Fi`. 1140 ''':-.r; . ^^.,', .: i ,.. a:' i ' " A r ' 12.00 ill, 2000.0 s _ +,f "" - x " � 6 yr'.✓` t , : — N F 'f,,. 1240 41,' - _ s ,. t z 4. ',.; r �c x r A ' ffi0f f .6 { + ". . 10.00 iii 3000.0 } 4''''''''' a a�, ' gg ,�.. a .. .yr 1340 ., 'zr � ,+ . r . { • , . 14.50 D 4000.0 • � ^� vr 15.00 :. .: 15.60 P T",- »w, _,.,e• + "1.4" H ,,, ' . +'> , " s. .r:. r a � , e k 1 16.50 Mb 5000A x r �1 .+x � � '1- { .a Yom- i . x. r „� - ' 5 1 k 17.00 si . '? ,r .1,'m. '';.4.4,-t _ z,.. r _ , ' "- 17.60 .t 1.1: G 'mow ' . ' ; *4."::,,_ .r ar TTt i ;� 18.00 6000.0 .3 r ram u...,..,�,.� , F - " 18.60 x �.r r4tS � ". ,: r. .+. +a.A� ` '. . "p 1 sr r 19.00 ,, - .2h - ,' t aA 1 1?, .+* ` S ',"",. - „C R JF d $�+ N Sr' Y t i" h ..'1." Y 'a w,y1P '>MF ? 7000A _ �fi 'x - .rv'n v''.' , y , ' ; - 't'Xy" 'I ' •` ..„ ,., . - tp, ..ti'.. " 'NtF'a`G' . • Wmµ .!1 y'''a'� ^ ' u , �K31 f� 8000,0 a "'C l * ` '` ` l w ' `� , r ' ' ." " ' a t , 4? Y , + , T xw 3 .? 4 - - ' dip lik 9000A s ue _ 'r �*' " rte ?fir c' ' 's' 4 10000A CDP Spacing = 110 ft Figure 8 PHILLIPS a a ETRO a eats COMPANY P [A Y ��II.��g�S � o ��t��;;�.r�� oa9`�6 °s��1 � Project: NPRA ` Well: Nova 2 Pore Pressure and Fracture Gradient System 10/13/2001 K. Heinlein NCTL: 155- 4.5e -5 Nova 2: PPG Predicted from Seismic Online 49495) (time) 155- 4S- SOS_PPC 4 NOVA _ Seismic:ALAMO SSSIIIC Vj�K1 SW NE p 7 o 0 0 0 0 pp 1 0 0 0 0 4 p 0 p 7 p 0 0 0 0 0 0 0 0 0 0 D D i Q i 0 5 0 5 5 9 0 g 6 f 6 i 0 0 5 j 6 5 0 g 6 g 6 0 6 6 0 7 7 y 0 0 7 7 7 7 7 7 7 7 7 0 9 9$ $ iI CDP 4 4 4 4 4 4 4 4 4 4 4 d 4/ 4 4 4 5 5 5 5 5 5 5 55 9 p o 8 55 55 112pp334 {{5 67 780990 81 2 33 5 78 05 �b gg bb p 8 bbg !/! 0,0 0 5 0 5 0 5 0 5 0 5 0 5 0 5 0 5 0 5 0 5 0 6 0 •0 6 0 5 8 5 b 60 0 15 0 0 6 i 6 0 5 0 6 0 5 100.9 MOON 111 111 1 11 . 1 l i 1 � ` "; 3 - { r , rye ® „ t 80 °a .:. M _ -.. . 1 _. 1 1� 1 11 1 i l 9. WIND Ill 1 11 ' 200,0 950 . 11111111111110 I I i 1 1 I 1 111 iI� i 11 l i td 1 10.90 300.0 1 ll W} @ � �I � � IO O � 111011 4 :.9 T i ei<I !! 1 11.00 1.50 I 11 111 1 11,,1 � ! II 72,E 600.9 ; 1111 �. a 11111111 111111111111111111111111M11111111111i =:. im iii 31 .00 700.01111 ii 1111 #1.III IIIII 11111111111111111 1111 1 h # 1 } ? 111 1ja11111]111ji` 1 fill III 1.1111 11111 ,4.00 ; . 3 x ; r j I I sr= 111 11 11 i'283i2 11111 1111 1'11111X11 1111 10 1N1 1111! 1450 T 09 �� -�,, . .� � # { t��.s.xs#r�1��t :i3 � �� HE �i j� i �i j f i q E 900.0 } iiniii i l� iE "I' .5 1 1 111 2 $ # P ) I 3Sr 9 ®„6b , , 000. 0 �, X �} I 4; r . 14 < l# ;t . tilt a. f '� i I � �� I M 1 1 1111111 11111 .11 19 I 7 „00 ; "' � "11 � 113 1 t 111 1111111111111 1 1200 f MIN 11 E I lll Illlll illl llllll 111111.11 Il IM 111111 1 11811 1 1 U I/ 10.50 ;� S y+ # #t ♦ !# ,9.00 1300A !}1 s�.1H.i31l ommou o i i 1 J 3 J iJ 111 um 1 l - � ,"'Iv r H I ND , 400,0 �� .�� . �,� . � ;� � _�� .�t.� N ,� � � x 1 III 500.0 itili � � - { � �i . < .. i 1i I I . n._ . � 16013 ...$ i'ii ii�� iiiiii i iiiiiits-. i 1�� l _. �_� �_ �� ili ... i , r - tc <• ��c1�s� iit :f2 � i�c ; ;f+t ► <<° ' : -- ►�: f �°�xc�° zar". 17oa.o } 1 'i �Zrt t3 . > >k. s 1 w x s�sci b i' Iii " *I I Y3' trt 1;t -E � ci-c� ;�C> ilt' a.+, : Vl it ,. »,: 4. Lrs 1000. 111. 4 �:: ; ANN 11 1 ll iViiii irP I 1 . L Ott 1900.0 41111 11 1 I 111 X1111 ii i iti l lt i ll 1 1111 Ill 11 I �Ill 11I.'� 1 µ 11 .1 11 Iiiil CDP Spacing = 110 ft Figure 9 PH �e nn 6 P PETR COMPANY Pro ect: NPRA Pore Pressure and Fracture Gradient S Este 1 Well: Oxbow 5 10/13/2001 K. Heinlein NCTL: 150 -4.5e Oxbow 1: PPG Predicted from Seismic (Inline 49471) (depth) 15, -15 -505 nns_: 0R0 i SW yy pp NE 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 6 6 6 6 0 g 0 6 6 6 6 6 6 1 6 1 6 0 6 6 6 CDP 2 2 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 5 5 5 5 5 6 b Egg 5 6 6 5 8900112233 3 5 - 78899ga � 5 i ; t 11 223 4 455• 8 8 9 0 6 0 5 0 6 0 5 0 5 0 5 0 .5 0 5 0 5 0 5 0 5 0 6 5 6 0 5 0 6 5 , 6 b • i 9 N! ' " „� ; .� 8.00 -.±•,- " -<:x. z 8.50 1000 ' 9,50 • _� •"� 9.50 x,. '� s s 10 .00 •'`. •. , 10.50 ._ .00 . � ._`. 4,- 11 11 .50 >.. • n Y _ 12 .00 ' �, -' x 12.5 3000 -- --- "__' -_._._....- -__......_ _.__ _....___�; -_-__. - •. _ ._..�._.__.- . _______�. .__._ �..��.�_ _ � _....___. 1 ,,. ,.: '�' 14 .00 x14,50 D 4000.0 _. . . _____, _._....______. �_.,..__._._ ._.:___._..___________�_.•.___. _ _.•- :. _ .�� 15,00 E P 15 .50 T 16.00 H 16.50 ... - ' ,:_- - _. ._.___. -.. -.. .. .._ -----1'-'," 17.00 s; -- 4 \,`,.. ' - - 17 ; 18.00 6000.0. ._._. _�_ 19.00 IIII 1850 ..., s `..v+� ..._ ... �., 19. 4 ` 3� - ,.-> �'• A . . , ' t ` 0000.0 t, . . ,R '-- „,. • ' ., £ fi x' �, - �� u 9000.0 - tai +^a 4a r : gi p . 8 », { " °¢ • 8 �. .k !1 ° F 10000.9 /' ,-{ 1 . : CDP Spacing = 110 ft 2 Figure 10 PHILLIPS �® PS s��9 -tee OLEU � a r r� c;c�® ect: NPRA "I 2 R,. ��.0 6'° � 5' �, G 'J° �D � C� a�% 0 �� 6 6Ft : 6'' 0 .., Tr P ®re Pressure a nd Fracture Gradient System Well: Oxbow 1 10/13/2001 K. Heinl NC TL: 150- 4.5e -5 Oxbow 1: PPG Predicted from Seismic (Inline 49471) (time) 15$ - a -sos PP i OI8OW $,i,.ic:Maro xana SW pp p pp pp p po p po NE CDP 2 2 368 6 6 6 6 3 3 6 � 6 61118116111111P11,1111bil 6 6 6 6 3 6 6 6 4 4 4 4 4 4 4 .{ 4 4{ 4 4 4 4 4 5 6 5 6 5 5 s 5 5 4 5 4 4 5 5 5 5 5 7 5 7 0 5 g , 5 5 6 6 6. p 6 6 6 6 6 4 6 4 6 g 5 6 6 6 6 7 6 7 6 6 88 8 901 233 66 b7E 0011 223 i�y �„6 a 8 0 - 0505050 56 000000 5 0 0 0 05 . ,. !!! 8.00 0,0 5 0 05 � 505050 2 3 5 6 0 7 8 0 2 3 0 7 8 ,DD. 11. ll # #1# N # #IM# . .. i I /I i # # # #. D �D ' I II it I IIIIII 6.00 II 8000 II 1 #ill I II t 1111111E# I - 1111111N10/1/11/1 # 1 II I 1 ; �0 0 • 300.0 11111111111101 Illl II 11111111111111171 IIIIII I II ll III O I II I IIII I 1911111111111 II h I illI III I ; o 6000 : 5 . .. �: , " f I ll I .IIIlIII I . . . ;2 # #II�IIII �I IIIIII.��ii�� . # # i IIIiI I i #iill IIiI I�� I i 6002 1 l ({ l l llll } ($ y li m i i �ti s S ` 1 1 212 ti i j / j l �� li mi S ISIR I II I { � ll 1360 7 00,0 1 1 1 1 11 .1 1 11 l 1111EM l lllllllll lull llli lil 7,i lettl IIli >pilEl lll moi 1420 {{yy r 4 y ;' { j_ �`. fa : # S $ S tc <Y,.��$S x ..�$t ,7 } } s}'sg i j yi �/ jj ¢¢¢ {{$� {` f 8002 w �� illl �� i� ?2��F�7f1 ��t ?��Y�7� #� I��S2� ?ill 111 11111II1� ��5��5�5��_�� l� Rlll 1�b0 111 ii f 1 MIM1 i l i ]] 9y I iii 15.DD T ��C r2 ? ? 15b0 M 600. y g 111 i itailitigi ?�L'SRtil.r S7C� � i' l ] 1 ■ ■ 4 1008 # i# i Ii ii1Ililiiil111 i # ii # 4 1 1 11 i I ! ,s,so �. a . d 1 141 1 t r fit i � ,z DSo 1200,D ::: ii 1# #Iliilliliilii� #iiilllll #ill # #I #i I l ill l ii I#I ilill l il lil li #i llililillii l ;9 .00 ,3002 _ . �i��III l �� II� � �� 3 � � �� #i�� mom to �� i��ii # ## #iii #�� Iii�iii � � � iiililli I. ill� �# i >F� g i i i Dili _ ii 1 5 002 , ' t ` i.. 111111 ail #iii _# # i�. � � :��iiil # #iii #ii #ii� i�� . • ,b00.0 - s a s � °� 17 00 ` ,� � '1a 101 ,i gi x't '' tom ii x ;~ . atfilill161:71:;;. '' � � �� 1,114 m � ,� 4A m r ( ... . �� y,�_, aa� , . # 3 �1 ., # # 1 °.o , ''r 1 � i0' ) i i a" s ` 'I0 411 ' ' a � 20002. , f# 1"' 'i #i # #lil�� #iq�ili #i CDP Spacing = 110 ft Figure 11 PHILLIPS VIL o � �F He MPAN Project: NPRA U Pore P ressure and F ractu re Gradient System Well: Rendezvous 3 10/13/2001 K. nlein NCTL: 152- 4.5e -5 Rendezvous 3: PPG from Seismic (Inline 49607) (depth 152 -43 -505 PPO I 009002VOUS_3 Predicted A SW NE 1 0 0 0 0 0 0 0 0 0 0 0 1 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CDP 2 3 3 3g 3 3 3 3 3 3 3 3 3 3 3 3 3 3 4 4 4 7 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 5 5 6 5 5 5 5 5 5 5 II! 5 5 6 55 5 5 6 6 6 6 6 6 6 6 6 6 6 6 6 6g 6 6 6 6 6 9 0 1 1 2 3 4 4 6 5 6 7 • 9 9 0 0 11 2 3 3 4 5 0 7 6. 9 8 0' 0 6 2 3 4 4 6 77 8 8 9 9 0! 1 1 2 2 3 3 4 5 5. 6 7 7 8 x x 4' -. - w 0.00 8.50 900 1000.0 - 9.50 • ,. .. l y� 10 00 _.... ._ .. .. _- ... _� E 5 R '. p "'_:_.., i 1000 11.50 12,00 12.50 3000.0 - __.;_____.u..._._- -"---_—_`_ _.- ...._F _..__ 13.00 1350 ..; 14,00 14.50 .. - D 4000.0 -------- _....._ . _ .:. .__._._..._. _ 1500 0 E P 16.0 M ry 1650 5000.0 `' ___._._.�._ ___-_. .... _._.�._..___._.___.. . e= 17.50 --- 18.00 :.� 18.50 •4�M- 19.00 7000.0 ' _ ' -11-'1°1- ;�:: ', 6000.0 k ^ s-« i k 9000.0 'r.' 10000.0 CDP Spacing = 110 ft Figure 12 PHILLIPS PHILLIPS PETROLEUM COMPAIMY Project: NPRA Pore Pressure and Fracture Gradient System Well: Rendezvous 3 10/13/2001 K. Heinlein NCTL: 152- 4.5e -5 Rendezvous 3: PPG Predicted from Seismic Online 49607) (time) 152- 4S- 50S_PPG_i RENOEZVOUS_3 Seismic: ALAMO_EESYIO SW NE 1 11 111,,,,1,111,1 „11111111,11,111 „11111, 111111 „11,11111111,11111111111,1111 1 0 0 0 0 0 0o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CAP 2 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 4 4 4 44 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 9 3 3 5687 0 1 1 1 2 3 3 4 4 5 5 6 , 4 9 0 1 1 834 8 7 8 9 9 0 0 2 2 4 4 5 6 6 6 7 7 8 9 9 1 I i �iiRi iiiiiiiiiiiiiiiiilli ig � iiiiiiiii3ili el i tili it1iililiiiii ll�f$� O N i� { i ii l � " 91 itliiit r iiklik k iii 8AO 100,0 �� j mom j 8.50 2000 MII 11111 111 ll1 i 111111101111111 1 1 I h 1111h 1I � 1 . I 0 p 1 -- 9.50 i 11 ii 1 1 1111 1 Il 1i 111111 II 111 1 i 11 Illill l . 16.06 • 1 I i 11 1 1 i ID(^! I e :Ail 1 l 1 11,. 11111111 j *Ill l 11 1.11 111 1 i I M 011ji11 01 �: 11.50 00 500,0 v 1 I 1 II 1 i/#j1ia 1 1 HEWN 1 1 111lll1 ll IIHIll1 lilt 111IIWIH1 j I0 101 _ 12. 600'.0 t 1 I la ( l�lll 1 ? 1 1 l $ l {llll u110 11l I1lfil } h ul l +` 11 x$ 1111 1 1 Ill l 1i 1 ll I 1 111 111ih111l1i�11 / : 13.50 700.0 Ii EIII �...TTT AIMIL117775 31! 11 1 ? lJIllil y$ RI MAN 11 l Il 11 jII i + 01111 lj 11 1 111 i 1 {i ! 11 `� 0111 . ,4A0 ;. i7;'. j I III II UMl1JII1IIIh1)111 14.50 I s {sI _I ... .IIIII��l��l III li 1 80 0 ,0 ,jyl*�I}]11 IIIIiIII +a 1 }IS IIII `gs.. 1 CII 1111 7l Si ll flll! #Ailllll! Rll3ll 116i1i11 1 III 15,50 900 0I. _J IL8i11i1�1�1�i��I�11`il �� + i� t E l 11 i i ]I�1. ��il�l I� I 1660 ,me, ,996.6 $i1lI t ~� `y 7"" i� 1f# fl f 11 111 011111I 11111111111 111 l 1h1IIIIIIihIII MDMI I 1 0111Illll1 " 1,00,6 , .�.�, , i �>l<.1.#11 #1 1 #1111111 I111 1111111111I111111111i1111111111 it11i11111111 11I 1263.6 c ��: 111 ! 1 1111 19. 406.6 1500.0 gg�} . $) ] j j j I 1 j { # j iI �� / j ¢j 3 l _ { }� _ i8:i1^I Iiilllll�7r 11llli illllilll l Allllll l,�lillll 1I �9 I I 14 1. 4 Ii i'i �T7 R 11. 1,70:0,04$4 i v . i . � ,l i ill it I .1 . _ I I hill 1 Ill 1 # Ii $ g ,w z,<14 1699.6 i . 1 P.L4 ° . M . . t it 11 11 F ' well- o a � it ti # ) f / d .6 4 1900.0 x r' 2000.0 � � � _ , ...is s... . :. __ 1 1l � , , ! .1, ; ) l CDP Spacing = 110 ft Figure 13 PHIL PP "Pe PETROLEUM C� ^! Project: N PRA r Well: Spark 6 :' : ? Pore Pressure and Fracture Gradient System 10/13/2001 K. Heinlein NCTL: 152- 4.5e -5 Spark 6: PPG Predicted from Seismic (Inline 49800) (depth) 152- 48- 505_PPO Z SPARK _S A SW NE 111111111111111111111111111111111111111111111: 11 .11111111 CDP 3 3 3 9 9 3 3 3 3 ° 0 4 4 4 4 4 4 4 4 4 0 4 4 4 4 4 4 4 0 0 5 5 5 5 5 5 5 0 0 5 5 5 5 ,v,', 5 6 6 0 6 0 608 6 6 6 5 6 6 6 6 6 6 6 6 6 0 7 7 7 7 7 7 7 7 7 7 n15�9,ai 65b 688 8 88 88. s bi6 0 i 6 . 3 .65�6,5� � 5 6. 8 . 65bb 5 5b�$ PI! aa 6.00 Sb0 ,4, ,,L - a�' i � ,-. +t + • 10.50 2000,0 A,. -' " .° - 11.00 . . , � ' � '�? g � , � 1 1.50 n 2 00 y 12.50 3000.0 r s 1 13.00 +5, _ s: t 13.50 t 1, 74 . � £` x«tt — 14.00 D * - . '' . .., 4•J . ' "" 14.50 . " r . . .. 15.00 P - s 15.50 € ,°,: ie d a +'. 1 0'5 H 4;—' r 3` ,.� t ":4, "� t . - 16.50 5000.0 ...,,:*i:0 Utl .. ^� r: r 1700 t � , , . r r » �� r � � ,� 17.50 `, e; 8 000 . 0 »» l'„ I yp ,� w k t ` �s . ` iv. 3 ma _'i`7- - ..� { - - $ + g :14, ' l_ - 9000.0 �� :� * '1:^; ." 1 °L . .�: d T <6 ,t, { H ' , `".k '_ .. � ~ � tea*' _, 1_ -- -• _. '4'° 'h'` g �� ` "`- ��4,• ,-- . ,- �w. ...- .< 10000.0 CDP Spacing = 110 ft Figure 14 C PHILLIPS cn s aaa -° ® e ®a . COMP a c�cev Pro NPRA Pore Pressure and Fracture Gra System Well: Spark 6 CL 10/13/2001 K. Heinlein L: 152- 4.5e -5 Spark 6: PPG Predicted Seismic c (Inline 49800) (time) 152 45- SCS _ PPC_i SPARK 0 $ei�.ie:ALAYC EE$MI SW NE 'obbbbbbno'p� 22 b bu 8 114 , 020 0 0 00 Q 000b002 7b b n n!I CDP 33 ■ 4 4 44 44 X 6 0 5 0 0 6 0 • 0.0 ip�msyx� �. - 8A0 100.0 n �a_ 4 200. t. i y e :�� r` r ° ° 't 1 h ��aed��r� � ■ 111 « i;x �I M i l I s.0o 300,0 11111111111111 111 Ii � �. t I . r' . i i t .ft�� ,x ii iiiiig • � Ob � M u i ll 1 111 1[ n I ° 0 0 • Illlll 1 1 1 1111 1 1 , i ' "Jilin 1010 I�I I �I IIl I 1 11 I II IIiIl lil 1111 IN 1 6000 11 11 11 I1I1 11 1 i 1 1 1 X111111 111 1111, 11111 111iI1111111111111111111 12.00 OOOA 111 1 111 1111111111 lillll ; I llllllllllllll IIIIIIIl illlllIIIIl ll 1 1111 �r ,3no lli 1 I I�1 1 11111111111111111111111 111 11111111111 # {) Il j f ij � j i 1 14 :0 700. i[t - \1111 X l .� 14 111 l 1 1 � _ 3 �1�I111� 111111111111 1 800.0 3 °s «azs< 1 - r r �1� � a 18.00 E �� ` ��;� �� I 111 � 1 �� r� � � €I �� :I 7 6.60 ,. ,0�,0 411 1111#11 ; z:� xim 11 1 1 111111111111 1 11111111 u1 111 1 1111 1 1 9 12 � � ' Ill II II I l I II Illl111 111 1 I ll1 111111111111 ; 9 1900.0 gill 11 1 1 119991 � 7 1 # s] I� "at }} 1 , um 1400.0 � � � � . . x � . � �� .. � '-- c,�.� -,=� t ' � .F _ � 'f'� ,500.0 .� FP7I l �� l 11 11 1111 1116111 1 1111 ;.1 �� Y x #t3 ; �_l #Iti # #�� # # # # # # #$x�t #� _ �iai 1b'00.0 .rri..l'Zi�!'�I�l �.i'�►�ti�rl.. f� <. 'x'��" %'7� �iFZ.r - _ _ _ _ � 1 11'- g, .C � i ` r � � �• ' v r r f <:. - r ii s, tt ilil u.a,.,e. a z:x �g x .e 8 "a �# �•.' _'am'tii � , "+ `. � . ;eteu �' y `� :. �. r ,. .�.., � itifi‘‘ C:il 1 .i 11111 1 1111 1 ;.:4 4 171 41 ) 1 $ m ,: f . ' l l ,500.0 1 1 1.1 1 1 �1111I1��111I1 111 1 1 11 �11� 11 1 ,700.0 . f 4 ° � � � f� i 9 ' ..131 . -2 . .. 4 , i� a 3y' 4 . 2000.0 - -: ��_< <� ic�y LZCS. c{ ti. M' ;.:"'£ ° E4' ie7s` 8�' S 1i" L' L"9S"l�i":4iS93'#1'$'R�SaB'X� ". ... J, d, e®' . e. 1" Li .........w.K�a3.rCtisP.C .�..*..., . CDP spaying =110 ft Figure 15 PHILLI Pia ,iLaIPS F,T m0l� aV c,oir�P �s�s a Project: NPRA Pore Pressure and Fracture Gradient System Well: Spark 7 10/13/2001 K. Heinlein NCTL: 152- 4.5e -5 Spark 7: PPG Predicted from Seismic (Inline 49912) (depth) 152- 45 -SOS PPG_Z SP ? SW NE 6 3 6 i 01 CDP 3 5 5 0 5 0 5 0 5 0 5 0 5 0 5 0 6 0 5 0 6 0 5 _64 5 0 5 0 5 0 6 0 0 1 5 0 5 0 5 0 E 6 6 0 5 0 5 0 1 5 0 6 0 5 0 6 0 6 0 5 0 6 0 5 0 5 0 5 0 5 0 2 0 11 4 !!f 8 °- 8.00 4: .s -? - -,..,: ,,,mow}. y,r, '"'"" I, 41 0 8.50 A • 9.00 1000.0 ---- -�_._..__- ___._.__ 9.60 10.00 +e , 4 `a ', : 1050 a >• �. _ w te ` a''.'' . 11.00 2000.0 .. , 31,..,4. �„ 11.50 a u 12.00 „ r, 12.50 ,. r . 13.00 3000.0 13.50 .�,... _... 14.60 D 40000. _, ,.. _ ----- _- .�. -- -.- __. -__. _..._- •sw+5 15.00 H .15.60 P T 16,00 H 16.50 �. PO 5000.0 ^- --- 17.00 ..... 17.60 _ e _ 18.00 . 18,50 6000.0 -..,._ ., d s 19.00 7000.0 _ ____ "`__--- lig • y � z . 8000.0 , 4:. a, 1+ .e- s 1 a ! -. .Y.. +5'' , .,.,,. `,g 9000.0 , s � sa :: - •,. ' 1 0 . 1J ..rte -% � ' Y ,t t . x 'mm`s ... , - 2 . 3-, , ,;., c. , #' a au ` .' 42 ..< z 4z s - '' y ' , . 10000.0 Figure 16 CDP Spacing = 110 ft PHILLIPS PHILLIPS PETROLEUM COMPANY Project: NPRA Pore Pressure and Fracture Gradient System Well Spark 7 10/13/2001 K. Heinlein NCTL: 152- 4.5e -5 Spark 7: PPG Predicted from Seismic (Inline 49912) (time) 152 -45 -50S PPU T SPARK � 7 Seismic: AUMO_EES111U SW NE 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 11 1 1 1 i 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1, 1 1 1 1 1 1 11 1 1 11 1 1 1 1 1 1 1 1 1 p 1 p 1 1 1 1 CUPS 3333393533444444 !41 4444455555 555555555555 666 5 5 6 7 7 $ 8 9 9 0 0 1 1 2 2 3 3 ,,{{ 55 55 6 7 7 8 8 9 9 0 1 1 2 2 ii pp 3 4 44 5 5 6 6 7 8 6 5 gg 9 0 2 2 3 3 4 ... 0 6 0 5 0 5 0 6 0 5 , 5 0 5 0 5 0 5 0 4 5 0 5 6 5 0 5 0 6 0 5 0 5 0 5 0 5 0 6 0 3 5 0 5 0 6 0 6 0 5 0 6 0 5$ 6 yg� 5 0g$ 6 0 6 2 PH ,00.6 A I 1 N ; 1 8 i . �:. 1 � / ■ I .:� c O li R d II ! tll ! I� II�I�I�IN NIA hill 1 I 1 j ] 1 Pit ! 1..tli1I 1ef ! +! 1 1 r j 1 �1f1 " :111:500000 am 460.0 . ]t � � 5! @� � 6E � f � �$ g1, f s. ��?ii g ( �� ! l F y � � �!{E � 500. ((l! 5 � {{ f ! f j / [ j� � }{ ]]jj[[ �)'{j i i { 6 F, ..?€ ,!�. Py t � 21i� 1 .[ f {jR if11 +� 600. 1 *YU I I■ I1I ' 4 ` I j I1 i1 � i� 1N1[1I111h1 13.00 ? )17"3 '$ ] ss *j ruilimilli j■■ { 11 ■(t'([��(r( ■( !j 13.50 700.0 a�� .ti�>:C R �I;ttl)"1clatl � � }y i � 3# � �}} Y i fk )} f S s � .!( y # }}}t {{ I �}c i71 2i s �7 1i ii! �`r { 1 4. 0 606.6 ��il�fi{�A}�3i+�R�`��i�ft��5�� H Man �jj l] rsjJ +j, jjj '!""!}'. ,"9„1. ###J.Ti9 { �' ?75� }Y _ I 15. EA 900.0 `° <a yyjjp(� rx. . {{ {{{{ ,{ ! a } {j$ j �y {. { } 25 �$r'4- yes t{ } 'tea ��l {' 15 ? 1 . AS H 1 I ! . 4 # # l i) l L �Lt � +[Z t ��F ° d s�S ti 16.50 ,. .� , _ ,.. } !1 # #� ;z:5o }6 ate ��yyyrrr jj # _ f 111 1 1 # viii#! M 11000 l 1 1 41i.} 185D 1200.0 �. a g?J � � 1900 1300 i 8 tk 6 i 4<'w# t ## I# r iiii 1 a # i# ## i C � 15 , 0 ' II1 t ill I Y �> � i 'L f � �3X A . ) R i +E i ... ,' s'� "� i# tai #�;ii +��!�ZrEt�< � _ita #�><r;si T ��'�i�� -- iv �, X {� /w-, �1��i`7�� • 1800 tr .lv �.,r., -=.- That» $�a3it�� fS iw f� 2�".�.G. n, e< > 6�is5 a:1.[w*t�.�ec ata `f` aG5 9' ai - 5 a> .K ._ { �e �+ gg gad, 1� 1 3°e . a . 3$ ! i� ` i ) ' # # 43J # i #111 ; 3 1700.0 180001114 ii iii di i #. ii # , 11 2000. I l �_ ' - - cc " < .- 4.. -.A .bss:°csms� g /. 5 swiat fs :" es► "a�! ;L?E i3 f �+ c + �r z CDP Spacing = 110 ft Figure 17 PHILLIP s ®ew € -aw®�= � �. ®cean CON, r e Pro NPRA ;; Por Pressure and Fracture Gradient System W S 10/13 K. H NCTL: ell: park '152- 4 .5e-5 Spark 8: PPG Predicted from Seismic (Inline 49993) (depth) 152-45-50S _PPG L SPARK_8 S W ypyp p pp pp 1 ]]] p p p 77 p 7 7 p g NE 0 3� 3 9393 9 33 0 gg g�g 06 da 4 44 � 0 4 6 4 0 4 q � �4 � 5 11 6 6g5� p i� 0 6 5b6 �g 0 g 6Q $ 1 001 g 0 0600i1 i 8 0 CDP 3 6 T 8 S 1 3 4 4 6 6 7 8 9 gg 0 3 4 5 6 6 1 8 1 2'S 6 6 6 , 5 6 6 8 7 6 ' 5 $ 2 !!! 61t , 5g6 b i i �6b. ,, i6.0 1.6 6 , 10,00 i b1168 . . 6; - ' a — s.00 1000.0 �,_ — • 600 x ". 10,50 2000,0 °° 11 71.50 Q '.. _ 72 s . " "` { v .-- 1 2.50 3000,0 t' **r+ 5` c+4F � `, . , a y, .._ _... _- _,.. 13.00 50 [ a y 3. ` ' - , � , . � , f t5 � 4,00 D 4000.0 ' f A : I* . � 17.50 ' *'" 4 ' ` -wa a ' 5,'1., 15.00 P ,..r. * 16.60 1 8�.r. A ,, m F " ,�' 16.00 6000.0 • `� "t `' s f �?^ ,- '"i sm' 1 ° ` f 4 16.60 e r i a _ 17 ^00 � � : '.4.741:f 1s. $ 17.60 .S " ?•art, ,, . *.1„,-V,"'6:, ' ,. N� 18,00 6000.0 - t'" :1,4 r : 18, �► x = � ` � 16. r � , 7000,0 ��.nr' �xv `�d � n �r � ? a fir, N _ ,�, are fig 1- P, 80 00 , 0 F �r � 9000 ^0 -a'.- i " +4, - ...Kt*.- ' : � P : ' ' s ', . �,� - ,� 5,, ' ' ..."+ _ti a ! ".. a x ...a �,r K `°xa" ` i 1 _ . ..^r r' ., . 10000.0 CDP Spac = 110 ft Figure 18 PS PHILLI ate ' 5 er -' F �s,° RO ; ,e c�v e= ONM ea NY Project: NPR/ g PHILLIPS PH J C e ,w 9 EI"BQ.PE�.��P @r (v ". �F,9€'6 S �Q9 Pore Pressure and Fracture Gradient System Well: Spark 8 10/13/2001 K. Heinlein NCTL: 152- 4.5e -5 Spark 8: PPG Predicted from Seismic Online 49993) (time) 752 -4S -505 PPG_T SPARK 8 Seismic:ALAYO EE5YI0 SW NE 1 ,,,,, " " " bbbb bp b bbb 4 bbbb' bbbb b b „ pp , bb bbbb 0 ' ' pbbbbb b ' b0 " b00 CDP 11 11 g 1 3 , 8g 0 3 b 33 0 38 28 33 3344434 4493336 Hi 54 5556 6 55 75589 660gg 66 6 p g ' 6 a 5 66 0 1 2 2 4 6 6 9 8 7788 9 9 0 0 1 1 2 2 3 3 3 6 9 7 7 8 8 9, 1 5g 3 4 6 6 7 8 1 1 2 2 8 3 4 g gg 7 7 88 9 9 7 p 0 5 3 0 0 6 0 5 0 5 0 6 0 6 0 5 ! — .- q13,!' 0 5 ' 5 0 5 0 5 0 5 0 5' 6 0 5 0 5 0 5' 6 0 5 0 5 0 5 0 5 0 5 5 0 5 0 5 0 5 0 6 0 0 6 6 0 5 0 6 0 5 2 PP5 0.0 2 5 u W« 11:1 t ”' 81 1 , a 4. y{ vE `, : { .. srg �� Ltd: A yl 3a' x ;<.ar�,m } e$Xw,7 ljp j € n,� . s+ rg " pir i c' .,«.. <'�"�r6i<,.,�x..:<,.�� 8,00 ,00.0 ". 4 '� � .'' ; h �� aa . ii� 1 5 7: v�r i 11 I 1a11 111111 1I11111 � II II I 1 1'1� �1 �� 1 � - 900 2000 1111111111111111111 11111■ 11111110111111 1111111111111111111111111111I1111111111111IMIIIII 1011III11111II1111I11111I111! 9.50 • 0 1 t/ �jj� ji Q j ( ] 1 1050 300 PO i 11 11 11/11111 1 117) 11111 1� 1 IIIIIIIf11111 f 1 1 11'711111 111111 1 IIII 1 111 11 11 1 1 1 ! ,1 I�1111�1 11 111 111 .12 .00 i 1 1 1��11111 l� 1 t l�lt 11111�11� 1111��11111 1 I ( _ 1 11 11 �1 1 500 j $ {� i j 1111 § { 4 * {j IIII III 11 IIII Ili 1 t 12.50 6000 11 � f1 ��}1xj�1�S�11 �1t2 ill .111 111�11i j }1 l)j(f��)� 7 IIII � 1j 1 �ri 1 111 + 7 .50 7000 �''r2; 1 111 6 • ? ?.� '�r ?3 11 1 �1 fill I JJ1ll 7)1 ?101111111 Ip 11 11 1 1 111 111 II 1O 11111 11ff101111 11 11 IIIII�1 111 —=;: 13 0 111 1 # 111 Illl ICI #�I II M 9 00 0 .0 A 1 111111 61 I I 11 1 tit C1��121 3 1 5� `.- ST1 11$CINI I I 4111 1111 1111 1 11 / ...._... e ,.,, 1 I I III . 111 11 011 1111111141 I I u I t o i s 6 l 11 111 lll'' 1111 11 1111 #111 # 111 1 11 IIII 1 1 I #1 111 1 I 11 17.50 r-- -17 1200.0 II 1IPJI JJ JII 1111111111 011111 f111I 111 1 11 .11111 I w l 1 I iii 1 = 1200.0 111 111111 l 1111I10I# I 11 1 ) 11 11] 111111 , .. IIIN 11 �]r , 1 1Y 1 # 1 130 IIII1 11111111111111111 111111 1 �1 11111 1 111 111 1 1 11 1111111111#1111 1 a 1� 111111I1l1111111I 1111#1 1 111111111111111 1111 11.01111111 11111II1111 11111 ll 1 I 11111 • . 1 � ifs cg 9 ## 9Ii ! #! 4ilR� # � ill # ! #$ o-w.s 1 if1... ?.�_ sa e �i ii 913104 I ' lsaoo a - .4 ) ...,ti RK . rr; <. .,. -,'' ))]1 '" ? rt "ti .. -) 07 _ l )E i f 1 t3 Y.efi �.1„11��1 �� 15°04 }��.1111111� 91 V i #+ttl " x w --1 , :.55 .,WIT .$.5 1 0 ttoo, j � �i� i.�s"� rte. -�<, _ ;.-� a�? ?�� 1000.0 i�S1 � 11 t �a fl .� . 1 % :1x111 1111.,11 11 1 1 1 1t *1 11#161 0141 111 /1111 111 11 l 11111 11 ii 11 it 1 C 11111 11 1 ,900. F .... .$s "i T?" 4 "411151 ' 41f ° 1414 11111 " V;44144414 : 1 1# 'a . 64 "' " ( � : ; .i . ' . 2000.0 it: 1 .a�. rp .K.a .4g.4ca>.z8...11,S �wz - 1.� Lral t* 11 s {tiaxara 4. 4t �m a lr S� :T c c ___._ <<� .y _ _ _ CDP Spacing = 110 ft Figure 19 PHILLIPS Project: NPRA < PHILLIPS PETROLEUM COMPANY Well: Lookout 2 `.. Pore Pressure and Fracture Gradient System Y NCTL: 155- 4.5e -5 10/13/01 K. Heinlein Lookout 2 (Inline 49540, Xline 10845) DEPTH (Datum sotto FEET MSL MSL r 7 C.. - -...": "T '.1 : • 211 -- - t.. 7 . 1- i 1000 - , . . _ • .r: - ... .. • .. it • -- -' —ter _ .1_ .,. -- -- --- - - - -' -- *-- ' , • 2000 -- . nom. -`"T. ! ;-.,.r (fli ; ' i; _..- - - - -�- - -- - - -- —;--- . - -- - _ -- 2000 • 3000 • 1 - -i =-- -- - - - --- • —_- f_. - i t - --+' - —_ . — -- -_ -- -- -- 3000 -: i dd .�■ f .era L, woo woo • f MV" ■ ii � I , ; t o mN j — _ - Nil 7. _ Dal • , '-; 1 i li i n 9 -_-_-_-_—.-_-_-4-_. i _ 3, R. i— ! r _— �— 5000 , _ . 1 , m mums . Is it _LI - ---_-: 1------ , 1 i ' r ____i r m .1. , f1 .1 ow mg..' jig _= - ! 7__ ° - ; . 111 NI ill . - • -- —� r _ _ ___ _ _ _ _ # __ , i ll i 1— - t 1 I .. '.. ___..1._ __ ..___.... _ -- - • _t f T u w f u� I i le IN Mi -- — ? — '— 7000 7000 _ ' , EOM uiuiS NO31 M _;_— . --F f -- -� F q �t� - I NM : . 1 U e �r� ao I — — - i -- t — , -1--- • r- s '1 . iy l. E nmuu: 'tii — � ) — +—_ _ 6000 8000 , : ' ' i l -i , r — — moo '� 40 60 80 100 120 • 140 160 180 6 7 8 9 10 11 12 13 14 15 16 17 NCTL Intercept d GL a 155 PPG Logarithmic slope s - 43e -55 a 155-45-50S PPG Z Figure 20 -e- 155-85-50S FG Y PHILLIPS Project: NPRA a . ,. PHILLIPS PETROLEUM GMPA Y Well: Mitre 1 ' Pore Pressure and Fracture Gradient System NCTL: 155- 4.5e -5 10/13/01 K. Heinlein Mitre 1 (Inline 49567, Xline 10712) DEPTH (Daum sett FEU MSL MSL t 4-.1-1 T 1— h_ -- - -� - loco l 000 F t ; . - - -- —_ 1' t- t :. Iii - ?.. - - .... - i - -� - -' t- - III . . i ;�' !- f , 2000 2000 I .: , - , _ _ _ -- -'-- - _ _ _ _ '_ - 4 - — _ - - -- --- - ---- —' • , { r' + ; �+ — — -- — — — { I � f� a000 fi !�I W , I, loll i _. 1 . i .. 00 _ _:.. } p >, I I - , • !1! HE UL EEO - ' -1- - ; -- - I 4000 E� ri ;a I � - — t I---- r-- r- - " - -, 4000 �'- ' - -' P ' - 1' - -- -"- -- - 1 ' - i - - - - - - 4. - - - ' - - 1 -- -- - -r - -- _- - - -_ : -- - -- BHP ,II MENENIIIMIN Br MI 1ggq��ppq�� . L am gm �!� ' -ilia - - -- - iiii n� f — 1 — ... - s000 20D I.IImmom ninon H7l H i ; - - _ 1 , litli. lgll!l i _ _ 1 f am :HA 1R hIUll y Mir If invamph 1 h'I III —l_ ' 1 I _ i 1 - 6000 .` ■! N MU i s MU i , 6000 N 1al r ° °Ep11un !Jl 5 H 115H 9 ml !>l�II N =H �N�� !i ry � 1 ll�� I � A � ll ,�lt11 _ 1— • 1911151111111 I • .1♦�a '' 1, RIBIHB 11 11 N i ar. I MUM M I! LISI ! I lu'IEn — 70 • 7006 L sums. f an �f � � — 1 I - - — ... . L ... 111111114111111B11111pm yp _ �'- --- -_ _- - - - i - - - l - - - - — *'-- --- .i_ _ _ L . . - _ _ DI•iJ IIIDe ul - I i 3 — -- I I.IIIU IIIIII IIHI i i I --t �- -� T y�7 ■p�=MVP fF1N —_� 8000 ileq_` 4- ---IOWA El i --- .7 .--- -i-- -_ -. �_. —_ . , ._ ÷....____, . °— 8000 ;jj;; � i�Ti iiiu Elul i _, , -:_:_ H !i! 7 ( 1•�� 8500 7 8 8500 40 60 80 100 120 140 160 180 6 9 10 11 12 13 14 16 16 17 NCTL bitoroe0t 155 PPG Figure 21 Lo Slope = - /5e-15 --e 155 -45 -505 PPG Z -6- 155 -45 -505 FG Z PHILLIPS Project: NPRA PHILLIPS PETROLEUM COMPANY Well: Nova 1 _.....-......_, , Pore Pressure and Fracture Gradient System NCTL: 155-4.5e-5 10/13/01 K. Heinlein Nova 1 (In line 49546, Xline 10562) DEP111(3elum sett° MSL) FEET MSL . MSL - --, --;--- ' ;•••• - 1-H 1 i . i 4 , - -.,1- ' -1- ' •-1- . ' . * ;- - I - ■ I . - 1 - -!- . ' ' ' t - N i it! I.. . . 1 i - , . t• i i' , ". I ■ . , ; .,,,,, --"- i - + -1- T - 1 - '''•-• -H , . ; 1---- --4 — , — ' - - --,---,—,-- ---t--- • .. ' -L-- i .i. :, ; ' , - .- -..- --,--- •. : ' ' : '•i ": 1 ." i i'''' ' 1:: ': - ! . , . 3000 . ; . : ' ‘• i : ' -i ■ ', ; 14 I 14!: • i • - - .- i -- -0 . _-2--,-. - - , 1 .-- , . 14 ' ---1---.---;- • ' , ' . --',.-- -±i trii I-- i--. , .- --i. i _ -. -', ■ -1 i . , , ! , i ', i 7 . : • , : 1 i . ; ' t i .. . . . • , 1 . ., • I I" • I : . . , . • i ii... , 1 2000 , 2000 : ' • t _ _ •.._;__,_t. . 1. - I - ..-7, -,-- , -': A- ---i-t+-4tii ___ — — , .. I _.J .1-- - --i - I : „ . __,_ ___,. - 3000 ---"--; 7 - ' 1 - -I-4- - iiii -A --,-- i . I -i-- . 3000 ilii, t ' 1 ' 4 i i-- -4------ --,-- —H--- - --i- - . .. .. . . . ... --1-- •-■- ,- , s , — •,-• i . I-1- - -,-- - - - -I 1+ 11 :+ ; h- . , -- ■ - i - . • ' - 1 • Insimismal many ui __. I — T F V I i t , 7 lore • , ,Fi --i . mu ---r-- -i- i --1 ---?-- i I -I-- f la irii Krill"' I -- 1 -I ____I________,__ —1,_-_-__ 4000 4000 „ ••••-1- I '. - ----1--;--i- -1- 1 -4 4.-. Eli lill --i-----i---, 1 4 ' 1 - 1 - - - -I ; - t - I--- . --i---1--.1 -----_. ! . .1_ rliviciritri. : Li Li .._ ... .'.. .. __ ..__ . 1 .......-.... .1..._ _ 1_ __._ 1 _ NY ii' i -I f I s , i r i — j 7 _ f__ , ___, -1- 6000 ... :. .,...., _ -- , il 41 ' .1 -, I- .1_ 1 5000 Figui .ratags ..inkflpe i 1 , 1 ......i . : , Li 4L_4 , L i --,;---1 " h. mug it il , ---L. -I_ -, - — ' ' it am ani 1 i -4 i - Ili 1 i i 71091111 ----t : ,.., .71 -- -I - 11.1111 OP ! ___Itiliki...reramih....1 '..... ....... ,......r........ niu nu . 6000 ---t I i imormamonaltl! maings itki.nota 1 ,■___ _i_________, i 1 1 ' 1 ,________ _ 11 , Moor 1111111111 IiiiIIIIIIMI i I , 1 , —1- ! 1 .! I • ; _ ...... _I : m7; II Intl Ell 1111111/11 1 ' ' - 1 - - 4 -L • i i i . ' . ' 1P ti l ; ;---- Ask.: , 1 am IA , ----1- 000 7000 U sill I ffAih f' V I f HIFI 1 . , 7 • . N Mil • i 1111411 1--- 'imossi 2 + - -11, _ , - -; -- - - - - - -i- 1-- SE 1 WI --;_ . ...4.. ITMEMBEItg - -----1- , 1 . -- ---- a000 i L -- 8500 8 °°° ' , wmfiragiminollamum ____J, ! _ e . .J -- .. . .. 1 • i I 1 . I -- --4- ' ■_____, 1 1 --1 . F-_- .. ,_______ t _____ 8500 -- - -- - - H'i -- -F W 1 40 60 80 100 120 140 160 180 6 7 8 9 10 11 12 13 14 15 16 11 Figure 22 NCTL Intercept sd Gl. wee PPG Logarithmic Slope o -43e-I5 -e-155-45-50SPPG Z -e-105-45-sos_FG1 PHILLIPS Project: NPRA {n " Pi ILLIPS PETROL—UM CO PAN" ,` Well: Nova 2 Pore Pressure and Fracture Gradient System NCTL: 155- 4.5e -5 10/13/01 K. Heinlein Nova 2 (Inline 49495, Xline 10610) MT DIM (Datum sdm MSL) L MSL I - -- - - - --- --� - - - - .; i I t i ; I, ' — - I - - + .. • 1 — {- . — +— 1.. • 1600 1000 T t -I. i t • U i fit, -� - - -_ • 2000 - - , , 3000 - + i s i } i I I! I }! i, till } , .. j i . ... } ..... I. _ _. I ; 3000 I � _ , -_ _ - s 1 i 4000 - - f - i I 4 - - � '' - 1 � 1 fi -- -- - -- - '-- -'--- -- - -. . .. � .__.__ Naer 1 luN(111 �_ ' - 7 - - - 1 - II--- - + --. 1 11111611 -- , ___:=, - — _ __ _ - { p — _I . 4. 1 [ 1 Be1:a ∎ � .. ■e ! Fi r ming .. , _ , w� ee. �� N0. IA.. .1 tN s000 - i ; �m �nenn w m t — 000 I ;. outi ttMI UM YI I � 6000 - -; i , !� l■NNleHtli[5f11[1111 t _ f 6000 — ■ ■ ■ ° ■ � Ue NM m�mmuil • wail I : — _ , y � T �HIi N lltHi�� , ■ IN a ■ m1 1 + . —_ {— } j_ t ■ �1 —f -- t ! _ r — I _ ■ a 111111H III 7000 _L il imi N pun ry --`-- --- t — - — — -- - -- — ---1- L 6000 , - o`m ` ■u e ► 1 ( 8500 40 60 80 100 120 140 160 180 6 7 8 8 10 11 12 13 14 16 16 17 8500 NCTL Intercept d GL =155 PPG Figure 23 Le rNh■Ic Slope s - 451-55 -e- 155 -45 -505 PPG 2 -0 155 -45 -505 FG 0 PHILLIPS Project: NPRA fl : , PHILLIPS PET OL Ii COMPANY Well: Oxbow 1 Pore Pressure and Fracture Gradient System NCTL: 150- 4.5e -5 10/13/01 K. Heinlein Oxbow 1 (Inline 49471, Xline 10461) DEPTH (UeYxn Rib MSL) FEET MSL MSL _ -- - t -- -- - - - -- - -- - -- ` -- -- - - -- -- - -- - -- - -- --- - --- _ - _ ____._ - -___ 1000 - 1000 E ._- - _ _ - t t i • 2009 _ -_ ' - - 1-_---4--- _..__ - -_ _ -_ _ - - 2000 _ _ _ _ –_ _ ___. -__ –__ .. 1 J - ` t I j -1 -I i.}- .I i ,- :l) - 1 - i' 1 - 1 ...- .... . . 3000 - _. ___ ._ 00 ----s-`-r-'--T' +-1- 't-f-'-t i t EEEFI -- -i-- ±--- s. _. - ... -... - r-- ---: --'- -- :-!- .� -.. - L_1 : #. -J -1 -T �.i� � - _ — 4000 _ - -'T -- - ie �� _ __ __ L.__ -; - __.___ __. r r - - i _ 1 UM I ._ -- - - — - F - -- - - t---- ; - - - -- 5000 5000 ._1 - _"" ;._ -.. 1 ! ` t _ 3 -- — _ - F _ 1- = = T -- _ f - - 1 ' .1.1..,,_ .. ` - poi .. - soon s000 °_# �s min a _ _ -- �' - —— i ■��/{�E g g g g g q r • — — � - - • - 1 . _ . _ !!/iEEEM 1EEECfI EI t 7W0 # -- } • i IIII :-..1- -- F = - ' - - - - { 7000 • r L!L^ - _ _.- - - 1 — i I -T _ -_-- - milli _____L - . mos mom vainum" t 8000 ' , I iElfEl>�16N - -� - _ - -_ • 8000 • 8500 _4_.....;__ ' ' F ~ � - - i i t ________H__ -r-- I -�— i - �&�i00 40 60 80 100 120 140 160 180 6 7 8 9 10 11 12 13 14 15 16 17 KCTL Intercept dm= 151 PPG Figure 24 LegeriTh -e micSlope=- 4So-15 - 151 45 - 50S PPG E -0- 152 -45 -505 FG PHILLIPS Project: NPRA PRHLUPS PETROLEUM COMPANY Well: Rendezvous 3 ' Pore Pressure and Fracture Gradient System NCTL: 152- 4.5e -5 10/13/01 K. Heinlein Rendezvous 3 (Inline 49607, Xline 10462) FEET DEPTH ([lah�m setlo MSL) MSL MSL , - _ __ -- -- --- I 1000 : . 1000 { _ L f : : -- • 2000 ' ' , :— .. - -- i . — ...n .� 22000 ' f l } 1 ; i ( .. T F_ ,...�.1.. 7 . # , i . -f.7..„.. f.7..„.. i. 1 . t; -}.... - ;. ... - ..._ 1 . _... - – – - /J I ' a --. '" - ' Emma r".1- M8 i — .. 3000 00 ( } -,-F • t. {... jll Ot t/ _ - ! .-_.:�_:- - -- -- - { - - f ('I -, t - } - i 4000 --_ '•— 1"T CI . `.1. u - k - -- 1 l i - - I -- - - - - - -- 4000 , _,... __ I I lik„, i_ t i ELI --E- i ii HIi - - ( .._... _ - —� i - - - j fi000 11 i ' i____ I , _ , , :±--- IN _ I li A . .1 1 1 i�Wii .._ }_I- mamma Mill 1 }-- 4 _ — i 1 , — i -- 8000 • !�. ■�nn u tuu' 1211E 1 + { 1 ' {■ua�; ■■■■ nn mum t o m + ° Ammo _ _ ittri-t 7000 E� E� , � � � � nn nE Rm. Hill � � '.: . 7000 �i�i�t i • iNnit#'EnlEiu___ °G I , ! ��. LiNwswom E�fs °m: ■�d .nnWIEEEE6WUlya _ l I _ _ 1 ��f ■m■I ffin N!N 4 - -- -.- F _ woo � ■nss�ann� l>r��nn : 8500 � � _...�_. se mi IUll! , , i .8600 40 60 80 100 120 140 160 180 6 7 8 9 10 11 12 13 14 15 16 17 NUL Intercept at G° PPG Fi(''1Ure 25 Lsgu■�micSlope — 4,60 -15 -0-- 152- 45 -50S PPG Z g - e - 152 - 45 50S FG Z 1 PHILLIPS Project: NPRA PHILLIPS PETROLEUM COMPANY" Well: Spark 6 Pore Pressure and Fracture Gradient System NCTL: 152-4.5e-5 10/13/01 K. Heinlein Spark 6 (In line 49800, Xline 10551) DEPTH(Delum setto MSL) ee, FEET MSL - :11 1 , - 1 -- . 1 - .. - -..-; i ct,---7141 7_17 '-• -- . --- ! -- 7.7. - .11 - 1:77 . i t:: _... - r_ mt . tT L .. ; . . . _ : :: ' . 1 i :. , - .. ._.1.-.,_ 1 „. i 1 • 1 , - ---!--- , +! ! . -; - •; 1000 1000 1 - - .--; - :- -' — — . . . , I -L • : 1 i I , ; ■ . t , 5 . ; i q - - . : , siamse i ; ' . ■ —, ; - rj 2000 ' . 2000 III .,.., 4 ,.___:_•.,.._:_.,..•:, ! ,..,„. , : : , . ■ =- ' ' t - : i • 1 . . s ... : ;I' ' ' • ' . ; - - =---:-.-: --- - --,--- -I-4-4-t- • 4 -; • - .-- • 1- - lin . .. - t --!-- 1 i-- i- ' I i 3000 4. : : • : . - ; ; - 3000 ' -L-_-4.----i--L --i-- -.'- lin __ ____1: -4-__-, ---- -7. , t -- '1 - r; 1 - 1 - r• t I MITIMI _ ' ; ' ' " ■ -----, ---"- --- .._ ' : " , _: ; ' . _;_i_i • r • : "IBM ( ___F_ -i-- ■ :PL- :-.-'-}- mige-A l T 4- j I ; -4- 1 4. 1 1. ; ; _. neg AIN ow = ____I i --- • —+- . . -4-- --+ , 4000 . I __.i . 4000 lag 4 ---__-4- ; L, --i----F . r i , , 1.R. i Hill It i m ifflu . _i__. -' i , , __‘___- _ i .,, Irani maisibil ------ __ -- — ■- I ---- - r--- — - _ --.--1-r-1- ,-,, -r4-. 111 .° 1 - 1 7 : - 1 1 I j 1:1 1 - . , _111 . .i , ;.i_ I. III I li,' _... .... . ..!_7i: I.- : L. 4 1 5000 ' 1 , 6000 i . - - l' ' i ______,i paqiciapim IIIII --I- • - I 1-- 1 _I + 1 . , .___...... i i ' 1 ■ =- - ---- M.ligia411 1 .',..'1111111P11 u 1 . , , milliiill :,, mop! 1 — 1 — a in I 1 .,„ TN I u „„, la . i +- .___. I ; , 6000 =MA rh: Numeseill litHi 1 • 6000 ' II ? 1111 1114 I Ili ; I - __i_.,_ --I-- ■ 1 .._ , _ we i I ----- -± A- _ ..,_ 7 4 '. - ' • " f - 4 V 1 ' '' 1 4 1 t" : 11 ' IP. - • ".'" - - —4-- - - ' 4 " - ---1- - -4 --- • --- -71-.- - -- 1-- • -1-: -,--- !. I — 7000 - 1 - r r' • ..(.1 1 1 -1 , 1 , tI, ili _ 1_ ._.. -1 ,.. -H . - I - 1 -. - 1 .- .. - ---i- - -4. - -- I --- - I-- • 1.- " ; - - _ ! .:1 t- t• -• • _1.1. 1.._1_1 4.1 ., .... 4 • i 1 i t ; _______,..4._ • ____;...____ +___ . r 5 • , I 5 711 - ' --'-- ' 1 ",-L V bi .1 . ._______i •i T- --! setz'ajMn -- 1 I -- 8000 ' ' _,. 1111 ._ 1 ----1----,- - - -,- ' ! !-H 1 --- -i- , --f l• - i- - ' - L - - - H - - 4 'H--! ', ._____1____ _ ___ — 40 60 80 100 120 140 160 180 6 7 8 9 10 11 12 13 14 15 16 1 , .t ,, I. i_ , ---f t--- —t---- —t ---1 -i— --t-- ----i asixi 8500 7 PPG NCTL Intercept at GL o S2 Logarithmic Slope o -4.5e-IS -e-- 152-49-50S_PPG Z -e- 152-46-506 FG1 Figure 26 PHILLIPS Project: NPRA PHILLIPS PETROLEUM COMPANY Well: Spark 7 Pore Pressure and Fracture Gradient System NCTL: 152- 4.5e -5 10/13/01 K. Heinlein Spark 7 (Inline 49912, Xline 10542) DEPTH (Mum setts MSL) FEET _ __..t-. _r._ - _L _. T . , , i h'? - ._ _ _ _1__ ___._1_ -..__ Y_- __� —_— -___ ___ __- - y . __... ! � . i i -- - 1- • • 1 — - -- -- - - —_ _ 1000 t : - i': ! -- - -, -- --' --- -- --- moo — -; --i-- • : - 1 : . AL -n. i--- --1 -4.- — , i- i ; _ - - rti-i -=' WM - i A i � - -- 1 — -T - -' 2000 • 2000 -- . . . , _ . —_. — ! - - -__ _ — r E I i 1 ft"_' �., — - -_1__ _ — , — —_ ? 3600 3000 ' ' ' gf I t _., . . 11: , .... In elitiM._ _____L: __ ___,___ 4000'- -' . - -- '- -' '1 -t---- - }.. .' - al in _ ! m i� a ■ i s n 1 {Itl i i Iltll , - I - - j - - ---- i i �- —4-1 mien t3 II ' ��1• O mi H HHEE`i114 11111 1 1 • H� f1■ HfiHHSHH81l1U1 /11NSi1 1 - 5000 5000 _ r - _ i � — ie IN i� i I ` .6000 . 6000 —i-1 MEN �mfn ma,' 11HU Inn — i _ _ _- -___ -- ! --- ---_ -- -- . ital. C III pp 1 - mi 7000 1 1i�au��a/Hi�ilfan i F� Y1u 7000 _ AIM mmHE . 4-- RI I 8000 ..i • • n� i � -- -- � .o . _ 1 J - 8000 El i dul 211 2112 NEl11111�ryyJ21tnf11 J 3 - ` 1 ` • I i I 1 . B l � ..... ( , - 8500 -- � 8500 40 60 80 100 120 140 160 180 6 7 8 9 10 11 12 13 14 15 16 17 NCTL IrterceDt al GL =152 PPG Logarithmic Slope - - lie-15 -e1- 102 -45 -505 PPG_2 Figure 27 X152- 45 -50S PG Z PHILLIPS Project: NPRA ,-- ,-- -1, PILIILLIPS PETROLEUM COMPAII\" Well: Spark 8 Pore Pressure and Fracture Gradient System NCTL: 152-4.5e-5 10/13/01 K. Heinlein Spark 8 (In line 49993, Xline 10500) MTH (Mem setto MSL) FIE/ MSL MSL . „ , . . 14 41111 h:i 1 F" ---i- ; ,- .• ,--.- 7 - t • . i -; : . ' '- -, .■-■ ' ; 7 - ,. --.. • - 1 : : -'• i i- : . , ._, i -,-- ! . : • • 1 • 1000 ' .-----:— -woo . • . ; ; ; 1 ;:i: :..1 i•1 . 1 , -------4.-- --:----- i.4 4- - :---. ---- --- --- . _ : --I , • j „_____. _,.. . ....,_ _ _1 , ‘.., ,-... A - 4.- • 1--- ;__ _____:. ! +-- : ---: I' ,_, -,-. . 2000 . ' . .1- ! 2000 ---.---- -1 . -- `. -;--.--:- -±; - --. — . - — - --- --- . . . , . • , i : ; : : . ; ■ ., ., '; . • . . ! . i I ; • ; I • • , : . ; I • j i • • - - - - 1 .1 Il •---!--- ' - ': _. i _. _i_ .. i . ____,._ • „ ,• --i - , : • ,_____ 3000 ' 3000 --- • — ,- —.------ I r ____I. I— - _.,_ -,- -- , ,-7r4-1-- . . .1 I 1 _ ____ _ t-._ . -1- ..:1 _ .__ _, • ..._i tl 111111 , i _,___ , ____ .; ,- • •;-; 1- 4 i '. - Tr ,11 er 1 -4 - 1 : -' 4-- , - - 1 ' -1. - . i - r„ • 4--;- - - 1 . hr -.1-4-1'. 111 : 4. ; ' il • I ! 1: .. . 4000 4000 ■ • 1 t1 ! IMMI 111 H• i • ____ 1 , IN I . -- I , : —I 1111 KII11111[11E11111 : i ninmins . • -1- u IBEIE 1 1- AM; Mikl; ------ ; . I • : 5000 • , I i . --- 5000 1 ff.L±._ rigiMPF 4- autE rithi 'i. .. i _ t i I ,-- . i ...1_ . , L — _...--i-: -; Tr_ — -.. 1 :-.1,- 1 - .1: • tht. . : lfi i ' r 1 ii -- - - r ___[ • IMME"`'Immagr, _"illiniall IliffidnINIm f : • I Ill11111=MIll immIllt•MililtillIfill7 111111.1m. 1 , , 1 6000 6°°0 I. ; _4_,_ gin i rr. i rn l nnimmiinnte 1 , , . '.....,...- • Rill Mihifilria MIN= I : • : _LI Dill ialliMIIIIIIIffi I I I -1 ------1-- i ! , sr E il...r o mon I _, . . . : -, —1 I _A__ , ■ 1 II ■ 'MI ---- . -it . 1 1111 1, I 1 i I 1 A - • I 1111 - 1' i r.. 114 - -- 1 - - - - - -: - ' 1 - - - • - ' - - - - — - l'. I ' 7000 . _1 _, „ 4 En 4 !. El l r 1A , - - --t r - . , ' t 1 .,. !I! 4 1-- 1 Ems , i p m , .. ism ril , / I : learl _ I ; & IIIU no &null& I I . r 1 i=- - - ■ L ham IIIIIIIIIIII ; — ' : --: I lisa IteljtJAMIRIDAI i_____ 111111•111111111 I 1 • • i - 8000 , , : : 8000 , „:: .,„ , • - ,: I pp 1 . 1 4- ; ; . 1 T H r i • TT; • " - t .,11...., _..1 . . . f - -i-: 1 --1--,-r- !VII +1,!: !;iy III , 8500 40 00 80 100 120 140 160 180 6 7 8 9 10 11 12 13 14 3 i - 1 . _ : -:.; _ _ ._ I .: ., 8500 15 16 17 NCTL Intercept it GL 452 PPG ' Logarithmic &lope x -43e-15 -0- 152-46-50S PPG 2 Figure 28 -G-152-45-500 FG 7 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs_ Inserts\Microfilm _ Marlœr.doc FRANK H. AfURKOJVSKJ GOVERNOR DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS 550 WEST 7TH A VENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE: (907) 269-8800 FAX: (907) 269-8938 ~,o{ June 2,2004 h' v1/ yÞ John Nonnan, Chainnan ()( ~ Alaska Oil and Gas Cons~rvation Commission p . ~ ..' 333 West th Avenue, SUIte 100 f ftXY Anchorage, AK 99501 0r Re: Extension of Confidentiality Lookout 1 (API 501032035900) Lookout 2 (PùPI501032041000) Mitre 1 (API 501032040900) Dear John; TW.c l~tt~r r~q\.1e~ti release of well n~ta ~nd inform~tiou a') appropriate on the ~bove-re.ferencp.cI wells.- Our request is made in accordance with temporary extended confidentiality terms granted by the Division of Oil and Gas and accepted by ConocoPhillips Alaska, Inc. (see attached letter). The extended confidentiality term expired.today, June 2, 2004, upon successful completion of the Bureau of Land Management's National Petroleum Reserve - Alaska Oil and Gas Lease Sale 2004. Data and information ftom the Lookout 1 and Mitre ~ wens, originally scheduled for disclosure on l\1ay 4 and May 21, 2004, respectively, are subject to immediate release. 1 Data and information from the ~ookout 2 well are scheduled for release on June 5, 2001. ----------- ..----_. _.- ----_.- Sinc9fely, i( '~¡:XV ,"// . . ~f'¡.'~1,-{ f--T é"._~1-~',,¿ {/( ~ Mark D. Myers II""'--Director Cc: James R. Winegamer, CPL Staff Landman ConocoPhillips Alaska, Inc. P,O. Box 100360 Anchorage. AK 99501-0360 @~ ,/ .. / \ \,¡ .'Develop, COllserve, alld Ellhallce Natural Resources for Presellt alld Future Alaskalls. " A11adarko Petroleun1 Corporation 1201 Lake Robbins Drive The \Voodlands, Texas 77380 Attn: John A. Bridges, Land Supervisor, Alaska u.S. Department of Interior Bureau of Land Management 6881 Abbott Loop Road Anchorage, AK 99507-2591 Attn: Colleen !-.1cCarthy. Fjeld Manager Attachment . .\ ---- - ------ - -~ -.-- ------ ConocóPhiiii ps Alaska, Inc. P.01/01 James R. Winegamer Staff Landman P.o. Box 100360 Anchorage, AI( 99510-0360 Phone 907.265.6914 Fax: 907.263.4866 I"'IRY-20-2004 09: 11 May 19,2004 Faxed and Mailed .1o.l- Od--7 FfECEIVED MAY 2 Ú '. ÃIIr.L... ¿ /"J I ''''''''.f'~~ . '~;:'~I Director Mark Myers Division of Oil and Gas Department of Natural Resources 550 West 7th Ave" Suite 800 Anchorage, AK 99501-3510 Fax: (907) 269-8942 Re: Extension of Confidentialit~' Lookout 1 (API 501032035900) Lookout 2 (API 501032041000) Mitre 1 (API 501032040900) ConocoPhillips Alaska, Inc. (nCPAl") has received your letter granting a temporary extension of confidentiality for the information from the above referenced wells until June 2, 2004. CP AI accepts the temporary extension of confidentiality provided that the Bureau of Land Management's National Petroleum Reserve - Alaska, Oil and Gas Lease Sale 2004 ("2004 BLM NPRA Sale") is held on June 2,2004 as cwrently scheduled. If the 2004 BLM NPRA Sale is not held on June 2, 2004, CP AI reserves the right to request an extension of confidentiality for the infonn tion fronl the above referenced wells until after the 2004 BLM NPRA Sale is held. uL2es R. w::1~J ~ ~~;Landman u.s. Department of Interior Bureau of Land Management 6881 Abbott Loop Road Anchorage, AK 99507-2591 Attn.: Colleen McCarthy, Field Manager ... . . ... ... ... . . : . : . : . : . : . : . : . : . Alaska Oil and Gas Conservation Commission ::::::::-:::::::333 West 7rh Avenue, Suite 100 ! ~ ! ~ ! ~ ~ : .~ Anchorage, AI.as~ 99501 . .:.:.:.:.:.:.:.: Attn.: COlllIIl1SS10ner John Nonnan, Chairman ... .. ... . . ... ... . . , . . ... . . . . ... . . . . . . . . . . . . ... ... -;; r{ C? - o"l 5" c{ ,;t Anadarko Petroleum Corporation 1201 Lake Robbins Drive, The Woodlands, Texas 77380 Attn: John Á. Bridges, Land Supervisor, Alaska TOTRL P.01 ) ConocJPhillips TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Librarian or Howard Okland AOGCC 333 W. th Ave, Suite 100 Anchorage, Alaska 99501 RE: Lookout 2 Permit: 202-027 DATE: 05/18/2004 Transmitted: CDROM Digital well test data Lookout 2 Halliburton Surface well test report; Test #1; April 8 to April 13,2002 Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. To all data recipients: All data is confidential until State of Alaska designated AOGCC release date Data marked proprietary is indefinitely confidential and is available only to owners and partners "On behalf of itself and other owners. ConocoPhillips Alaska, Inc. submits the attached data for the Lookout 2 Well. Drilling Permit No.202-027 as specified in 20 AAC 25.071. We request thai this dala be held confidenlial as reqUired under AS 31. 05.035(c) and 20 AAC 25.537(d). This data is from federal lands. 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." R E C E I V E 0 CPAI LEGAL 2/4/2004 MAY 1 8 2004 CC: Greg Wilson, CPAI Geologist L{ ulLJ Recei pt: Return receipt to: Date: Alaska Oil & Gas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. ATTN: S, Lemke, ATO-1486 700 G. Street Anchorage. AK 99501 Prepared by: Sandra D. Lemke ConocoPhillips Alaska, Inc. Global Information IT-Tech Data Management 907.265.6947 Sandra. D. Lemke@Conocophillips,com FR4NK H. MURKOU.Sf:! GOVERNOR '- . : i:.~':- L DEPARTl\'IENT OF NATlJRAL RESOiJ<~--L- .~ES I~'f-._._L DIVISION OF OIL ANf3. GAS. ...1 - ...--".. I ¡i~.;'.... . .., ,_. ~- . 550 WEST 7TH A VENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE: (907) 269-8800 FAX (907,1 269-8938 ¡ :- ~i', .. 1- -. -'. , ":." " .,,-- .. .....-. .;¿Od - O~ 7 CERTIFIED I\'IAIL #7002 24\ 0 0006 2052 3143 RETURN RECEIPT REQUESTED "" . - '! ,- _._0'-""'.'.' Ric hard P. l'vlott ConocoPhillips Alaska, Inc Vice President, Exploration and Land P.O. Box 100360 Anchorage, AK 99501-0360 .-.'" -'''--'- ; ....--"'--'- . ---. -.-'-" RECF'J\/ED W,þ,) 0 fi 2004 DECISION OF THE DJRECTOR Alasl':a 0;; u Gó~ ~...JI¡~. I..ummission Anchorage RE: Request for Extension of Confidentiality under AS 31.05.035 and 11 AAC 83,153 Lookout #1 API 501032035900 Lookout #2 API 501032041000 Mitre #1 API 501032040900 I am responding to your April 28, 2004, letter requesting extended confidentiality under 11 MC 83.153 for wen data, Teports and infol111ation generated from the three above-referenced wells and filed with the Alaska Oil and Gas Conservation Commission under AS 31.05.035. On April 9, 2003, ConocoPhi11ips Alaska, lnc submitted a similar request to extend the confidentiality period for these wells (and others) beyond the normal 24-month term. In my April 21, 2003, reply 1 requested that you resubmÜ any subsequent request by March 26, 2004, so the Division could evaluate the information in the context of activities up to that time. You did not do so, instead filing your request only five calendar days prior to the disclosure date of the well information. Nevertheless, 1 am approving a temporary extension of confidentiality for the infonnation from these three wells through Wednesday, June 2, 2004, during which time ConocoPhi11ips must make a showing under 11 AAC 83.153 that the well data and infol111ation currently protected from disclosure contains significant information related to the valuation of unleased land. Please contact the Division as soon as possible to arrange a meeting for this purpose before Monday, May 24,2004, so that the Division can issue a decision by June 2, 2004, regarding any fUl1her extension of the confidentiality period beyond this temporary thirty day period. By copy of this letter, I am notifying the Alaska Oil and Gas Conservation Commission of this temporary extension of confidentiality for thes-€"three weBs. ( .. ~ A person affected by this decision may appeal it in accordance \',;th 11 MC 02. Any appeal must be received within 20 calendar days after the date of "issuance" of this decision, as defined in 11 AAC 02.040(d) and (d) and may be mailed or delivered to tvlr. Tom Irwin, Commissioner, Department of Natural Resources, 550 W. 7U1 Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1-907-269-8918, or sent by electronic mail to dnr appeals(li)dnr.stJte.ak.us. This decision takes effect immediately. If no appeal is filed by the appeal deadline, this decision becomes a final administrative order and decision of the department on the 3151 day after issuance. . ---l '-- \' \ , \ r \ ~ . . , \ " ,', : I, - ('\ > ~ \'. "", ~ "/ -' '. .', /. ' >' '~\ "Del'elop, COllserve, alld Ellhallce Natural Resources for Present alld Future Alaskans. " An eligible person must first appeallhis decision in accordance with 11 AAC 02 before appealing this decision to Superior Caun. A copy of 11 A..AC 02 may be obtained from any regional infonnation office of the Department of Natural Resources. Sincerely, ~:9~ l\1 ark D. t-,-lyers, Director Cc: Chair, AOGCC J. Landry, DOL J, Cowan, DO&G M. Crosley, DO&G DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 Permit to Drill 2020270 Well Name/No. LOOKOUT 2 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20410-00-00 MD 8200 TVD 8200 Completion Date 5/5/2002 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: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Logl Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Fnnt Number Name Scale Media No Start Stop CH Received Comments -- ---- --- -- ------ ----------- 'ED C v11227 Gamma Ray 1 110 8200 Case 6/25/2002 ~t See Notes 7894 7927 Open 12/20/2002 C" . '- ~ "\"J~ (c' ~. "~,1 t-: I I Log See Notes 2 Col 108 8200 Open 5/1412002 Formation Log ~. See Notes 2 Col 108 8200 Open 5/14/2002 Formation Log ~-' . ,/ Log () I Log See Notes 2 Col 108 8200 Open 5/14/2002 DML - MWD Combo Log flOg See Notes 2 Col 108 8200 Open 5/14/2002 Drilling Dynamics -Ç!J>g c..see Notes 2 Col 7850 8050 Open 5/14/2002 CMR DMRP Processing ~Og ,Sonic 5 Col 7350 8184 Open 5/14/2002 _: Log / Gamma Ray 5 Col 7350 8184 Open 5/14/2002 ~D C '1"f114 See Notes 7895 7950 Open 5/14/2002 DSI Best DT I rED D . - Directional Survey 0 8200 Open 5/14/2002 , Rpt Directional Survey 0 8200 Open 5/14/2002 :-ED C '-11110 See Notes 7902 8195 Open 5/14/2002 Open hole edit containing AIT I Platform Express I CMRlDSI/FMIIMDT I I ¡ED C 1..0-1-1111 See Notes 7820 8054 Open 5/14/2002 Processed CMR data and : displays I ! 1,/ ; ED C V11112 See Notes 7894 7930 Open 5/14/2002 Digital Core Photo Images I I l..." ED C '-11113 See Notes 7894 7928 Open 5/14/2002 SWC and Conventional I Core Descriptions ...,. ,ED C /'11115 See Notes 110 8200 Open 5/14/2002 Final Well Report L-Rpt --sëe-Notes 110 8200 Open 5/14/2002 Final Well Report - - ----- --- ----- ----------- ---- --- ------- DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 Permit to Drill 2020270 Well Name/No. LOOKOUT 2 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20410-00-00 MD 8200 ND 8200 Completion Date 5/5/2002 Completion Status P&A Current Status P&A UIC N Well Cores/Samples Infonnation: - - -- -- ------ - - ---- Interval Start Stop - -- -. ---- 8200 7930 Sent Received Sample Set Number Comments Name -- --- ---- - -- -- --- ------- --- ---- -- ---- -- - ---- ----- - -- .- - ---.- ----- --------- - -- -- --------1 I I Cuttings Core Chips 108 7894 1069 - 1069 ADDITIONAL INFORMATION Well Cored? & N Chips Received? (Jy N Analysis GN Received? Daily History Received? GIN ~}N Formation Tops - -- -- - - ------ --------- -- --- -- --- ---- ----------- --- --- - - --- -- -- ---- ---". --- -- - --- ---- -- ----------- ---- Comments: - -- -.-- ------- ----- ------ -------- ---------. -------------- ----- ------ ----- comPlian~e Reviewe~~~; --=------~ ' ( --- - ---- Date: - --7--CZ ß.( Á..lfu-1-'\ f/lJlAIA--~ ~ ConocoPh ¡IIi pS Alaska, Inc. '?- ~, ,0 Ie? Richard P. MoU Vice President Exploration & Land P.O. Box 100360 Anchorage, AK 99510-0360 Phone 907.263.4556 ... April 28, 2004 Tom Irwin, Commissioner State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Ave., Suite 1400 Anchorage, AK 99501-3510 RECEIVED APR 2 8 2004 Re: Request for Extension of Confidentiality Alaska Statute 31.05.035 and Regulation 11 AAC 83.153 Alaska Oil & Gas Cons. Conrnission Anchorage ConocoPhillips Alaska, Inc. ("CP Al"), as operator for and on behalf of the working interest owners ("Lessees") of the wells listed in Attachment A hereto ("NPRA Wells"), requests extended confidentiality for the reports and information generated from the NPR-A Wells and filed with the Alaska Oil and Gas Conservation Commission as required by state law ("Data"). All of the NPR- A Wells are located on federal lands located within the NPR-A and not adjacent to any state lands. Lessees make this request for the following reasons: (1) the Data is important to the Lessees in evaluating acreage in NPR-A that will be subject to the Alpine Satellite Development Environmental Impact Statement ("Satellite EIS"); (2) the Data for the NPR-A Wells constitutes trade secret information, which is protected from public disclosure under federal law and state law; and (3) the Bureau of Land Management, which is the federal lessor and administrator of the leases on which the NPR-A Wells are located, has not determined that the Data should be disclosed to the public. First, the Data contains proprietary and sensitive information relating to the valuation of land within the NPR-A. The final Satellite EIS will be issued in July of 2004. The Bureau of Land Management ("BLM") will issue the Satellite EIS Record of Decision in August of 2004. The Satellite EIS Record of Decision will significantly affect the way NPR-A federal oil and gas leases in the area are developed, including those on which the NPR-A Wells were drilled. Disclosure of Data to the public, which Data was obtained at the sole risk and at substantial expense of the Lessees, prior to release of the Satellite EIS Record of Decision, could be detrimental to Lessees' competitive position in NPR-A. Commissioner Irwin Request for Extended Confidentiality - NPRA Wells April 28. 2004 Page 2 Second, the Data constitute "trade secrets, II which are protected from disclosure under both federal and state law. See, e.g., State v. Arctic Slope Regional Corp., 834 P.2d 134, 138 (Alaska 1991). In State v. ASRC, the Supreme Court of Alaska addressed the question of the validity of the provision in AS 31.05.035 that allows the Department of Natural Resources ("DNR") to review otherwise confidential data as part of the process to obtain extended confidentiality. The court in that case, however, expressly did not opine on the question of whether such trade secret data could or should be disclosed to the public without compensation, and in fact, specifically distinguished its decision from other decisions that addressed the public disclosure question. 834 P.2d at 144. Other courts have invalidated requirements in state laws that require the trade secret data to be disclosed to the public. For example, as cited in State v. ASRC, the Supreme Court of Wisconsin invalidated such a requirement in Noranda Exploration. Inc. v. Ostrom, 335 N.W. 2d 596 (Wisconsin 1983). Similarly, the United States Court of Appeals recently invalidated a Massachusetts statute that required tobacco companies in Massachusetts to disclose the ingredients of cigarettes to the public. Philip Morris v. Reilly, 312 F.3d 24 (Ist Cir. 2002). Similarly here, where the DNR has the authority to recognize and protect trade secret data from lands that the state of Alaska does not own or manage, the DNR should find that extended confidentiality is watTanted based on the facts of the situation. Third, the Data was generated on federal lands under federal oil and gas leases issued and administered by the Bureau of Land Management. Federal statute 5 USC 552(b)(9) exempts "geological or geophysical information and data, including maps, concerning wells" from the right of public inspection and disclosure provided in the Freedom of Information Act ("FOIA") at 5 USC 552(a). The NPR-A lease terms under which Lessees leased the lands on which the Wells were drilled states as follows: During existence of this lease, information obtained under this [section 5] shall be closed to inspection by the public in accordance with the Freedom of Information Act (5 U.S.C. 552). Paragraph 2, Section 5, NPR-A Lease Form, a copy of which is attached hereto as Attachment B. The Bureau of Land Management has not determined that the Data should be made available to the public under FOIA. The Bureau of Land Management furthermore has not determined that the criteria used by the DNR in determining whether to agree to extended confidentiality are reasonable, appropriate, or applicable to wells drilled within the NPR-A. The public interest considered for federal purposes extends much farther than the state of Alaska, and the federal and state interests may not be and often are not the same. The Alaska Oil and Gas Conservation Commission's authority over federal lands for environmental and conservation purposes cannot .8, impermissibly conflict with federal law, and the DNR's authority here is similarly limited. To disclose the Data to the public before the Bureau of Land Management has determined that it may be disclosed to the public and without the express written agreement and concurrence from the Bureau of Land Management creates an unnecessary, direct, and impermissible conflict with federal law and policies. The Data should be granted extended confidentiality as requested in this letter. Commissioner Irwin Request for Extended Confidentiality - NPRA Wells April 28. 2004 Page 3 Lessees request that the DNR find that the Data should be granted extended confidentiality until at least 90 days after the date the Satellite EIS Record of Decision is issued. If you have any questions or require any additional information, please call me or Mr. Jim Winegamer at 265-6914 and we will atTange a meeting to review this request in more detail. - " Richard P. Mott Vice President Exploration & Land cc: U.S. Department of Interior Bureau of Land Management 6881 Abbott Loop Road Anchorage, AK 99507-2591 Attn.: Colleen McCarthy, Field Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Attn.: John Norman, Chairperson V State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Ave., Suite 800 Anchorage, AK 99501-3510 Attn.: Mark Myers, Director Anadarko Petroleum Corporation 1201 Lake Robbins Drive, The Woodlands, Texas 77380 Attn: John A. Bridges, Land Supervisor, Alaska .: Commissioner Irwin Request for Extended Confidentiality - NPRA Wells April 28, 2004 Page 4 A ttachment A Extended Confidentiality ReQuested for the followin2 NPRA Wells Well Name Permit to Drill API Number Data Release Date Lookout 1 202-003 501032035900 05.04.04 Lookout 2 202-027 501032041000 06.05.04 Mitre 1 202-026 501032040900 05.21.04 Commissioner Irwin Request for Extended Confidentiality - NPRA Wells April 28. 2004 Page 5 Bc: B. Fullmer, ATO 2084 J. Winegarner, ATO 1468 EXHIBIT B .. .'ITED STATES DFf'"'1t.. .,..ø:!:NT OF THE INTERIOR BiÏlrl.U OF LAND MANAGEMENT ALASKA STATE OFFICE OFFER TO LEASE AND LEASE FOR OIL AND GAS mal No. .. . . () -. M-081801 The undersigned (reverse) offers to lease all or any of the lands in Item 2 that are available for lease pursuant to the Mineral Leasing Act of 1920, as amended and suppleJllCIlted (30 U.S:C. 181 et seq.), the Mineral Leasing Act for Acquired Lands of 1947, as amended (30 U.S.C. 351-359), the Attorney General's Opinion of April 2, 1941 (40 Op. Atty. Gen. 41), or the Naval Petroleum Reserve Production Act of 1976 (42 U.S.C. 6501 et seq.), as amended. READ INSTRUCI'lONS BEFORE COMPLETING 1.. Name ARCO Alaska, Inc. (78%) P.O. Box 100360 Anchorage, Alaska 99510 and Anadarko Petroleum Corporation (22%) P.O. Box 1330 Houston, Texas 77251 Street City, State. Zip Code 2. This applicationlofferllease is for Public Domain Lands in the National Petroleum Reserve - Alaska (NPR-A) Legal description of land requested: *Tract No.: 991~H-049 .Sale Date (mldly): May / 05 /1999 *SEE INSTRUCI'lONS BELOW PRIOR TO COMPLETING PARCEL NUMBER AND SALE DATE T. R. Meridian State Counti T10N, R2E Umiat NE 1/4 Amount remitted: Filing fee $ . Rental fee $ 28.780.00 Total aaes applied for 5.756 Total $ DO NOT WRITE BELOW THIS LINE 3. Land included in lease: T. R. Meridian State County T10N, R2E Umiat NE 1/4 Total acres in lease 5.756 ReDial retained $ 28.780.00 ThIs lease is issued granting !he exclusive right to driD for. mine, eXlJact, remove and dispose of aD !he oil and gas (except helium) in the lands descn'bed in Item 3 together with the right to build 8Dd maintain oeœssary improvements them1pcm for !he tenD indicaœd below. subject to reaewal or extension in accordance with the appropriate leasing authority. Rights granœd are subject to applicable laws, !he tenDs, condiûoos, and IIUached stipulations of Ibis lease, the Secretary of the Interior's regulations and formal orders in effect as of lease issuance, and to regulatioas and formaJ orden herea1'Ia promulgaœd when not inconsistent with lease rights granœd or specific provisions of this lease. NOTE: This lease is issued to the high bidder pursuant tohislher duly executed bid or nomination form submitted under 43 CFR Part 3130 and is subject to the provisioos of that bid or nominaûOllBDd those specified on this fonD. 1be parties agree (1) that this lease fonn replaces the previous lease form executed by the parties for this lease; (2) that this]ease wiD he deemed to have been issued pursuant to this lease fOlDl; (3) that this lease wiD be deemed to have been execuœd as of the original date each party executed the previous lease form; and (4) that the effective date of this lease is September I, 1999. THE UNITED STAlES OF AMERICA . Type and primary term oflease: by ] Noncompetiûve lease (ten years) ] Compeûûve lease (ten years) ~J¿) ~ Sr. Leasable Minerals Adjudicator res iCT' ( X] Other Compeûûve NPR-A Lease (ten years) (TItle) ~IIIIIIIIIIIIIIII 201 7 2002.000248.0 (Date) EFfECTIVE DATE OF LEASE September I, 1999 AK-3130-1 (April 1999) ," - 4. "(a) Ynllersigned certifies !bat (1) offeror is a citizen of Ihe Un!¡,.d "'ates; an association of such citizens; a municipality; or a corporap""'. 'rganized under the lawl of Ihe United StaleS or of any SIB;; .Terrilory thereof; (2) aU parties holding an inleJeSI in Ihe otTer~. )liance with 43 CFR Part 3100 and the leasing authorities15.. )15 not considered a minor under Ihe laws of the Stale in wbich She lands coverod Þy this offer are located. 0 . . '. (b) Undersigned agrees thai sipature 10 this offer cons .- acceptance of this lease, including aU tenns, conditions, and sti.. ODS of which offeror has been given notice, and aøy amendment or - separate lease thai may include any land deacribed in this offer open 10 leasing althe time this offer was f1ted bul omitted for any reason from this lease. The offeror further agrees thallhis offer cannot lie . withdrawn, either in whole or in part. Thia offer wiD be rejected and wiD afford offeror no priority if il is not properly completed and executed in accordance with the regulations, or if il is not accompanied by the requiIed payments. 18 U.S.c. Sec. 1001 makes it a crime for any person knowingly and willfully 10 make 10 any Department or agency of the United States any false, fictitious or fraudulent slatements or æpresentatioDII as ID any matter within ilS jurisdiction. AUTHORITY: 50 Sial 900; 25 U.S.C. 500 The Privacy Acl of 1974 and the ægulatioDS at 43 CFR 2.48(d) provide thai you be furnished with the following information: NOTICE PRINCIPAL PURPOSE: The primary uses oflhe records are (I) to determine your qualification to receive an oil and gas lease; and (2) to provide information concerning oil and gas leases for administrative and public use. . . ROUTINE USES: BLM and Ihe Department of the Interior (DOl) may disclose your information on this fOJ1D: (I) to members of the public who have a need for the information thai is maintained by BLM for public æcnrd; (2) 10 Ihe U.S. Department of Justice, court, or other adjudicative body when DOl determines the information is necessary and relevanllo litigation; (3) 10 appropriate Federal, Staœ,locai or foreign agencies responsible for investigating, prosecuting violations, enforcing or implementing this statute, regulation, or lease; and (4) ID a congressional office when you request the assistance of the Member of Congress in writing. EFFECI' OF NOT PROVIDING mls INFORMATION: H you do not furnish aU the information required by this form, your application may be rejected. Duly executed this clay of ,19 SEE ATIACHED SIGNATORY PAGElS) (SigDature ofJ..essee or Attomey-in-fact) LEASE TERMS See. l.ltaItaIa" Rad8IJ obaII be p8Id 10 Ibe !lOp« ofIiœ of Ieuor in adv8uce of each Ieuo year. AJlDuairentol - per .,.. or fnodon Ibeaeof - (I) NOD<OIIIpOIitive Ieuo, $1.50 ror Ibe lint 5 Y""; tbae8fIo< $2.00; (b) CompeIitiw Ieuo, $1.50; for Ibe lint 5 yeua; IboreafIa $2.00; (c) OIboa-, - ~ or for NPIt-A: $S for Area A: $3 for Area B; IS opecified in die dobåJed -- of Ale. If tbia ~ or . poIIÍOD Ibeaeof ia c:òmmiaod ID aD appnJ>eII coopenIiw or llllil pIaD wbIcb indadea . weD c:apobIe of poducIDc Ioued - llllllibe pIIII COIIIaina. JIIO'ÙIOD for aIIocadon of productioD, JOyaitiea abaIl be paid OD !be prodac:tioo allocated 10 IbiJ ba Howevu. ........ .-. abaIJ c:ontilraO 10 be due at Ibe raœ 8Ìec:i6od in (8),(b). or (c) fordlOle liliiii- widlin.~ aIeL F IiJure 10 pay ......... mdaI, witbÏII 30 daya aftor teœipI of . Notiœ of DeIinqueIIcy abaIJ cause Ibia ~ 10 temIÍDIIe. ltaIIaIa may be waMcI, øcIaœcI, or .....-w by Ibe ~ 1IXID . aufficia>I abowiD& by Ieuee. See. 2. Royab:iea - RoyalIies abalI be paid '" !lOp« oftioe of Ieuor. Roy8lûcs abaIJ be c:omputed in accordao<:e wiIh ¡qaIadaIII OD prodactioD nmned or..1d. Royaky ruIoa - . (8) ~ve Ieuo, J2~; (b) CoIqJeddve Ieuo, 12~; (c) OIbet, - anacIIIœ8, ar for NPR-A: 1~ for Ana A: 12.5~ for Area B . opec:iIiod ill Ibe doIaiod - of... 1Moor ...... Ibe ri8bl1O opecIry wboIber royrIty ia 10 be p8Id ill nIue or illlånd, llllllibe ri8bl1O CIIabIiah reuoDlble DiamJm nJueo OD prodocu aftor pvq -- IIOIice II1II .. opportaDiIy \0 be bemL Wboa paid in Y1IIuo, royaIIIea abalI be due II1II payable OD Ibe IaaI day of Ibe D*h mllowio¡ Ibe ID>IIIh ill which puducIion oa:aned. Wboa p8Id in kiad, podudioD aIIalI be deIiwnd, ...... O\berwiae a¡reed \0 by Ieuor, in morc:baDIabIe coødilioo OD Ibe pnoIisea wbon: IIÐCIuœd wiIbDaI m. 10 Iouot. LeaRe abalI DOl be nqllired 10 bold IIICh pmcIuctioo ill IIOIap beyoDd Ibe IaII day of Ibe IIIOIIIb mllowiD¡ Ibe DI>DIh ill which puducIion e><:eumod, DDr abaIJ Ieuee be lIeU liable for baa or deoIraètioo of 1O,.,tIy oil or othoo: prodocu ill IIOIap Iiom - beyood \be reaaooabIo CODIIOI of Ibe --- . MiDiDaIm lOyally ill Iiou of tmtal of DOl loss IbID Ibe RIlla! which O\berwiae would be ICCUired for lbaI!oue year abaII be payable Blibe oDd of each ~ year be¡iooias DO or oller . diaco>el)' ill paying C1I8DIiâes. This miDImm1 lOyally may be waived, IUSpeodecI, or Iedaœd, lllllibe abo... JOyaky raIe8 may be reduœd, lOr aD or portioos of Ibis Ieaae if Ibe Sec:maty cIeIemioea IbaIIIICh aeIÏon ia œcouary 10 CIICOUlIe \be greateII u1\imaIe ro<:o>ery of Ibe Ieued - or is olbenriae jaoti6ed. AD iDterest c:barge abaIJ be aueaed OD late lOyalty paymeou or \IIIdapaymoDII in acconlaDœ with \be Federal Oil aod Gas RQyaIty MlII8gemeol Act of 1982 (FOGRMA) (30 U.S.c. 1701). LeaRe sbaD be 1iabIe mr royally >II)'I\IODtS 00 on I11III g..1o1l or wasted Iiom lloaae lite whelllllCb 10.. or wllsle is due 10 DegUg....., 00 Ibe pan of Ibe operator, or due '" Ibe failure 10 IX>IqIIy wilh.., I1IIea, regaIatioos, order, or cilllioo issued uDder FOGRMA or \be leasing auIborily. Sec. 3. BoDds " A hood sbaD be filed IIIIII\IIÌDIaiDOd Ibr Ioaae opera1ioos as roquimI UDder reguJatioDS. See. 4. DiJigax:e. rate of develollllODl. wùtizaIioo, I11III draioa¡e - lasee sbaD exercise fCasooable diligeoce in developiDg aod pn>duciDg, I11III sbaD pre-1IIIDCCCIIIU}' damage 10, loss of, or wllsle of leased JeSOun:e.s. Lessor reaenes \be right 10 specify Mco of dewlopmenl aod prodw:lloo iD Ibe public interest I11III10 require Ie.- 10 aubscn'be 10 I cooperative or uoiI plao, witbin 30 days of DOtìce, if deemed oecessary for proper dewlopmeol aod operllioo of area, IieJd, or pool emIncmg Ibeae leased Iaoda. Leuoe abaD drill aod produce wells œcouary to protect leased lands &om draioage or pay m~ royalty lOr cIrainoge ÌD IIIIDUOt delelmÎllOd by Ioaaor. See. 5. DocumooÞ. evidmœ, oDd iDspe<:tioo - Leuoe sbaD fiIo with properoftioe orloaor, DOl later IbID 30 d8ya"" etrecti>e dale Iboreor, auy m- or evidmœ or othoo: ~ for .. or diapoaaI of podac\IøIL At aucb limos oDd ill aucb tbnn as Iouot may pre8Cribe, Ie.- aIIalIlUmiIb deIaiIed -Ibowio¡ 8D>1IDU II1II quaIiIy of aD products remoYCd I11III sold, proceeda Ibadiom, lIIIII_œl1ued forprodu<:\ioD parpoIC8 or-idIIIIJ 1oS\. lasee may be required 10 provide piau oDd acIIoaMIIJc cHaar- abowio¡ deveIopIoeø wm. and a...v .---. and reports with Raped 10 parties in iDIeresI, expeDdiIurea, and cIenciadoD COllI. .m Ibe 10... pacribed by Jc8w. Ie.- sbaD keep . daily driIIiDg record, . log, ioIimDatioo .. well --.eya laid -. II1II I .-- of aab8arfaIo8 ÌDves\Í8a1Ìo111 aod fiøDisb copies 10 Ieuor wbeø reqaBed. LesMe IbaII bep opeD . allUIIODII>Ie IåDoo for ~ by auy IUIborized officer ofloaaor, Ibe leased pnoIisea lIIII.aD""" /aJpowaadl,lIIII:IiDoIJ,laId IiIIuna ~ and aD boob, ......... maps, and reamIa RIaIM 10 opentio8a, mneya. or ÌDWIIIi8IÌODIcm or iIIlbe IeaøI ...... LesMe sbaD maiDtaiD copies of aD CODb1ICta,"""-" --. ncorda, 1IIII-.,#"""..IIICh. bi1Iiap, invoicea, or similar documentllioo IhIIIVpport œIII dIìmod . ~ JRI*IIIIoo, aadIor InIIIpOnadaa mIlS. AD aucb recorda sbaD be IDIÌDIIIÌD...f ÌD Ie.-'I IICCOIIIIIÌIII eftioe i>r ÑI1Ire audit by Ioaor. LeaMe .... IDIÍDI8ÌD required recorda Cor 6 years oller !bey are pœrated or. if aD audit or ÌDves\Í811io0 is uDdetway, UDIiI ftIoued of Ibe obIipIioa 10 I\IIÌDIIIÌD IIICh recorda by Ieuor. Duria¡ e>dstmœ of this Ieuo, iDfonnIIIoo ob\aiDed œder Ilia ICCIÍDD aboII be doted 10 iaIpectioo by Ibe paI6c in acconlaDœ with Ibe ñeaIom of Information Ai:;t (5 U.s.c. 5$2). See. 6. Cooduct of operatioDs - LeaRe sbaD amduc:t optntioø ill. -- -1IIÌIIÌDJiZiO8 od- ....... 10 die I8d, air, I11III Wiler, 10 C1IIturaI. biological, \'ÍIUal, II1II othor _laid 10 O\b&'r load -- or..... ~ abaII... reasomobIo ............ deemod œcouary by Ieaaor 10 ICCOIII>IIab Ibe IoIeIII of Ilia IOCIÏDB. To Ibe - mDlÏsla>l with ~ rigIø graoted, aucb - may iIIdude, !Jut are _1iaIiIed 1O,IIIDCIiIicaIIoa 10 aIdøa or deaip of faciIitie&, timiDg of openIÍDDI, and IpCCificaIiOD of iaIaIm II1II fiDaI........ -- Le8Jr ........... Ibe ri8bl1O c:otIIÎDUe aIMiDg -- aod 10 8IIIIIorIzo ÑI1Ire -- ....... or iD Ibe Ieaaed IIaada, iDcIadID& ... opproval of -. or rigbu-of-way. Such -- ..... be 00IIdIIi0IICd .. .. 10 ~.......,. or --"Ie ÏD/eIfInIK:e wilhriglø of--- . Prior 10 CÜSIurtJiD Ibe IIIñace oflbe Ieuod Iaoda, --.... _Ioaor 10 be IIp]riIed ofp0c:edure81O be IOlIowed and DPCIiIicaIioDl or ...Iamatioo - - may be 1ICCCI8J. Areaa 10 be dishatJed may require iDveDIOriea or lpeclal otudie8 10 detcmIine !be - of ....... 10 O\b&'r reao- LeaRe may be nquired to complete minor iDYCDIoriea or abort IeIDI opeciaI otudie8 œder pIdeIiaCI proWled by Ioaor. If iIIlbe CODdUCI of openIioDs, IbreaIeoed or endangtn:d apecIoa, objec:u of bi8IcIi: or aciadific iaIeRII, or subalanlial ~ eoviroDlDOllIal etm:Þ are 0"""'-1. Ie.- sbaD immediately c:ooIacIloaor. LeaRe abaII- auy openIioøa ... would renk iD Ibe cIoIIractiDa of aucb IpCCiea or ol;ocu. See. 7. Milling opera1ioDS - To Ibe ""teDllbaI ....... &om IIIÏDiII operatioDl would be aubaIaodaDy díIfereDI or greater tbaD thole lIISOCiated wilb DOrmai driIIiDg openIioDs, Ieaor -- Ibe rigbllO doøy IIIIIOvai of IIII:b operllÏoos. Sec. 8. Exlrlctioo ofbo6um - Lessor reserves Ibe optioo of extractiag or having ""\rICled belitim ttOm gas productioD ÌD I JDIIDDCI' specified and by meaos provided by lessor II DO CJ<peIISC or IoISIO Ie.- or owoer of \be gas. ~ sbaJI iDclude ÌD l1li}' cootrlC\ of sale of gas Ibe pro.tsioDS of this aectioD. Sec. 9. DlIIDIIgco to property - Lessee shaD pay Ieuor for damage '" 1euo(1 impro>eølCDlS, and sbaD saw aod hold lessor harmless Iiom aD claims for damage or harm 10 perIODS or property as I reouIt of lease operllÏoos. See. 10. Proœctioo of diverse ÌDteres.. and equal opport1IIIÌty - LeaRe abaII pay whell due aD _!ogaDy assessed aod levied under laws of \be State or \be UDited StateI; accord aD eoØ>yeea mmplote freedom of purchase; pay aD wages at least twice each IOOttth iD IawflllIOOIIc)' or \be United Swes, DllÌDtlÌD I safe wortiD¡ eoviroDlDOlll in accon:laD<:e wilb Slaodard iDdustry pncticea; and take -1IOCCII8\}' 10 prolCCllbe boaIth aod safety of \be public. . ~IIIIIIIIIIIIIIIIIIII 3 of 7 2002.000248.0 '. . . -LeŠaor resoneI tbo riaJt to ....",.. tboI prodUCIÏoD is IOId IlJeaso~ . - prevent rmnopoly. If Ieasee openreo 1 pipeliDe, or OWDI coduofliDc in_I in 1 pipeIiœ or 1-;;;:;1.. JoputtiD¡ 1 pipeliDo, which fillY be J openred ICœIIibIo to 00 derMd from tbose loosed 1Imds, Ies..e IbID comply with oecIioD 28 of the MiDonI 'Le1SÌD¡ ~ of 192°: Laaeo IboD co...,1y with BucIttm Order No. 11246 of SeptenØr 24, 1965, U IIIIODIIed, ODd regulalÏoDl ODd ",Iimor orden oftbo SecretoryofLobor iuued pumIIIII tboreto. NeItber...... DOr """'s aubeoDlnll:fOfllboD DIIÙIII8ÌD segregated fociIiIieL DuriD¡ the perfolfDlDCe of this Ieue, the Laaeo DIIII comply fully with pongnphs (1) drouøh(7)of41 CFR 60-1.4(1) wlthreapecl to omployrDtDI dilcrimiDalÏoDOD the bosiJ ofrace, color, "'lisioO, - 0' DllÎODII orialo. ood DIIII iDcorporale the requinmJeollsel fonb in tOO.. plrll!raphs in every subcontract or purc:hue order, u provided by tboI..guIatioo. Sec.11. TfIID.Ifer of ~ ÍDIen>Ita ood n>IiDquisbmeol of"'" - Ao IO<uired by ..gulatioos, ...... IboJ1 file with Iosoor any usi¡rImeDI or other InDafer of ID ÌDIeIeII in Ibis...... Lessee moy relinquish this leue or IDY legll IUbdivisioo by fiJiDg in the proper office 1 written "'liDquisbmool, which IboD be effeclive u of the date of fiIiDg, IUbjecllO the CODtinued ObligalioD of the Ieasee ood """1)' 10 po)' all accrued rentals ood royallies. Sec.12. Delivery Of........n ....Iœ u all or ponioDi of this ..... ore reI1IJœd 10 Jouor, ...... ÙIIIII pIIÞI affected wells in co;¡;.,~. - ~D or lbaDdoomeDt. n>oIaim the I8Dd .. apecißod by Ieuor 8Dd, witb8 t reasoD8ble period of time, remove equipment md ÎD¥Ovemoota DOl deemed ooceaaary by Jouor for ~ 01 producible wells. Sec. 13. ProceediDgs in cue of deflult - If...... rails to comply with lID)' provillom of this Ie-. aad .. DODCOmpliaDce coDtioues for 30 days ofter writteo DOtice thenor, this ..... IboD be abject to etmœII8IIoø ItII1eII or lIDIiI the leuehold CODtaioI 1 wen copable of production of oU md gu in poyiDg IUIDIÏIioI, or the Ie8æ ÍI comnitted 10 ID approved cooperative or unit plan or colDDlDitizatioD agrccmcot which coolaiDs 1 weJI c:apab1o of prodUCIÏoD of unitized SUbsl8DœS in p8)'ÌD& qUIDûlies. This provision IbaU DOl be coDStnled to preveot the exOtCÌIe by IeMar of IDY other legll md equitable remedy, iDc1udios wllver of the default. AI IIICb remedy or waiver IboJ1 prevent laIer C8t1CeIJalioD for the some defaub occurriDg at lID)' other time. LesIee IboJ1 be subjecl 10 applicable provisioos ood penalties ofFOGRMA (30 U.S.C 1701). Sec. 14. Heirs ODd SUCCUIOfI-iD-inte...1 . Bleh oblisalÏoD of this leue lboJ1exlend 10 md be biodiD¡ uPOD, md every benefit he=f IboJ1 inure 10, the hein, e""",,lOra, admiDistratora, successofl. bendiciaries, or UÓigooeI of the respective ponies hereto. INSTRUCTIONS A.General 1. The front of Ibis form is to be completed only by panies filing for a noncompetitive lease. The BLM will complete front of form for all other types of leases. 2. Entries must be typed or printed plainly in ink. Offfrol' must sign Item 4 in ink. 3. An original and two copies of this offer must be prepared and filed in the proper BLM State Office. See regulations at 43 CPR 1821.2-1 for office locations. 4. If more space is needed, additional sheets must be attached to each copy of the form submitted. B. Special: Item 1 - Enter offeror's name and billing address. Item 2 - A single tract number and Sale Date shall be the only acceptable description. Item 3 - This space will be completed by the United States. PAPERWORK REDUCTION ACf STATEMENT The Paperwork Reduction Act of 1990 (44 U.S.C. 3501 et seq.) requires us to inform you that: 1. This information is being collected pursuant to the law. 2. This information will be used to create and maintain a record of oil and gas lease activity. 3. Response to this request is required to obtain a benefit EFFECf OF NOT PROVIDING INFORMA 110N . If aU. the iDformatioD Is not proflded, the offer may bÙejected. See reguJatiom at 43 CFR 3130. ~IIIIIII mllllllll'~1 4 of 7 2002.o0024a..G AK-3130-1 (April 1999) .. - ~ 0' (), SIGNATORY PAGE FOR U.S. DEPT. OF INTERIOR B.L.M. OFFER TO LEASE & LEASE FOR OIL & GAS SERIAL NO. AA-o81801 ARGO ALASKA, INC. Lessee's Signat e James M. Ruu Attomev-in-Fact Lessee's Name (Print or Type) & Title THE UNITED STATES OF AMERICA STATE OF ALASKA January 31. 2000 Date ARCO Alaska. Inc. Company Name ) ) ss. ) This certifies that on the 31st day of January, 2000, before me, a notary public in and for the State of Alaska, duly commissioned and sworn, personally appeared James M. Ruud, to me known and known to me to be the person described in, and who executed the foregoing lease, who then after being duly sworn according to law, acknowledged to me under oath that he executed same freely and voluntarily for the uses and purposes therein mentioned. WITNESS my hand and official seal the day and year in this certificate first above written. ~\\ \ \\\11111/11111111/ ~ ~ \.A/J~ ~ ~"-A ..'.........';'(/ ~ ~~;"'~~'" ~ ~ ~..'c!" '" ... ~ ;¡¡¡¡ :l' ítþ$" ~ is sa : .,..10 ~).::: - . ~'" C . ....= ~ \ ~~L1 i '"'"~ ~ ....l'~v Ã,,'~~i! ~* '" ~8~"~~ ~ d'~~......~..~ \,'f ~ ~III%'~~ \\\\ø ~ w. 4~ Nota ublic My Commission expires: 6-8-2003 ~I ~mlll~ II'I'~~II'I 6of 7 2002.000248.0 .. - . J . . , . () C} . SIGNATORY PAGE FOR U.S. DEPT. OF INTERIOR B.L.M. OFFER TO LEASE & LEASE FOR OIL & GAS SERIAL NO. AA-081801 ANADARKO PETROLEUM CORPORATION -~ø Lessée'sSignatu Todd L. Liebl Aaent and Attomey-in-Fact Lessee's Name (Print or Type) & Title January J' . 2009 Date Anadarko Petroleum Corporation Company Name THE UNITED STATES OF AMERICA STATE OF 1.EXAS ) ) ss. ) This certifies that on the !}6 fh day of Januarv. 2000, before me, a notary public in and for the State of Texas, duly commissioned and swom, personally appeared Todd L. Liebl, to me known and known to me to be the. person described in, and who executed the foregoing lease, who then after being duly swom according to law, acknowledged to me under oath that he executed same freely and voluntarily for the uses and purposes therein mentioned. WITNESS my hand and official seal the day and year in this certificate first above written. DAYNA L DRYDEN :.A.; NOTARY pUBLIC .."'JIIIIi~ State of T eJC88 eomm expo ()8.08-2002 ~) cf! Iik~) ota Public My Commission expires: 9-g -CJt¿ ... !IIIIIII~ Ilmllllllll . of 7 2002.000248.0 .. .< . . , .. . f - . .. . . . . . () (yi SPECIAL STIPULATION S FOR LEASE AA-O81801 Standard Lease Stipulation Numbers 1-24,26-28,30,32,34-38,40-44,46-48,51,53,55-79, as identified and delineated in the Final Record of Decision and Detailed Statement of Sale, pertain to all leases created from t,he National Petroleum Reserve-Alaska Sale 991, and are herein incorporated by reference and made a part of this lease. The following Special Stipulation(s) is/are specifically delineated in the Record of Decision and Detailed Statement of Sale as pertaining to this tract, and is/are hereby made a part of this lease. This/these is/are a direct quote(s) from the Detailed Statement of Sale .document. All references to Exhibit A pertain to Exhibit A of the Detailed Statement of Sale. No part of this lease is identified as Exhibit A.: m. The "No Permanent Oil and Gas Facilities" and "No Permanent Oil and Gas Facilities within 1/4 mile ofFish-Bearing Lakes Stipulations," Number 39, are identified on each specific tract in Exhibit A hereof. They pertain to some of the tracts in both Area A and Area B. IIIIIIIIIII~ 111111m~11 7ot 7 2002.000248.0 DATA SUBMITTAL COMPLIANCE REPORT 4/15/2003 Permit to Drill 2020270 Well Name/No. LOOKOUT 2 Operator CONOCOPHILLlPS ALASKA INC ;/,,~J API No. 50-103-20410-00-00 :.¡ ,v' , ,. , ~~l ,<t t /! oj :} ~..... MD 8200 /" TVD 8200./- Completion Dat 5/5/2002' Completion Statu P&A Current Status P&A UIC N -- - -- -- --.-- --- ---- -- ----- - -------- ------ - --- ---- - -- - --- --- --- REQUIRED INFORMATION Mud Log Yes Sample -We- "I ).../J- - - Directional Survey Yes -- ------- -.----------- - .-------- ---- - - - -- ----- ---- - -- ------ ---------- ------------- --------- DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Logl Data Digital Digital T~Pÿ1yl~~ ._--~.!!1~ --- ---- Name ~fr- Dir Directional Survey ~ Dir Directional Survey Log Log Run Interval OH/ Scale Media No Start Stop CH ~ved -------- 1 0 8200 Open 4/2002 0 8200 Open ~2002 7902 8195 Open 5/14/2002 Dataset Number Comments ----- ~C Cn See Notes ~C Cn See Notes ~-C Cn See Notes ~ Cn See Notes ~ Cn See Notes Rp!..,../ Cn See Notes L~ Cn See Notes ~.." Cn See Notes ..M'" Cn See Notes ,W" Cn See Notes ,~ Cn See Notes ~ ~onic La GR Gamma Ray :~C Cn See Notes :l.EIr'"--- C GR Gamma Ray Rpt Cn See Notes - - - - -- - ------ Well CoreslSamples Information: ~1 0 Open hole edit containing AIT I Platform Express CMRlDSI/FMI/MDT 7820 8054 Open 5/14/2002 ~1 Processed CMR data and displays 7894 7930 Open 5/14/2002 ~ Digital Core Photo Images 7894 7928 Open 5/14/2002 ~ SWC and Conventional Core Descriptions 110 8200 Open 5/14/2002 '~ Final Well Report V- 110 8200 Open 5/14/2002 -Fínal Well Report 2 Col 108 8200 Open 5/14/2002 ¿,.W'mation Log 2 Col 108 8200 Open 5/14/2002 ~ation Log 2 Col 108 8200 Open 5/14/2002 I.81VIL - MWD Combo Log 2 Col 108 8200 Open 5/14/2002 L.BfíÍÍing Dynamics 2 Col 7850 8050 Open 5/14/2002 ¿c.MF(ÓMRP Processing 5 Col 7350 8184 Open 5/14/2002 5 Col 7350 8184 Open 5/14/2002 7895 7950 Open 5/14/2002 UJ.~14 DSI Best DT 110 8200 ~~ ß/25/2002 e,;..1227 7894 7927 Open 12/20/2002 - ---------- ------ - ----- --- Permit to Drill 2020270 MD 8200 TVD 8200 Name D{'i~ ~, C L\-~ (" ADDITIONAL INFORMATION Well Cored? L,~ I N Chips Received? &1 N §)N Analysis Rp.r.p.ivpr? - - - - - - - -- - - - - - - -- --- - - ------ DATA SUBMITTAL COMPLIANCE REPORT 4/15/2003 Well Name/No, LOOKOUT 2 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20410-00-00 Completion Dat 5/5/2002 Interval Start Stop , Î.I S ~ ),_ù~ Completion Statu P&A Current Status P&A UIC N Received Dataset Number Comments [uýc{ Sent I _i ~, IJI ,~..-Jl t. S .uJ . Daily History Received? cYJN "'" WN r; :~- 1......:(. ,"' c. Þ I " '. '. '.-- t. -.. c--'- û,,'lIJ-::JAf.1i' VI 11'( Þ (J " ".~',./I. ~ '- ~ Formation Tops -. -- ---- - ---- - - --- ----------- ---- ----- - ---- - --- -- - -- ------- ------- ---- Comments: TÚk <fi~ KJ-<J.'p-~ ------ -- ..:....-.--=-..:=---==--=-=--:=----=-==-=---= ----7-/--- Compliance Reviewed By: - ----- -- _..._~- ----- - - - ---- Date: ~~ I 6 d...¡1- .?ò.c~ - PHilliPS Alaska, Inc. A SUbsh;,ary or PHilLIPS PETROLEUM COMPANY TRANSlVIITTAL CONFIDENTIAL DATA FRO].\t(: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Lisa Weepie AOGCC 333 W. 7th, Suite 100 Anchorage, Alaska 99501 RE: Lookout 2 PERMIT 202-027 DATE: 12/20/02 Delivery: Hand carried Transmitted herewith is the following: Lookout 2 (501032041000) Report ~core Labs, Core Analysis Results, Lookout #2, CL 57111-02045; December 13,2002 Please check off each item as receive~ sign and return one of the two transmittals enclosed to address below. "On behalf of itself and [name other owners].ConocoPhillips Alaska, Inc. submits the attached data for the Lookout 2 Well. Drilling Permit No. 202-027 as specilied in 20 AAC 25.071. We request that this data be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the use of the Commission in carrying out its duties. we question whether any future disclosure to DNR or the public would be appropriate or valid. However. it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure. so that we may be heard on the issue." cc: David Bannan, CPAI Geologist Receipt: Return receipt to: d--- -, G.1k;, r -.-J Date: ,~-- ;;"O-D;;} ConocoPhillips Alaska, Inc. AlTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Prepared by: Sandra D. Lemke CPAI - GIS TDM ,~ ~~ ~,,:"" [ore Lab ¡OEÏiluLEUtl ~rAVIl¡'; AOG ~t CORE ANALYSIS RESULTS PHILLIPS ALASKA, INC. "LOOKOUT" 2 COLVILLE RIVER SW FIELD ALASKA CL FILE #57111-02045 Performed by: Core Laboratories 3430 Unicorn Road Bakersfield, CA 93308 (661) 392-8600 Final Report Presented December 13, 2002 Petroleum Services 3-1 =..(, Ijr".: .:,rr, R.,:.j,j 8 je'07r; 11':-1,) C jld,:,rrll,j '~, ~~,I),?, T~I ~,(I~I. =f~.:.-t¿')(1 Fj., ,3(1~,- :j':~'?~(it,2...J , . :. .. ':'~lr¿;'1 :JL:I ,:I:.rÍl ,~L)¡-d - [>.;.; -¡ ClB II:Imm f~'.J ~i S E TABLE OF CONTENTS SECTION DESCRIPTION OF SERVICES 1 CORE ANALYSIS DATA - TABULATED RESULTS 2 HYDRAULIC UNIT ANALYSIS RESULTS 3 PROFILE PERMEAMETER RESULTS 4 TRACER ANALYSIS RESULTS 5 CORE GAMMA 6 INTRODUCTION Phillips Petroleum Company selected Core Laboratories to provide field handling and analytical services for cores recovered from the subject well. Core laboratories personnel handled the core in the field and prepared it for shipment to our laboratory in Anchorage. Services provided at the Anchorage facility included core gamma surface Jog, core sampling, slabbing, permeability profile and core photography. Drilled sample plugs, plug end-trims, and several mud samples were forwarded to Core Laboratories' Bakersfield location for analysis. Standard porosity, permeability and fluid saturation determinations were performed on all horizontally oriented samples. Vertically oriented samples were tested for permeability only. The mud samples and a number of horizontal plugs were designated for Iodide tracer analysis. Sample end- clippings were cleaned and forwarded to Geologies in Dallas, Texas for thin-section preparation. Presented herein are tabular presentations of the gamma surface log and pressure-decay profile permeameter testing performed in Anchorage as well as the results of the analyses performed in Bakersfield. In conjunction with the report, the core analysis results are supplied in Excel format on floppy diskette. We appreciate this opportunity to be of service and hope these data prove beneficial in the development of this reservoir. DESCRIPTION OF SERVICES - ANCHORAGE Core Gamma Surface Loq Each core was scanned for natural gamma radiation utilizing Core lab's gamma spectrometer. The resultant gamma plot was forwarded to the Bakersfield for digitizing. Total gamma radiation is reported in API units. Core Samplinn and Slabbing After the surface gamma log, a sample segment approximately three tenths of a foot long was taken from each foot of core for sampling. The remaining core from each foot was slabbed parallel to the core axis utilizing a one/third - two/thirds cut. Isopar mineral oil was used as blade coolant and lubricant for core slabbing. The one/third slab sections were mounted in slab boxes with Styrofoam inserts for photography, and to facilitate core viewing, description and sample selection by Phillips' representatives. Sample Preparation - Anchorane Both horizontally and vertically oriented one-inch diameter plugs were drilled from each of the three-tenth foot core sections taken for sampling. Isopar mineral oil was used as the bit coolant and lubricant for the routine sampling and cold nitrogen vapor was used as the bit coolant for drilling tracer analysis plugs. Each of the drilled plugs was trimmed to a right cylinder, weighed, wrapped with Saran wrap and aluminum foil, and sealed in a sample jar. Once all of the requested samples had been taken, the plugs and end-clippings were packaged and shipped to our Bakersfield California facility. DESCRIPTION OF SERVICES - BAKERSFIELD Sample Preparation - Bakersfield The plugs were received wrapped with Saran wrap and aluminum foil and sealed in plastic sample jars. Upon receipt, each sample was weighed and that new weight was compared to the weight that was recorded in Anchorage prior to shipping. The samples were then unwrapped, labeled, and reweighed. To prevent sample loss during processing very friable or fragile appearing samples were mounted in tared thin-walled metal jackets with 120-mesh stainless steel end-screens. The sleeves and jackets were seated under hydrostatic loading at 1000 psig Sample end-clippings were batch cleaned in soxhlet extractors using methylene chloride and then forwarded to Geologies in Dallas Texas for thin-section preparation. Fluid Extraction Water and the oil were removed from the samples by Dean Stark methods using toluene as the solvent for a minimum of twenty-four hours. Dean Stark extraction was deemed complete when the volume of water collected in each individual receiving tube had stabilized. Complete hydrocarbon extraction was accomplished using soxhlet extractors with a 70:30 methylene chloride/methanol mixture as solvent. Fully cleaned samples were taken from the soxhlets and placed in a convection oven at 2300F to drive off residual solvent. After a minimum of twelve hours and after weight stability was verified, the plugs were removed from the convection oven and cooled to laboratory temperature in a desiccator. Grain Density Determinations Grain volumes were determined by Boyle's Law double-cell methods using an extended range helium porosimeter. Where applicable, metal jacket and end-screen weight and volume corrections were applied. Grain density values were calculated using Equation 1. 8ma = Where: cSma = Mg Vg Mg Vg (1) = Matrix (grain) density (glee) Grain mass (g) Grain volume (cc) = Porosity Determinations Direct pore volume measurements by Boyle's Law double-cell methods were performed upon samples confined at 400 psig in Hassler-type core holders. Porosity values were calculated using Equation 2. ~ = 1 ' p -lOa - (Vp + ¡.~ )- (2) ~ = Porosity (0/0) Vp = Pore volume (cc) Vg = Grain volume (cc) Where: Fluid Saturation Calculations Oil and water saturation results were calculated using Equations 3 and 4. So Sw = ( '" ( ,,- AI f - AId - AI to - ~ - 100 ðo ) \. Vp ) - (3) \. = ~ - 100 V - p- (4) Where: So Sw Mf Md Mw Vw = Oil saturation (0/0) = Water saturation (0/0) = Fresh sample mass (9) = Clean, dry sample mass (9) = Water mass (g) = Water volume (cc) 80 = Density of oil Vp = Pore volume (cc) Permeabilitv to Air Steady-state permeability measurements were made immediately after the pore volume determinations. Permeability values were calculated utilizing Darcy's Equation for compressible fluids, Equation 5. Ka = -(PaevgelOOO)- - QaeL 2- - 'e Mep 1(~ (5) Where: Ka = Permeability to air (md) Pa = Atmospheric pressure vg = Gas viscosity (cp) ð-P = Differential pressure p = Mean pressure Qa = Flow rate (cc/sec) L = Length (cm) Vb = Bulk volume (cc) Hydraulic Unit Analvsis After rock property measurements had been completed, a hydraulic unit analysis was performed. Reservoir quality index (average pore throat size) and pore ratio values were calculated for each of the horizontal samples using Equations 6 and 7. RQI = 0.0314 .~~ (6) PR = cþ [1- <Þ] (7) Where: RQI = Reservoir quality index Ka = Permeability to air (md) ø = Fractional porosity PR = Pore ratio RQI and PR values were used to group the samples into hydraulic units. Each hydraulic unit represents a unique pore geometry relationship and provides the foundation for the integration of core and electric log data. The results are presented sorted by sample depth, and by hydraulic unit; to facilitate selection of representative samples for any additional testing. Tracer Analysis Potassium iodide was added to the drilling fluids as a tracer. Mud samples were collected periodically during the coring. A mud press was used to obtain water samples from the mud for tracer analysis. The extracted waters were filtered, bottled, labeled, and kept chilled until they were shipped to Metrohm Peak in Dallas, Texas for chemical analysis. Sample plugs designated for tracer analysis were first analyzed by Dean Stark methods. Final cleaning was done using toluene rather than methylene chloride to avoid leaching of the iodide tracer. Following the standard PKS determinations, the sample plugs were crushed and leached with distilled water. As was done with the samples obtained from the mud, the plug leachates were filtered, bottled, labeled, and kept chilled until they were shipped to Metrohm Peak in Dallas, Texas for chemical analysis. Metrohm Peak analyzed each sample for its chloride and iodine content. The results of analysis are used to try to quantify filtrate invasion in the core. Pressure-decay Profile Permeameter (PDPK) The PDPK determines permeability by unsteady-state methods using a transient "blowdown" technique, A tank of known volume is first filled with nitrogen and then the gas is discharged through the core sample to atmosphere. The decaying tank pressure is monitored versus time, which allows determination of gas flow rate and pressure drop across the sample at any given time. The automated recording of flow rate versus pressure differential provides the data necessary for calculation of a Klinkenberg- corrected permeability as well as the permeability to air. The results of analysis are reported in tabular format and on diskette in Excel format. Sample Disposition Sample plugs to be returned to ConocoPhillips Petroleum in Anchorage under separate cover as per ConocoPhillips' instructions. " Phillips Alaska, Inc. CL File No. : 57111-02045 å ,>.¡ .&F "Lookout" 2 API No. : 50-103-20410 ,!. . v,-"' .." #~, . 'é1 Colville-River SW Field Loc. : Sec. 25- T11 N/R2E Care Lab Core Analysis Results Sample Depth Perm. (Kair) Porosity Saturations Grain Description Comments No. Hor. I Vert. Oil I Water I Total I OIW Density tt md md % % % % Ratio glee Permeabilities were determined by steady-state methods, pore volumes by Boyle's Law methods. 400 psi confining pressure was used for pore volume and permeability measurements. 1 7894.2 3.35 1,20 19,5 33.6 41.0 74.6 0.82 2.68 Sst brn vfgr slty dk stn gld flu '-' 2 7895.1 14.1 0,341 22.8 24.6 25.9 50.5 0.95 2.68 Sst bm vfgr vslty dk 8tn gld flu 3 7895.5 0.049 6.6 61.4 33,0 94.4 1.86 3.01 Sst brn vfgr V81ty dk 8tn gld flu 4 7896.1 0.603 0.566 14.8 50.2 19,5 69.7 2.57 2.68 Sst tan vfgr vslty m stn gld flu Tracer 5 7897.1 9.18 0.184 21.4 33.6 31.6 65.2 1,06 2.68 Sst dk brn vfgr slty dk stn gld flu 6 7898.1 12.0 0.727 21.2 44.8 23,5 68.3 1.91 2.67 Sst dk bm vfgr slty dk stn gld flu 7 7899 3 6.77 3,07 19.9 27.5 29.2 56.7 0.94 2.68 Sst brn vfgr vslty dk 8tn gld flu Tracer 8 7900.1 10.5 5.42 21.0 42.8 26.2 69.0 1.63 2.68 Sst dk brn vfgr sslty dk stn gld flu 9 7901.1 21.4 6.83 22,1 37.4 30.1 67.5 1.24 2.68 Sst dk brn vfgr slty dk 8tn gld flu 10 7901.7 0.080 13.0 15.8 64,6 80.4 0.24 2.98 Sst brn vfgr vslty dk stn gld flu 11 7902,3 13.0 3.23 21.7 25.6 27.6 53.2 0.93 2.69 Sst brn vfgr vslty dk stn gld flu Tracer 12 7903,1 16,8 4.36 21.1 33.2 29.4 62,6 1.13 2.68 Sst dk brn vfgr sslty dk 8tn gld flu 13 7904.1 25.4 5.07 17.1 48.4 46.4 94.8 1.04 2.67 Sst dk bm vfgr sslty dk stn gld flu 14 7905.5 8.33 1.84 20.3 22,4 33.3 55.7 0.67 2.69 Sst brn vfgr slty dk 8tn gld flu Tracer 15 7906.1 9.56 3.60 19.9 42,0 26.4 68.4 1.59 2.68 Sst dk bm vfgr sslty dk stn gld flu 16 7907.1 13.1 2,36 20.4 39,1 34.7 73.8 1.13 2.68 Sst dk brn vfgr sJty dk stn gld flu 17 7908.5 12.3 4.75 20.8 23.3 32.1 55.4 0.73 2,69 Sst brn vfgr sIty dk stn gld flu Tracer 18 7909.1 15.0 4.99 19.3 37.7 25.9 63.6 1.46 2.68 Sst dk brn vfgr sslty dk stn gld flu 19 7910.1 16,8 4.16 20.4 37.1 27.6 64.7 1.34 2.69 Sst dk brn vfgr sslty dk stn gld flu 20 7911.5 11.4 3.19 18.8 23.2 31.2 54.4 0.74 2,69 Sst bm vfgr slty dk stn gld flu Tracer 21 7912.1 50.4 69.3 20.7 39.4 27.2 66.6 1.45 2.68 Sst brn vfgr vslty dk 8tn gld flu 22 7913.1 59.4 43,8 19.9 46.2 16.7 62.9 2.77 2.87 Sst brn vfgr vslty dk 8tn gld flu 23 7914.5 112. 77,3 22.6 30.7 19.2 49.9 1.60 2.74 Sst brn vfgr slty dk stn gld flu Tracer 24 7915.1 94.9 55.6 22.8 46.2 13.7 59.9 3.37 2.70 Sst brn vfgr vslty dk stn gld flu 25 7916.1 90,8 12.4 22.2 48.8 11.6 60.4 4.21 2,66 Sst bm vfgr V81ty dk stn gld flu 26 7917.6 0.078 0.633 11.8 32.6 33.0 65.6 0.99 2.70 Sst tan-gry vfgr vslty sh It strk stn gld flu Tracer 27 7918.1 0.079 0.218 12.8 50,6 29.9 80.5 1.69 2.67 Sst bm vfgr v81ty dk stn gld flu 28 7919.1 0.129 0.156 14.3 46.6 28.4 75.0 1,64 2.68 S8t bm vfgr 81ty dk stn gld flu 29 7920.5 0.656 0.168 17.4 34.3 23.7 58.0 1.45 2.67 Sst brn vfgr V81ty dk stn gld flu Tracer , . ~~J.;..i' ~\ Core Lab Phillips Alaska, Inc. "Lookout" 2 Colville-River SW Field CL File No. : 57111-02045 API No. : 50M103M20410 Loc. : Sec. 25M T11 N/R2E Core Analysis Results % Saturations Oil J Water I Total I OIW % % 0/. Ratio Grain Description Density glee Comments ft Perm. (Kair) Hor. I Vert. md md Porosity Sample No. Depth Permeabilities were determined by steady-state methods, pore volumes by Boyle's Law methods. 400 psi confining pressure was used for pore volume and permeability measurements. -" 30 7921.4 18.7 83.1. 20.2 46.0 28.7 74.7 1.60 2.66 Sst brn vfgr slty dk stn gld flu ~ Fractured 31 7922, 1 16.5 8.28 20.7 46.7 16.5 63.2 2.83 2.66 Sst bm vfgr slty dk stn gld flu 32 7923.4 1.61 1,48 17.8 32.4 18,7 51.1 1.73 2.67 Sst bm vfgr vslty m stn gld flu Tracer 33 7926.3 0.615 0,005 8.9 15,3 84.1 99.4 0.18 2,67 Sh brn vslty m stn vdor flu 34 7927.0 0.200 0.017 9.7 31.2 59.8 91,0 0.52 2.68 Sh brn vstty m 8tn vdor flu L'" Phillips Alaska, Inc. CL File No. : 57111-02045 "~\ "Lookout" 2 API No. : 50-103-20410 ---"'. - ii Colville-River SW Field Loc. : Sec. 25- T11 N/R2E [ore Lati Hydraulic Unit Classification Sorted by Sample Depth Sorted by Hydraulic Unit Depth Flow Reservoir Hydraulic Depth Flow Reservoir Hydraulic Zone Quality Unit Zone Quality Unit eft) Indicator Index (ft) Indicator Index 7894.2 0.5369 0.130 9 7901,7 0.1648 0.025 7 7895.1 0.8351 0.247 10 7917.6 0.1908 0.026 7 7895.5 0.3829 0.027 9 7918,1 0.1681 0.025 7 7896.1 0.3649 0.063 9 7919.1 0.1787 0.030 7 7897.1 0.7553 0.206 10 7920.5 0.2894 0.061 8 7898.1 0.8777 0.236 10 7894.2 0.5369 0.130 9 7899.3 0.7370 0.183 10 7895.5 0.3829 0.027 9 7900.1 0.8339 0.222 10 7896.1 0.3649 0.063 9 7901 . 1 1.0891 0.309 11 7923.4 0.4354 0,094 9 7901,7 0.1648 0.025 7 7927,0 0.4197 0.045 9 7902.3 0.8762 0.243 10 7895.1 0.8351 0.247 10 7903.1 1 .0486 0.280 11 7897,1 0.7553 0.206 10 7904. 1 1.8538 0.382 12 7898.1 0.8777 0.236 10 7905.5 0.7895 0.201 10 7899,3 0.7370 0.183 10 7906.1 0.8760 0.218 10 7900.1 0.8339 0.222 10 7907.1 0.9801 0.251 11 7902.3 0.8762 0,243 10 7908.5 0.9184 0.241 10 7905.5 0.7895 0.201 10 7909.1 1 . 1585 0.277 11 7906.1 0.8760 0.218 10 7910,1 1 . 1130 0.285 11 7908.5 0.9184 0.241 10 7911.5 1 ,0542 0.244 11 7926.3 0.8449 0.083 10 7912.1 1.8769 0.490 12 7901.1 1.0891 0.309 11 7913.1 2.1844 0.543 12 7903.1 1.0486 0,280 11 7914.5 2.3962 0.700 12 7907.1 0.9801 0.251 11 7915.1 2.1696 0.641 12 7909.1 1.1585 0.277 11 7916.1 2.2253 0.635 12 7910.1 1 . 1130 0.285 11 7917.6 0.1908 0.026 7 7911.5 1,0542 0.244 11 4."~:~':. ¡., Phillips Alaska, Inc. , JaI. ~ "Lookout" 2 ~,. -~ Và Colville-River SW Field Core LaI:i CL File No. : 57111-02045 API No. : 50-103-20410 Loc. : Sec. 25- T11 NJR2E Hydraulic Unit Classification Sorted by Sample Depth Sorted by Hydraulic Unit Depth Flow Reservoir Hydraulic Depth Flow Reservoir Hydraulic Zone Quality Unit Zone Quality Unit (ft) Indicator Index (ft) Indicator Index 7918,1 0.1681 0.025 7 7921.4 1.1947 0.302 11 7919. 1 0.1787 0.030 7 7922.1 1.0746 0.281 11 7920.5 0.2894 0.061 8 7904.1 1.8538 0.382 12 7921 .4 1 . 1947 0.302 11 7912. 1 1.8769 0.490 12 7922.1 1.0746 0.281 11 7913.1 2.1844 0.543 12 7923.4 0.4354 0.094 9 7914.5 2.3962 0.700 12 7926.3 0.8449 0.083 10 7915.1 2.1696 0.641 12 7927.0 0.4197 0.045 9 7916.1 2.2253 0.635 12 Phillips Alaska Lookout #2 Colville-River SW Field Profile Permeability Depth (ft) Ka (md) 8.63 2.56 11.8 11.6 15.6 10.4 0.852 0.0360 1.19 1.37 5.67 11.9 18.6 6.11 10.1 3.44 6.27 9.49 13.8 29.0 13.5 10.5 22.7 11.2 9.65 7.78 10.7 14.4 6.39 16.1 18.4 38.2 16.4 8.51 0.618 2.43 20.4 11.8 13.6 15.5 13.4 19.1 22.8 21.0 9.85 7894.22 7894.40 7894.70 7894.80 7894.96 7895.23 7895.40 7895.60 7895.80 7895.97 7896.20 7896.40 7896.61 7897.20 7897.41 7897.60 7897.80 7897.99 7898.21 7898.40 7898.60 7898 80 7899.01 7899.37 7899.60 7899.80 7900.02 7900.20 7900.40 7900.61 7900.80 7900.98 7901.21 7901.41 7901.60 7901.81 7901.99 7902.17 7902.40 7902.60 7902.80 7903.03 7903.21 7903.41 7903.60 KI (md) 6.92 1.87 9.67 9.49 13.1 8.42 0.546 0.0107 0.802 0.939 4.44 9.83 15.8 4.78 8.21 2.59 4.91 7.66 11.5 25.3 11.2 8.56 19.5 9.21 7.80 6.19 8.75 12.0 5.02 13.5 15.6 33.8 13.8 6.81 0.378 1.77 17.4 9.74 11.3 13.0 11.1 16.2 19.5 17.9 7.97 CL File No. : 57111-02045 API No. : 50-103-20410 Lac. : Sec. 25-111 N/R2E Standard Probe Tip. 2 5/8" Diameter Core ~\ ~::~~::~~Ska Core Lab Colville-River SW Field Profile Permeability Depth (ft) Ka (md) 26.9 25.0 23.0 15.4 5.35 6.20 4.50 23.3 15.2 21.1 14.0 16.0 13.4 14.5 11.7 5.97 5.72 12.5 14.4 15.0 18.8 22.2 26.4 28.0 15.4 7.71 13.4 25.3 25.0 20.3 23.2 23.3 21.5 21.6 17.9 2.55 14.9 20.9 14.9 5.28 8.08 8.70 80.2 44.6 38.0 7903.80 7904.01 7904.20 7904.40 7904.60 7904.80 7905.00 7905.20 7905.38 7905.60 7905.80 7906.01 7906.20 7906.40 7906.60 7906.80 7906.80 7907.02 7907.20 7907.41 7907.60 7907.80 7908.00 7908.20 7908.40 7908.60 7908.80 7909.04 7909.20 7909.40 7909.60 7909.80 7910.02 7910.20 7910.40 7910.60 7910.80 7911.00 7911.20 7911.40 7911.60 7911.79 7912.18 7912.35 7912 51 KI (md) 23.3 21.6 19.7 12.9 4.16 4.86 3.46 20.0 12.7 18.0 11.6 13.4 11.1 12.1 9.58 4.68 4.47 10.4 12.0 12.6 15.9 19.0 22.8 24.4 12.9 6.13 11.1 21.8 21.6 17.3 20.0 20.0 18.4 18.5 15.2 1.86 12.4 17.8 12.5 4.10 6.44 6.97 73.0 39.7 33.5 CL File No. : 57111-02045 API No. : 50-103-20410 Lac. : Sec. 25- T11 N/R2E Standard Probe Tip. 2 5/8" Diameter Core Phillips Alaska Lookout #2 Colville-River SW Field Profile Permeability Depth (ft) 7912.80 7913.02 7913.21 7913.40 7913.60 7913.80 7914.00 7914.20 7914.45 7914.60 7914.80 7915.02 7915.21 7915.40 7915.60 7915.78 7916.02 7916.20 7916.40 7916.60 7916.80 7917.00 7917.20 7917.41 7917.60 7917.80 7918.02 7918.21 7918.20 7918.40 7918.60 7918.80 7918.97 7919.20 7919.40 7919.60 7919.80 7920.01 7920.20 7920.36 7920.60 7920.78 7921.02 7921.40 7921.14 Ka (md) 69.5 43.2 45.3 34.6 62.0 51.0 75.1 24.6 77.5 65.1 75.2 55.0 43.8 77.0 99.8 43.1 120. 27.2 57.5 47.8 37.9 8.90 1.09 0.278 0.527 0.359 0.671 0.804 0.878 0.820 0.421 3.28 0.447 0.920 0.381 0.504 0.580 0.556 0.643 1.80 3.63 7.54 18.7 5.46 19.9 KI (md) 62.9 38.4 40.4 30.4 55.7 45.5 68.1 21.2 70.3 58.7 68.2 49.3 38.9 69.9 91.3 38.2 111. 23.6 51.6 42.7 33.4 7.15 0.725 0.147 0.313 0.199 0.416 0.513 0.565 0.522 0.241 2.45 0.258 0.596 0.214 0.297 0.350 0.334 0.396 1.26 2.74 6.00 15.9 4,25 16.9 CL File No. : 57111-02045 API No. : 50-103-20410 Lac. : Sec. 25- T11 N/R2E Standard Probe Tip. 2 5/8" Diameter Core !J'¡¡"'I 'r;~i:'~" ,~::,,::::, ~,,:J Cure LaI:i Phillips Alaska Lookout #2 Colville-River SW Field Profile Permeability Depth (ft) Ka (md) 4.51 4.47 26,0 4.27 15.5 14.0 3.94 1.04 1.16 0.661 0.285 0.282 9.25 6.10 1.34 0.598 2.19 1.32 2.31 0.677 2.97 1.95 1.87 1.81 1.25 3.03 0.968 3.96 17.5 0.455 2.04 0.480 1.02 0.525 0.738 6.92 1.48 0.678 7921.60 7921.80 7922.06 7922.25 7922.40 7922.60 7922.80 7923.00 7923.18 7923.40 7923.61 7923.80 7924.03 7924.37 7924.53 7924.79 7925.00 7925.11 7925.27 7925.42 7925.58 7925.81 7926.04 7926.21 7926.63 7926.38 7926.80 7927.12 7927.24 7927.44 7927.63 7927.80 7928.03 7928.16 7928.27 7928.38 7928.49 7928.58 KI (md) 3.47 3.44 22.4 3.27 13.0 11.6 3.00 0.688 0.777 0.409 0.151 0.149 7.45 4.79 0.911 0.363 1.57 0.899 1.66 0.420 2.20 1,39 1.32 1.27 0.849 2.26 0.631 3.01 14.8 0.263 1.45 0.281 0.673 0.311 0.465 5.48 1.02 0.421 CL File No. : 57111-02045 API No. : 50-103-20410 Lac. : Sec. 25- T11 N/R2E Standard Probe Tip. 2 5/8" Diameter Core Phillips Alaska, Inc. File No. : 57111-02045 "Lookout" 2 Colville-River SW Field Tracer Analysis Results - Plugs Mp1 Sample Description Chloride2 lodide3 lodide4 Sample ID mg/L mg/L mg/L 0507- 2 1- Lookout #2 Depth - 7896.1 212.755 77.329 0.051 0507- 3 2- Lookout #2 Depth - 7899.3 200.397 77.231 0.015 0507- 4 3- Lookout #2 Depth - 7902.3 201.337 84.306 0.038 0507- 5 4- Lookout #2 Depth - 7905.5 222.118 83.165 0.035 0507- 6 5- Lookout #2 Depth - 7908.5 218.628 80.547 0.079 0507- 7 6- Lookout #2 Depth - 7911.5 187.699 39.382 0.042 0507- 8 7- Lookout #2 Depth - 7914.5 131.406 20.391 < 0.010 0507- 9 8- Lookout #2 Depth - 7917.6 171.243 64.228 < 0.010 0507-10 9- Lookout #2 Depth - 7920.5 144.667 69.726 < 0.010 0507-11 10- Lookout #2 Depth - 7923.4 115.657 64.607 < 0.010 1 Metrohm Peak 1 Original chloride analysis - should not be effected by the problems with the Iodide. 30riginallodide analyses were in error due to a second peak that traced near the Iodide peak. 4 Rerun Iodide analysis Analysis performed by Metrohm Peak Phillips Alaska, Inc. "Lookout" 2 Colville-River SW Field Tracer Analysis Results. Mud File No. : 57111-02045 Mp1 Sample Description Chloride Iodide Sample ID mg/L mg/L 0507-12 A 1- Lookout #2 Core #1 Suction Line Beginning of Core 13637.62 439.10 0507-13 A2- Lookout #2 Core #1 Suction Line Beginning of Core 13475.57 396.50 0507-14 A3- Lookout #2 Core #1 Suction Line Beginning of Core 13480.82 406.79 Average Values 13531 414 0507-15 81- Lookout #2 Core #1 Mud Cuttings @ 7895 ft 13392.31 380.51 0507-16 B2- Lookout #2 Core #1 Mud Cuttings @ 7895 ft 13305.07 385.03 0507-17 B3- Lookout #2 Core #1 Mud Cuttings @ 7895 ft 13161.62 395.09 Average Values 13286 387 0507-18 C 1- Lookout #2 Core #1 Mud Cuttings @ 7910 ft 12866.90 358.95 0507-19 C2- Lookout #2 Core #1 Mud Cuttings @ 7910 ft 13015.88 400.11 0507 -20 C3- Lookout #2 Core #1 Mud Cuttings @ 7910 ft 12679.51 392.24 Average Values 12854 384 0507-21 D1- Lookout #2 Core #1 Mud Cuttings @ 7925 It 13901.71 376.58 0507-22 D2- Lookout #2 Core #1 Mud Cuttings @ 7925 ft 8898.43 224.02 0507-23 D3- Lookout #2 Core #1 Mud Cuttings @ 7925 ft 12802,19 348.89 Average Values 11867 316 0507 -24 E1- Lookout #2 Core #1 Suction Line End of Core 13094.24 413.31 0507-25 E2- Lookout #2 Core #1 Suction Line End of Core 12870.68 391.93 0507-26 E3- Lookout #2 Core #1 Suction Line End of Core 13332.67 361.54 Average Values 13099 389 0507-27 F1- Lookout #2 Core #2 Suction Line Start of Core 13084,18 361.30 0507-28 F2- Lookout #2 Core #2 Suction Line Start of Core 13982.35 377.03 0507-29 F3- Lookout #2 Core #2 Suction Line Start of Core 13387.66 402.03 Average Values 13485 380 0507-30 G 1- Lookout #2 Core #2 Mud Cuttings @ 7930 It 13362.07 384.57 0507 -31 G2- Lookout #2 Core #2 Mud Cuttings @ 7930 ft 13615.88 403.73 0507-32 G3- Lookout #2 Core #2 Mud Cuttings @ 7930 ft 14572.25 410.32 Average Values 13850 400 1 Metrohm Peak Tracer analysis performed by Metrohm Peak Phillips Alaska Inc. Lookout #2 Colville-River SW Field CL File No. : 57111-02045 API No. : 50-103-20410 Lac.: Sec. 25-T11N/R2E Core Gamma Suñace Log (Gamma Log digitized by California Digitizing) Depth Total Gamma ft API 7894.00 -999.3 7894.50 49.6 7895.00 23.7 7895.50 40.2 7896.00 47.5 7896.50 16.4 7897.00 24.7 7897.50 39.4 7898.00 44.9 7898.50 23.3 7899.00 52.5 7899.50 51.1 7900.00 22.6 7900.50 15.6 7901.00 35.4 7901.50 23.3 7902.00 66.1 7902.50 50.0 7903.00 45.3 7903.50 34.2 7904.00 61.9 7904.50 38.5 7905.00 28,5 7905.50 51.4 7906.00 49.5 7906.50 32.6 7907.00 54.3 7907.50 43.3 7908.00 40.2 7908.50 36.6 7909.00 44.4 7909.50 40.6 7910.00 37.0 7910.50 49.7 7911.00 28.3 7911.50 48.4 7912.00 34.2 7912.50 19.9 7913.00 46.6 1 Phillips Alaska Inc. Lookout #2 Colville-River SW Field CL File No. : 57111-02045 API No. : 50-103-20410 Lac.: Sec. 25- T11 N/R2E Core Gamma Suñace Log (Gamma Log digitized by California Digitizing) Depth Total Gamma ft API 7913.50 14.7 7914.00 28.7 7914.50 35.5 7915.00 24.2 7915.50 34.8 7916.00 40.7 7916.50 23.4 7917.00 36.6 7917.50 18.5 7918.00 28.6 7918.50 38.2 7919.00 48.8 7919.50 53.1 7920.00 28.1 7920.50 55.6 7921.00 65.0 7921.50 42.3 7922.00 30.7 7922.50 48.3 7923.00 43.7 7923.50 55.1 7924.00 34.4 7924.50 42.4 7925.00 34.2 7925.50 59.4 7926.00 66,0 7926.50 57.3 7927.00 59.0 7927.50 55.2 7928.00 62.5 7928.50 58.0 dDd-OQ. 1 @ ~ ff1\ ~_IÇ Plu" ¡--oJ~ ~\ ~L fE\ ~ r([ ff}\ cid) - 1rJ ~ d LrÙ ~ Lrü æJ U \.ì ULJ Ald'-SKA OIL AND GAS CONSERVATION COMMISSION ,/ / ¡ I l / TONY KNOWLES, GOVERNOR 333 w. r AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 17, 2002 James R. Winegamer District Landman Exploration and Land ConocoPhillips PO Box 100360 Anchorage AK 99510 Dear Mr. Winegamer: The Alaska Oil and Gas Conservation Commission ("Commission") has completed an audit of the NPRA wells drilled by Phillips Alaska, Inc. ("Phillips") to verify the \vell status and projected release dates. In letters accompanying data submittals for these NPRA \\,'ells, Phillips requested that the Commission provide notice prior to any public disclosure of confidential information so that Phillips might be heard on the issue. Pursuant to AS 31.05.035(c), the data Phillips provided as required by AS 31.05.035(a) will be kept confidential for 24 months fol1o\ving the 30-day filing period unless the owner of the well gives written permission to release the reports and infonnation at an earlier date. The Commissioner of Natural Resources may extend the 24-month period of data confidentiality under certain circumstances. In the case of the Spark 1 A, Permit to Drill # 200-056, the Department of Natural Resources (HDNR") granted extended confidentiality for the well through September 3, 2002 although the Commission's records indicated that the status of this well is ~'Operation Shutdo\vn". An audit of the Commission's records indicates that this status is in eITor. The Commission has determined that the Spark 1 A well was in fact completed (equipped and conditioned so that it was capable of producing or injecting fluids) on April 29, 2000 and is therefore subject to release after September 3, 2002. Unless the Commission hears from Phillips before September 20, 2002, the Spark 1 A file will be released to the public on September 23, 2002. James R. Winegamer September 17, 2002 Page 2 of2 The following is a list of Phillips' NPRA wells that have projected release dates. Rendezvous A Lookout 1 Rendezvous 2 Hunter A Mi tre 1 Lookout 2 Mooses Tooth C PTD # 200-054 PTD # 201-003 PTD # 201-007 PTD # 202-013 PTD # 202-026 PTD # 202-027 PTD # 201-049 5/27/03 5/4/04 5/28/03 4/26/04 5/21/04 6/5/04 5/6/03 If you have any questions about these release dates, please contact Steve Davies at 793- 1224. Although it has been the practice of the Comnlission to publish well data release dates in advance on its website, it is the operator's or owner's responsibility to make a timely application to the Department of Natural Resources in the event that extended confidentiality is desired. '{ ou should not rely on receiving any reminders from the Commission regarding the release dates for these wells. Sincerely, I,., ~'" J-~- '~ \Jl'1'~\"1'~~~'" L:.t.'iAJ:.-l.. JÚA...\,lQ-L- . '- Cammy echsh Taylor Chair COT:~jc cc: Mark Meyers, DOG Lookout #2 Testing Summary Re\'ised 7/29/02 by TJB ),O;l...-O;t7 April 1, 2002 Last 2..1 Hours Acti\'ities: Continuing to rig up test equipment. 1\[ost equipment on site. Tank farnl is being assenlbled and bernled today. Building berms for separator and other equipnlent. A 01'" ìOO., pn ~, - - Last 2..1 Hours Acti\'ities: Continuing to rig up test equipment. [\,Iost equiplllent on site. The gas scrubber and desander \\"ill be deli\"ered today. Tank tàrm is being bernled today. Still lacking one vertical tank in the bernl. Building berms for separator and other equiplllent. Rigged up Schlunlberger unit last night. April 3, 2002 Last 2..1 Hours Acth'ities: Continuing to rig up test equipment. 1\,lost equipment on site. The desander will be deli\'ered today as well as the doghouse for the separator. The doghouse has all the tools needed to begin assembling lines. One truck broke dO\\ll in Fairbanks. It is back on the road and should make Oeadhorse by morning. All tanks in place in tank tàrm. Building berms for separator and other equipnlent. Perforated 34' in Lookout #2 from 7,890' to 7~924' l\¡[D. Perforated - 300 psi underbalanced with 400 psi wellhead pressure. W'ellhead pressure gradually increased,to,. 700 psi after the initial perforating run. Bled off the pressure to 400 psi before tiring gun number t\\'o. 1\,loved the e-line lmÏt to Lookout # 1. Could not run a jewelry log due to the Hot Oil truck being tied up at Lookout #].. Pulled the top OV at 2,500' 1\,10 in Lookout #2 with slickline and replaced with a checked orifice. Circulated 250 bbls hot diesel down the annulus and up the tubing to waml the T' x 9-5/8" annulus. April 4, 2002 Last 2..1 Hours Activities: Continuing to rig up test equipnlent. All equipment on site - tinally. The desander is stood up and in position. Flare stack spotted. Genset spotted. Beginning to run hard lines and hoses in tank farnl. Building bemlS for separator and other equipment. Perforated 90' in Lookout #1 from 7,876' to 7,921' and 7,953' to 7.998' MD. Perforated - 300 psi underbalanced \\'1th 550 psi wellhead pressure. Wellhead.pressure immediately increase~.~,~}_5Q-n§i..&ç~':ít!!S..~PÁtial perforating run (7,973' to 7,998') and then increased, to 850 psi in several miñutes. Flowed to an open top tank to bleed off the pressure to 550 psi before tiring gun number two and three. April 5, 2002 Last 24 Hours Activities: Continuing to rig up test equipn1ent. Ail equipment spotted. COlnpleted hoses and piping in the tank farm. Completed berms around the tank tàrn1. Completed berms around separators and desander. Con1pleted hard lines in separator benn and to tank tàro1. Conlpleted bern1s around relief tank and sand reco\'ery tank. RUlming hard line and bern1ing line to flare stack. Flare stack partially completed. Completed giant circus tent of visquine o\'er scaffolding around the desander. Began heating up de sander tent with tioga heaters. Generator up and running. running lines to equipment. SCAN lab spotted and rwming data cables. Ran two side pocket pressure gauges in Lookout #2 to monitor frac~ flow test and pressure build-up. Circulated hot diesel in the inner annulus to warm up the outer annulus again. Dummied off top mandrel. Pressure tested the annulus to 3.500 psi. \Veil prep'd for the frac. Displaced 20 bbls of diesel down Lookout # 1 to freeze protect. Loading and heating water to 110° F in frac tanks. Sand chief filled with prop. Coiled tubing return tanks spotted and bel1ned. April 6, 2002 Last 24 Hours Acth'ities: Continuing to rig up test equipment. Completed Flare stack and raised. Con1pleted hard line to flare. COD1pleted hard lines from desander to choke and to the sand reco\"ery tank. Only hard line remaining is from the wellhead to the desander. Built berm for wellhead line. COlnpleted air test on tank farn1 hoses - ready to heat trace and insulate. Nearly complete on desander rig up with hydraulic hoses and sand detection system. Circus tent sur\'Ï\"ed the wind storn1 with minor damage. Ran two Sparktek gauges and locked then1 in the XN nipple in Lookout # I. Ran two Inore Spartek gauges and set in the X nipple and could not get a pressure test (attempted twice with good sets both times). Suspect mandrels bet\\"een packer and X nipple could be the culprit. \\'ill troubleshoot when running pern1anent gauges. \Vill not affect our pressure data for the short tem1. Displaced 10 bbls of l'v1eoh down Lookout # 1 to freeze protect prior to setting second set of gauges. Heating water to 110° F in frac tanks. Frac pun1ps. Frac CAT on location. April 7, 2002 Last 24 Hours Activities: Continuing to rig up test equipment. Nearly complete on hard line from desander to wellhead. Partially complete on heat trace and insulation in tank fann. Desander ready. SCAN systen1 ready. Had to fly in a double stud adapter for the tlow line from Anchorage. Also had to get crosso\"er from tree to flowline frol11 well sen'ice group. Rigged up both. Sonle minor berming relnaining for flowline fronl well to desander. Rip in circus tent repaired. .a.egan fracture treatnlent on Lookout #2. Pumped 200 bbl breakdo\\l1 at 30 BPl\,1 with a step dO\\l1 test at the end. Frac gradient of 0.65 psi/ft. l\'Iinimal excess friction of 250 psi. \\'atching pressure decline and batching up gel in the PCl'v1 \\'hen the tubing pressure junlped 500 psi and the annulus pressure decreased 500 psi. Tubing and annulus pressure tracking through a small leak. Freeze protected the well with -1-0 bbls diesel and rigged up slickline. Found top Spartek gauge packing torn off with Teflon ring pushed up abo\'e packing area. The Teflon ring was probably the only thing holding pressure and finally gave up. Re-ran new Spartek gauge and pressure tested casing to 3.500 psi. Tubing increased fronl 500 psi to 800 psi. Bled tubing to 500 psi and held 3.500 psi on annulus for 15 Ininutes. Held solid. Bled annulus to 500 psi and pressured tubing to 3.500 psi. Annulus increased to 800 psi and everything held solid. Had to rig do\vn sOlne frac equipnlent to get the slickline unit in place. Plan to ha\'e the tì'ac crew on site tonlorrow morning early and begin frac' ing by about 8 A1\;1. April 8, 2002 Last 24 Hours Activities: Continuing to rig up test equipn1ent. Complete on hard line from desander to wellhead. COlnplete on heat trace and insulation in tank farm. COlnplete on heat trace of hard lines. Con1pleted renlaining berms under hard lines. Completed liquid high pressure test on test system. Completed fracture treatJnent on Lookout #2. Pumped 300 bbl data frac at 30 BPtv'l and averaged 3.400 psi treating pressure. ~latched pressure decline and detennined closure pressure and tinle. l\.10deled frac and adjusted leak-off coefticients to nlatch data frac results. Left pad size as designed for the Inain frac and added 50 bbls to 10 ppg stage due to improved tluid efticiency. Frac gradient of 0.68 psi/tì. tvlinimal excess friction. Pumped main job with 400 bbls pad and 950 bbls of slurry. Treated at an average pressure of 2.500 psi. Had a problenl with the densimeter on one side of the pod blender. So we had to use the other side and manually controlled the sand gates on the primary side. Unfortunately the fluid rates were not equal on both sides of the pod so our sand concentration was not as high as we thought. 'J.¡'e thought we had pumped 215.000 lbs of 16/20 prop with 12 ppg max at the perfs. but we actually pUJ1lped 180.000 lbs of prop with 10 ppg at the perfs. Flushed the job to completion -1- bbls short of the top perforation. Job went well other than we didn't build a lot of net pressure. \Vell need to see the bottomhole gauges to determine the exact anlount. Rigged down the frac equipnlent and mo\'ed out. Coiled tubing on site. Rigging up flow back equipment for coil and berm for unit. Diesel being hauled on site for the clean-out. April 9~ 2002 Last 2~ Hou rs Activities: Completed test equipment rig up. Completed insulation and safety systen1s. Completed coiled tubing clean-out. Could not work coil below the botton1 GLlVI at 7.653' MD. Suspect gauge at that depth could be bent or the coiled tubing could be bent in the direction of mandrel belly. Decided to clean-out from there. Well tlowing nicely during clean-out. Had 200% returns throughout job. PUlnped approximately 360 bbls of gelled and slick diesel during the clean-out and recovered 740 bbls to the tanks. Once the gas to the tlowback tanks \Vas too much to handle we switched the well into Halliburton systeln. Continued to pwnp hot diesel and n1inimal rate to keep the well warn1. Shut down pumping and pulled CT to surface and rigged down. Lit the flare at about 9:30 Pl'vL Had difficulty \vith the desander unit initially. Con1pletely tilled one side and had some proppant and formation sand overrun. Flush line was blocked. Finally got desander flushed and it is now working fine. Gradually opened the choke up over night as desander flushing pern1itted. Had difticulty with sample ports being plugged April 10, 2002 Last 24 Hours Activities: Continued to flow \\¡ell targeting a constant production rate. First set of gas and oil samples captured at 8 PM last night. Scraped pad clean. April 11, 2001 Last 24 Hours Activities: Continued to flow test well. Around 14:00 Fran Ulmer paid the operation a visit along \\'ith several other "isitors. Fran made several favorable comlnents regarding the cleanliness of the operation. The pad looked great. ADEC stopped by to check tank information around 18:00. Jack offered to show theIn anything they wanted, or perforn1 a spill drill. Apparently. Aha l'vlura just undef\vent a lengthy tabletop drill. so ADEC wasn"t eager to run another. At 19:00 the decision was made to begin opening up the \vell in order to achieve higher tlow rates. ~/e had etTecti"ely '.caught up" on crude hauling with the addition of the 4th truck. Increasing gas consumed quite a bit of our t\VO upward choke changes. After the second change, a slight oil misting up and out of one of the vertical tanks was observed. A combination of tàctors seemed to lead to this misting. The separator is full of carbolite \vhich has reduced its gas/oil split efficiency considerably. The high flo\v rate and piping friction dO\\111stream of the separator have raised the separator pressure to 175 psi. Both of these have led to higher gas \'olun1es going to the tanks. April 12, 2002 Last 24 Hours Acth'ities: Continued to flo\v test well. Completed clean-up and inspection of pad regarding previous night's misting. Alaska Clean Seas inspected the area and contÌrrned our procedural protocol. In an effort to minin1ize \'ented gas \'elocity in the \"ertical tanks~ we are now tlowing to all four of them concurrently. In addition~ we are pumping from the verticals to the horizontals at a steady pump rate. Vie have installed crate/adsorb boxes at the "ent of each vertical tank to capture any remaining droplets. The overall area is being inspected regularly~ and the modifications appear to have attained conlplete success. At 13 :00 we performed two small choke increases. These choke increases were wldertaken in an attenlpt to keep the liquid production rate flat and thereby Inaximize the pressure pulse. Howe\'er~ the choke increases were found to add slight liquid production at the cost of substantial increases in gas and overall GOR. It was detennined that this would put undue stress on the tank farnl and add some additional complication to the subsequent pressure transient analysis. Additional choke changes were aborted. April 13, 2002 Last 24 Hours Activities: Continued to tlow test \vell unti I midnight. Based on total reservoir volume produced, it \vas determined that continuing the flow until nlidnight \vould produce a sufficient pressure pulse. Consequently. the well was shut-in at 24:00. Final oil and gas san1ples were captured at 19:00. April 14, 2002 Rig down of the \vell test is in progress. Releasing supporting equipment as necessary. Evacuated all tanks. released both punlp trucks (Alpine and Lookout). released scaffolding around Kreps and tanks~ all tankers released. all vac trucks released. t\VO of the HES SCAN lab people released. All insulated nlats are stacked banded and over at the lVlile 28 Location for Puviak transport. \\.Till release the canlp as soon as possible as the equipment gets picked up. April 16, 2002 The wells group is planning to get to Lookout #2 Thursday morning to pull the two sidepocket pressure gauges. Remember that there may be a problem at the bottom gauge that \ve sa\\' on the clean-out. So it make take them some time to fish that gauge out.I'm not sure it is worth putting another set of gauges do\vnhole for another 7 to 14 days of data. It is probably the prudent thing to begin P&A operations ASAP due to the potential frozen 7" x 9-5/8" annulus probem \vhich needs to be addressed. If we attempt to circulate hot diesel every few days it \\lould disturb any pressure measurements do\vnhole unless \ve go for guages hanging from a lock mandrel in the XN nipple. PHilliPS Alaska, Inc. A SUlJ5ld,ary of PHilLIPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DATA FROlVl: Sandra D. Lemke, AT01486 Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Lisa Weepie AOGCC 333 W. 7th, Suite 100 Anchorage, Alaska 99501 RE: Lookout 2 PERMIT 202-027 DATE: 06/25/02 Delivery: Hand carried Transmitted herewith is the following: Lookout 2 (501032041000) Sperry Sun CD ROM í LIS Digital Log data(TIF and TXT files) ; also including CGMs, PDF's and EMF format log Image files containing BAT/VDL, EWR/CNP/SLD/DGR displays Please check off each item as received, sign and return one of the two transmittals enclosed to address below. "On behalf of itself and [name other owners]. Phillips Alaska. Inc. submits the attached data for the Lookout 2 Well, Drilling Permit No. 202-027 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the use of the Commission in carrying out its duties. we question whether any future disclosure to DNR or the public would be appropriate or valid. However. it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore. we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure. so that we may be heard on the issue." cc: David Bannan, PAl Geologist Receipt: Return receipt to: ~ ú-ikru . Date: lo-~s-o~ Phillips Alaska, Inc. ATfN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Prepared by: Sandra D. Lemke Phillips Alaska IT Technical Databases PHilliPS Alaska, Inc. A Suoslo,ary 01 PHILLIPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01486 Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Lisa Weepie AOGCC 333 W. 7th, Suite 100 Anchorage, Alaska 99501 RE: Lookout 2 PERMIT 202-027 DATE: 05/14/02 Delivery: Hand carried Transmitted herewith is the following: Lookout 2 (501032041000) Schlumberger CO ROMS --lL'" Processed CMR; CMR and displays; Job 22139, PDSVIEW, DLIS, LAS formats V Open Hole edits; LDWG; PEX: AIT/CMR/DSI/FMI/MDT; Job 22142; / Processed Data-DSI- Best DT Job 22141 CORaM ~core Labs-Digital Core Photo Images; Job 020283 ~SWC and conventional core descriptions; .xls excel format; Geologist-Dave Bannan; 4/26/2002 C%r Logs ~CMR DMRP Processing: from PEX logs-AIT/CMR/MDT ~Itra Sonic Imagaing Tool/Gamma Ray, logged 3/16/2002 Sperry Sun (disk and Q. C; report) vMWD directional survey data; Survey 9848; 03/18/2002; w/ hardcopy Q.c. report ( 2 copies of each) Epoch R~S and CORaM - Epoch - Final Well Report, Lookout 2- well information, lithology, daily activity summary, survey info, daily mud, bit, daily well site reports, formation log (MD and TVD); drilling dynamics (MD); MWD combo (MD) Please check off each item as received, sign and return one of the two transmittals enclosed to address below. "On behalf of itself and [name other owners], Phillips Alaska, Inc submits the attached data for the Lookout 2 Well. Drilling Permit No. 202-027 as specilied in 20 AAC 25.071. We request that this data be held conlidentlal as required under AS 31. 05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the use of the Commission In carrying out ItS duties, we question whether any future disclosure to DNR or the public would be appropriate or valid. However. it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our Intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure. so that we may be heard on the Issue " cc: David Bannan, ¿AI ./jist Rece~ ~ Ú O;or:J Return receipt to: Phillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 . ... . . Date: . .'~" ~ Prepared by: Sandra D. Lemke' Phillips Alaska IT Technical Databases MEMORANDUM TO: Cammy 0 Taylor, (t1 Chair Tom Maunder, 1£-1'rfI P. I. Supervisor' 5\ ,6 o~ Chuck Scheve, Petroleum Inspector THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 5, 2002 SUBJECT: Surface Abandonment Lookout #2 PTD# 202-027 Sunday, May 5, 2002: I traveled to Phillips Lookout #2 exploratory location to inspect the casing cut off and abandonment of this well. All casing strings had been cut off at approximately 4' below Pad level and all were found to be full of cement. A 1/4"thick marker plate was welded to the 16" conductor with the required information bead welded to it. SUMMARY: I inspected the surface cement plug, casing cut off depth, and the P&A marker plate on the Lookout #2 well and found all to be in order. Attachments: Lookout #2 plate.JPG Lookout #2 cut off.JPG X Unclassified Unclassified with Document Removed Classified dO d':-O ð- 'ì ." {> "... " li--eo-~oe - -. -\S~'?Ñ~"!><Ì ~ -eü-eoc 'C~\S~" .l (l ~ò "')"J,' \.J -:J ~'" Ç) \'YY!>"-, Sc,. CU,) tPHiruPs\ PHilLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage. Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 l\Ilay 21. 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7'h Avenue Suite 100 Anchorage, Alaska 99501 Subjecr: Lookout 2 (202-027 / 302-13-1-) Completion Report Dear Commissioner: Phillips Alaska. Inc., as operator of the Lookout 2 exploration well, subn1its the attached "Well Completion Report". (AOGCC form 10-407) to cover the drilling and P&A operations. Also attached is the summary of daily operations. directional survey, as-built. core description. P&A summary, The Commission is requested to keep confidential the enclosed information due to the exploratory nature of this well. If you have any questions regarding this matter, please contact me at 263-4603 or Tom Brassfield at 265-6377. Sincerely. ~1A-/l n~/,il }-!L I 111 f Uji., P. Mazz::i ~T Exploration Drilling Team Leader PAl Drilling PMlskad RECF~\/FD , . .' I - . f"\Ù. "''''; p .. ". . I .; i .'~L~; ~ " ¿ \.'~- Alaska Oil ~ G2~. \:(:ns L;.I:!:It~I' ,:ill.. AnchoraQE' On\c,r\! f\' ~\ \) t ~ 'J !~.\ L ) STATE OF ALASKA ~ ALA'SKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well I lOCAlIONS: 7. Permit Number y~ ~ 202-027 I 302-134 I Suf\~r"~;, ;:;!.~ B. API Numbe, P. O. Box 100360, Anchorage. AK 99510-0360 'r,>!..~ ~. 50-103-20410-00 " -.., ,.!' .1. ...... 4. Location 01 well at surlace -v'~~~"'" 9. Unit or Lease Name 3893' FSL. 1400' FEL, Sec. 25, T11 N. R2E. UM (ASP: 314047, 5955054) ~ - '-,. :_~j¡j'I":; Exploration NPRA AtTop Producing Interval : .- ,),..:"7 ~ 10. Well Number 1413' FNL, 1456' FEL, Sec. 25, T11N. R2E, UM (ASP: 313990, 5955029) '$--V'.d.l-....' Lookout 2 ~~~~,a~~:t~456' FEL. Sec. 25, T11N, R2E. UM (ASP: 313990, 5955029) ..'.~~ 11':~~~;~::nOOI 5. Elevation In feet (indicate KB. OF. etc.) 6. Lease Designation and Serial No. RKB 21.5 + 28.5 ADL AA0818191 AK5164 12. Date Spudded 13. Date 1.0. Reached 14. Date Comp.. Susp. Or Aband. March 2, 2002 March 18, 2002 May 5, 2002 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 8200' MD 18200' TVD surface YES 0 No 0 22. Type Electric or Other Logs Run CNP/SLD/EWR/BAT, PEX/DSI/CMR/MDT/FMI 23. 011 0 Gas 2. Name of Operator Phillips Alaska, Inc. 3. Address 0 Suspended 0 Abandoned 0 Service 0 15. Water Depth. If offshore 16. No. of Completions (P&A'd) N/A 20. Depth where SSSV set land nipple @ 914' leet MSL 21. Thickness of Permafrost 925' MD CASING SIZE WT. PER FT. GRADE 16" 62.58# H-40 9.625" 40# L-80 7" 26# L-80 4.5" 12.6# L-80 CASING. LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 115' Surface 3096' Surface 7883' 7734' 8198' HOLE SIZE 24" 12.25" 8.5" 6.125" CEMENTING RECORD 200 sx AS 1 422 sx AS Lite & 166 sx LiteC rete AMOUNT PULLED 195 sx LlteCrete 79.5 sx Class G 24. Perlorations open to Production (MD + TVD of Top and Bottom and interval. size and number) 4.5" TUBING RECORD DEPTH SET (MD) 7734' PACKER SET (MD) 7730' 25. SIZE 7890' - 7924' MD and TVD. 6 spf 26. ACID. FRACTURE. CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7890' - 7924' MD 1 BO.OOO# of 16/20 carbolite proppant 27. Date First Production tested from 4/8/02 to 4/12/0 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift. etc.) Plugged and Abandoned GAS-MCF W A TER-BBL Production for OIL-BBL 4/8-12/02 51 hours Test Penod > Calculated 24-Hour Rate> OIL-BBL GAS-MCF 3351 7 mmscfd CORE DATA W A TER-BBL 158 bwpd CHOKE SIZE 1 " OIL GRAVITY - API (corr) 40 API GAS-OIL RATIO 2089 Flow Tubing Casing Pressure press. 1050 psi 1200 psi 28. Brief descnptlon of lithology, porOSlry, fractures, apparent dIps and pressence of oil. gas or water. Submit core chips. '>...l- .. 0'":) ~~,-õJ ( :,\....\~ ~¥~'-01Çìd'\r"" ,- ~ C!..: I ,-' , ""r""r:-I\,r-ro ~( t . ~ t: ~ '.:' t L~ See Attachment I . .". ... . , ' , .~ :':~I') ) L..,.'... L- I - ,. I i.o..- Alaska Oil & Gê5 '~C¡'~.3 ;..,(1:':!\¡:,;).jIL~' ,AnchoraD8 Form 10-.m7 Rev. 7.1-80 CONTINUED ON REVERSE SIDE ./' (~ \/ Submit In duplicate 29 30. "' GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include Interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Top Nanushuk 3385' 3385' Top Torok 4105' 4105' LCU 7412' 7412' Top Jurassic 7863' 7863' J-4 7925' 7925' r) r.: ;'''' ,"'" n. , 1 r ['" h '.. ft ~"~, ~ ïl,,, iï f. ,. '""';¡ I I "I (' . ,,;, ~- ~" ....,) ., .~,~ ... :,.: j"; ~~ ':, ~JC;:::..' Alaska OJ ,~..: b:',':: Ct:~'.) \,,;(!.hti'l'J~;It;' 6.:Ir.hs1ni'~il~ 31. LIST OF ATTACHMENTS Summary of Daily Operations. Directional Survey, As-Built. Core Description, P&A summary 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Tom Brassfield 265-6377 s;gn"")1<f)..<I.- ¿ß/"f.., ¡ T;le Paul ",yç;olini /!LJ /1(Á ¿?iJL"t : Dnlling Team Leader Date J-) ,þ Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion, Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken. indicate "none". ,-.. r"'-. f '1 . . -- , r , . ~ ! Form t 0"407 P AI Drilling ~ a ~ ') Page 1 of 11 -, Phillips Alaska, Inc. Summary Report for: Lookout #2 Operations Summary for event: Rotary Drilling 2/28/02 . . Time Start End From To Hours Phase Activity Subcode Class Trouble Depth Depth Operation Waiting on trucks f/18E for rig move to Lookout #2. Rig maintenance, grease and service skate, inspect tugger lines, 0' grease manifold and choke and kill valves, service drill line spool gearbox, load out apc & doyon trucks & prepare rig for move. Waiting on trucks, prepare to move, blow down services, unlug electrical, move pipe 0' sheds, rock waher & tioga away from rig. Released rig(on moving rate) @ 1800 hrs 2/28/02. Load boiler, motors, O' pump & pit modules f/move. Move sub off 21-03 @ 1900, move rig off 2L location @ 2000 hrs, 0' crew change on ice road @ Colville river crossing. Total rig move 37,S miles to lookout #2. 24 Hr Sum Waiting on trucks, rig maintenance and preparing to move, Sub and rig off location @ 2000 hrs. Continue moving rig f/2L to Lookout #2. Spot sub & rig complexes, Rig up for spud. Hook up service lines, Put together pumps and lines, spot shop & pipe sheds. Nipple up entire surface diverter system, 16" x 105'. Load pipe shed w/4" HT 38 drillpipe and strap, Camp enroute from 2L. Continue moving rig complex, onsite @ 0700 hr, spot sub & complexes, rig up and n/u diverter, 00:00 15:00 15.00 MOVE WAlTON OTHR T 15:00 18:00 3.00 1\10VE WAlTON OTHR T 18:00 19:00 1.00 MOVE MOVE DMOB P 19:00 00:00 5.00 MOVE MOVE MOVE p 3/1/02 00:00 07:00 7,00 MOVE MOVE MOVE P 0' 0' 07:00 10:30 3.50 MOVE MOVE POSN P 0' 0' 10:30 16:30 6.00 1\10VE MOVE RURD P 0' 0' 16:30 21 :30 5,00 MOVE WELCTL NUND p 21:30 00:00 2.50 1\10VE DRILL PULD p http://bizak.ak, ppco.conv'n pr -a_ex p l/lookout2/sc ri pts/re ports/ opsum .asp 0' 0' 0' 0' 0' 0' 0' 0' 4/30/2002 .r AI Dri II ing 24 Hr Sumlload pipe shed, moving camp. 3/2/02 00:00 01:00 1.00 SURFAC DRILL OTHR P 0' 01 :00 02:00 1.00 SURFAC MOVE POSN P 0' 02:00 05:00 3,00 SURFAC DRILL OTHR P 0' 05:00 15:30 10,50 SURFAC DRILL PULD P 0' 15:30 16:30 1.00 SURFAC DRILL PULD P 0' 16:30 17:30 1.00 SURFAC DRILL PULD P 0' 17:30 18:00 0,50 SURFAC DRILL DRLG P 90' 18:00 23:00 5.00 SURFAC DRILL DRLG P 115' Page 2 of 11 0' Continue loading pipe shed & strap dp. Move in and spot camp 0' and rock washer complex, 0' R/U and prepare for spud, P/U 84 stands 4" dp, 6 0' stands 4" HWDP & 3 stands 5" HWDP. 0' P/U bha and steam, 0' M/U abbreviated bha, bit- motor-3 nm drill clrs. Flood conductor, check lIS' surface equipment & drill ice f/90-115'. 500' Spud and drill 12-1/4" f/115-500', ART 3.5 hrs 23:00 23:30 0.50 SURFAC DRILL CIRC P 500' 500' Circulate hole clean. 23:30 00:00 0.50 SURFAC DRILL TRIP P 500' 0' POH to p/u Iwd/mwd. 24 Hr Sum Load pipe shed & strap, spot camp & rock washer,p/u dp & HWDP, m/u bha, drill ice f/90-115', Spud and drill f/115-500', poh f/mwd-Iwd. 3/3/02 00:00 00:30 0.50 SURFAC DRILL TRIP P 0' 0' Continue poh to pickup mwd-Iwd tools. M/U mwd tools and 00:30 01:30 1.00 SURFAC DRILL PULD T EQIP 0' 0' Initialize same, one hour downtime due to tool problems. 01:30 04:00 2.50 SURFAC DRILL PULD P 0' a' M/U mwd tools and initialize. 500' RIH to 500' and survey, 500' 1,310' Drilled f/500-1310', ART 6.5 HRS. 1,310' 1 310' Circulate hole clean , w/sweep. Wiper trip to HWDP, no problems, maximum 1,310' 460' overpull 5K, no washouts, guage hole throughout trip. 460' 1 310' RIH, precautionary ream , 90' to bottom, no fill. 1,310' 1 980' Drilled f/1310-1980', ART , 7.6, AST .2 HR 24 Hr Sum Continue poh f/mwd-Iwd, P/U and initialize, rih to 500', drld f/500-1310', circulate btms up, Wiper trip to hwdp, no problems, rih, drld f/1310-1980'. 3/4/02 04:00 05:00 1.00 SURFAC DRILL TRIP P 05:00 13:30 8.50 SURFAC DRILL DRLG P 13:30 14:00 0.50 SURFAC DRILL CIRC P 14:00 15:00 1.00 SURFAC DRILL WIPR P 15:00 15:30 0.50 SURFAC DRILL WIPR P 15:30 00:00 8.50 SURFAC DRILL DRLG P 0' 00:00 04:30 4.50 SURFAC DRILL DRLG P 1,980' 2 364' Drilled f/1980-2364', ART , 3,5 HR. 04:30 05:00 0.50 SURFAC DRILL CIRC P 2,364' 2 364' Circulate hole clean and , observe well. Wiper trip to 1310', 05:00 07:00 2.00 SURFAC DRILL WIPR P 2,364' 1,310' Maximum overpull & drag 30k. http://bizak.ak. ppCO .conlln pr -3_e X p VI ookou t2/sc ri pts/reports/opSu m. as p 4/30/2002 .p AI Drilling Page 3 of 11 07:00 18:00 11.00 SURFAC DRILL DRLG P 1,310' 3, lOS' Drilled f/2364-3105', ART 9.3 HR, 18:00 19:00 1.00 SURFAC DRILL CIRC P 3,105' 3, lOS' Circulate hole clean, 19:00 20:00 1.00 SURFAC DRILL WIPR P 3,105' 2,175' Wiper trip to 2175'. 20:00 20:30 0.50 SURFAC DRILL TRIP P 2,175' 3,105' RIH to bottome, no fill. Circulate and condition 20:30 00:00 3.50 SURFAC DRILL CIRC P 3,105' 3,105' mud prior to POH f/casing. 24 H S Drilled f/1980-2364', CBU, wiper trip to 1310', RIH, drilled f/2364-3105', CBU, wiper trip to r um 2175', RIH, circulate and condition mud prior to POH f/caslng. 3/5/02 00:00 01:00 1.00 SURFAC DRILL CIRC P 3,105' 3 lOS' Circulate and condition , mud f/runnlng casing. 01:00 03:00 2.00 SURFAC DRILL TRIP P 3,105' 1,023' POH to 1023', maximum overpull 35k @ 1450'. Lay down BHA, stand back hwdp, lid 3- 8" drill 03:00 06:00 3.00 SURFAC DRILL PULD P 1,023' 0' clrs, read mwd, drain motor and break bit, pull mwd probe, I/d remaining bha. 06:00 07:30 1.50 SURFAC CASE OTHR P 0' O' Rig up to run 9-5/8" surface casing, PJSM, run 72 jts 9-5/8", 40#, 1-80 btc csg, land 07:30 13:30 6.00 SURFAC CASE RUNC P 0' 3,097' casing on hanger @ 3097' shoe depth, no problems rih. Establish circulation, 13:30 15:00 1.50 SURFAC CASE CIRC P 3,097' 3,097' stage up to 8 bpm, circulate and condition mud 2+ btms up. 15:00 15:30 0.50 SURFAC CEMENT PULD P 3,097' 3,097' Change out franks fillup tool to cementing head, Circulate and condition 15:30 16:30 1.00 SURFAC CEMENT CIRC P 3,097' 3,097' hole, PJSM on cementing, Batch up. Test lines and cement w/50 bbl cw100, 50 bbl 16:30 18:30 2.00 SURFAC CEMENT PUMP P 3,097' 3,097' mud push, 334 bbl lead cmt (Arctic Set Lite) @10.6ppg, 71 bbl Litecrete as per program. Displace cement w/mud w/rig pumps to calculated displacement (2157 18:30 19:30 1.00 SURFAC CEMENT DISP P 3,097' 3 097' stks), CIP @ 1920 hrs. , Bumped plugs w/1000# over (1500 psi), floats held. 135 bbls excess cement to surface. Rig down cementers, flush diverter system, 19:30 20:30 1.00 SURFAC CEMENT RURD P 3,097' 3,097' LID landing joint and casing tools, change out bails. 20:30 22:00 1.50 SURFAC WELCTL NUND P 3,097' 3,097' Nipple down diverter system. 22:00 22:30 0,50 SURFAC WELCTL NUND P 3,097' 3 097' Orient and nipple up Gen , V casing head. http://bizak. ak. ppco ,comlnpr -a_ex p l/lookout2/sc ri ptslreports/opsu m. as p 4/30/2002 PAl Drilling Page 4 of 11 \ 22:30100:00 1.50 ISURFACI WELCTL 1 NUND 1 P 1 13,097' 13,097' INiPPle up 13-5/8" bope. Circulate and condition hole and mud, POH, lid bha, rig up and run casing, cement per 24 Hr Sum program, displace w/rig to calc amt, bumped plugs, floats held, 135 bbl excess cmt, n/d diverter, n/u csg & bop's. 3/6/02 00:00 02:30 2.50 SURFAC WELCTL NUND P 0' 0' 02:30 03:30 1.00 SURFAC RIGMNT RGRP P 0' 0' 03:30 14:30 11.00 SURFAC WELCTL OTHR 0' P/U & M/U bha #2. 3 004' RIH and tag up 5' above , float collar @ 3004'. 3,004' 3,004' Circulate bottoms up. R/U, test & record 9-5/8" casing test to 2500 psi 3,004' 3,004' f/30 minutes-straight line, Witnessed by L. Bageley-BLM, Drilled cement f/3004- 3,004' 3,043' 3043. 5' cement on top of float collar. 24 Hr Sum Continue n/u bope, Test bope, witnessed by blm, m/u bha & rih, test C5g to 2500#, drill cement. 3,043' 3,105' Drill cement and float equipment, 3, lOS' 3,125' Drill 20' new hole f/3105- 3125'. 3,125' 3,125' Displace hole to new mud. 3,125' 3 125' Perform FIT to 14.5 ppg , equivalent mud weight. 3,125' 4450' Rotary Drill f/3125-4450', , ART 17.37 HR 24 H S Drill cement & float equipment, 20' new hole, displace hole to new mud, Perform FIT to 14,5 r um ppg e.m.w., Drill f/3125-4450'. 3/8/02 14:30 15:00 0.50 SURFAC DRILL 15:00 19:00 4.00 SURFAC DRILL 19:00 20:00 1.00 SURFAC DRILL 20:00 21:00 1.00 SURFAC DRILL 21 :00 22:30 1.50 INTRMl CASE 22: 30 00: 00 1,50 INTRM 1 DRILL 00:00 00:30 0.50 INTRM1 DRILL 00:30 01:00 0.50 INTRM1 DRILL 01:00 01:30 0.50 INTRM1 DRILL 01:30 02:30 1.00 INTRMl DRILL 02:30 00:00 21.50 INTRMl DRILL 00:00 12:00 12.00 INTRM1 DRILL 12:00 14:00 2.00 INTRM1 DRILL 14:00 15:00 1.00 INTRM1 DRILL 15:00 19:00 4.00 INTRM1 DRILL OTHR PULD TRIP CIRC DEQT DRLG DRLG DRLG CIRC FIT DRLG DRLG DRLG CIRC WIPR P 0' Continue nlppling up bope. Change out top drive grabber jaws. Test bope, 250 low, 3500 high-annular, 250/5000 rams & valves, 10 minutes each test straightline. Witnessed by L. Bagely-BLM, waived by C. Scheve-AOGCC. Install & lockdown double bowl protector. 0' p 0' 0' P 0' P 0' P p P 3/7/02 P p P p p P 5 153' Drilled f/4450-5153', ART , 9.6 HR. Drilled f5153-5249' w/reduced weight, 4k, 5,249' and higher rpm-180 to straighten hole. ART 1. 7 HR, 5,249' 5 249' Circulate hole clean, , monitor well, pump slug, 4,450' p 5,153' p P 5,249' 3,040' POH f/wiper trip to shoe, tight spots f/4739-3430' w/up to 70k intermittent http://bizak,ak . ppco ,com/n pr -a_ex p lIlookou t2/sc ri pts/re ports/opsum .asp 4/30/2002 .PAI Drilling Page 5 of II overpulls, appeared to be pulling balled stabilizers. No swabbing on trip, 3,040' 3,040' Service top drive. RIH, wash 90' to bottom, 3,040' 5,249' no fill. No problems or drag rih. 5,249' 5 450' Drilled f/5249-5450' w/4k , & 180 rpm. ART 3.3 HR. 24 H S Drilled f/4450-5153', drld f5153-5249' w/reduced wt & higher rpm to straighten hole,clrc, wiper r um trip to shoe, service top drive, rlh, drld f/5249-5450'. 3/9/02 19:00 19:30 0.50 INTRM1 RIGMNT RSRV P 19:30 20:00 0.50 INTRM1 DRILL WIPR P 20:00 00:00 4,00 INTRM1 DRILL DRLG P Drilled f/5450-6400', ART 19,0 hrs, Inclination 5,450' 6,400' down to .8 degrees w/rpm @ 180 and lower wob. 6,400' 6 400' Circulate bottoms up, , monitor well, pump slug. Wiper trip to 5140', 50k 6,400' 5 140' overpulls f/6020-5200', , no swabbing, monitor well. 5,140' 6 400' RIH, wash 90' to bottom, , no fill. 24 Hr Sum Drilled f/5450-6400', circ btms up, wiper trip to 5140', rih, wash 90' to btm, no fill. 3/10/02 00:00 21:30 21.50 INTRM1 DRILL DRLG P 21:30 22:00 0.50 INTRM1 DRILL CIRC P 22:00 23:30 1.50 INTRM1 DRILL WIPR P 23:30 00:00 0.50 INTRMl DRILL WIPR P 00:00 03:00 3.00 INTRM 1 DRILL DRLG P 6,400' 6,488' Drilled f/6400-6488', ART 2,7 HR. Circulate and condition while troubleshooting 03:00 04:30 1.50 INTRM 1 DRILL DEQT T EQIP 6,488' 6 488' mwd/lwd failure. , Circulate bottoms up, monitor well, pump dry job, blow down top drive. Trip out to 203', tight @ 5350' & 4650-4500' (75k 04:30 09:03 4.55 INTRM 1 DRILL TRIP T EQIP 6,488' 203' overpull), poh slowly f/4650' to shoe to prevent swabbing. BHA, rack back 1 stand 09:03 13:00 3.95 INTRM1 DRILL PULD T EQIP 203' 0' nmcd, I/d acoustic caliper, pjsm, pull sources, read mwd. 13:00 14:00 1.00 INTRMl DRILL PULD T EQIP 0' 0' LID all bha #2 mwd- no wet mwd connections. 14:00 18:30 4,50 INTRM1 DRILL PULD T EQIP 0' M/U bha #3, p/u & reconflgure motor, rr bit, 0' p/u new smart sub, scribe, program, initialize & load r.a. source, drop stabilizer. 3 100' RIH to 3100', shallow , test mwd. 3 100' S!ip & cut drlg Ii.ne, fill , pipe, grease sWivel. RIH to 6420', tight spots 6 420' @ 3750,3830 & 4560, fill , pipe and check f/plugged jets @ 4880'. 18:30 20:00 1.50 INTRMl DRILL TRIP T EQIP 0' 20:00 20:30 0.50 INTRM 1 RIGMNT OTHR T EQIP 3,100' 20:30 22:00 1.50 I NTR M 1 DRILL TRIP T EQIP 3,100' http://bizak.ak.ppco,com/npr-a_expUlookout2/scri pts/re ports/opsu m,as p 4/30/2002 EQIP 6,420' 6,488' Wash 68' to bottom, no fill, precautionary ream, Drilled f/6488-6525', 6,488' 6,525' plugged jet, AST ,2 HR, ART ,9 HR. 24 H S Drilled f/6400-6488', mwd/lwd failure, diagnose, trip out, replace mwd/lwd, rih w/motor bha, r urn drld f/6488-6525'. 3/11/02 .p AI Drilling 22:00 22:30 0.50 INTRM1 DRILL REAM 22:30 00:00 1.50 INTRM1 DRILL DRLG 00:00 00:00 24.00 INTRM1 DRILL 24 Hr Sum Drilled f/6525-7759'. DRLG 00:00 02:30 2.50 INTRM1 DRILL 02:30 03:30 1.00 INTRM 1 DRILL 03:30 05:00 1.50 INTRM1 DRILL 05:00 06:30 1.50 INTRM1 DRILL DRLG ClRC DRLG CIRC 06:30 09:00 2.50 INTRM1 DRILL WIPR 09:00 11 :00 2.00 INTRM 1 DRILL CIRC 11:00 15:30 4.50 INTRM 1 DRILL TRIP 15:30 19:00 3,50 I NTRM 1 DRILL PULD T P p 3/12/02 P p P P P P P P 19:00 21:00 2.00 INTRM 1 DRILL OTHR P 21:00 00:00 3.00 I NTRM 1 CASE RUNC P 24 Hr Sum 3/13/02 00:00 09:00 9,00 I NTRM 1 CASE RUNC P 09:00 11:00 2.00 I NTRM 1 CASE CIRC P 11:00 12:00 1.00 INTRM1 CASE CIRC P 12:00 15:00 3,00 INTRM1 CASE CIRC P 15:00 17:00 2,00 INTRM1 CEMENT PUMP P " . Page 6 of 11 6,525' 7,759' Drilled f/6525-7759', ART 18,1 HR, AST 1.1 HR. 7,759' 7,850' Drlg. from 7759 to 7850'. 7,850' 7 850' eirc. s~mples as per , geologist. 7,850' 7 893' Drlg. from 7850' to , 7893', 7,893' 7 893' Circ. samples=max gas , (486 units) Wiper trip to 6225' ( tight 7,893' 7,893' @ 6760' 6731'-6662' -30 to 75k over.) 7,893' 7 893' eirc. condition mud for , csg. 7,893' 0' POH to run 7" csg. (Flow check @ shoe.) Stand back 4"-5" & jars 7,893' 0' in derrick-down load mwd,s & lay down bha, Pull wear ring-Change 7,893' 0' top set rams to 7" & test same-change bails. 7,893' 0' Rig up & run 7" csg. 0' 0' 0' 0' 0' 0' 0' 0' 0' http://bizak,ak, ppco.conlln pr -a_exp Ulookou t2/sc ri pts/re ports/opsum, asp 0' Run 185 Jts. 7" csg. to 7838'-circ. capacity csg. @ 9 5/8" shoe. Hit bridge @ 7838'. Wash to bottom from 7838' to 7883'. Lay down fill up tool & make up cement head. Circ.-condition mud & hole for cementing. PJSM-Pump 10 bbl. CW 100-test cement lines to 3500#-pump 30 bbls, CW 100-drop bottom plug-pump 50 bbls. Mud push & 83 bbls. 12# cement-drop top plug & pump 10 bbl. water & 289 bbls. mud-bump plug on calculated displacement @ 1700 hrs. Rig down cement head- lay down landing jt,- 4/30/2002 PAl Drilling Page 7 of II 17:00 18:30 1.50 INTRM1 CEMENT OTHR P 0' 0' Install packoff & test same 5000# 10 mins, Change out top pipe 18:30 20:00 1.50 INTRH1 CEMENT OTHR P 0' O' rams to 3 1/2" X 6" variables-change bails & clear floor. 20:00 00:00 4.00 INTRrvl1 CEMENT SEQT P 0' 0' Rig up & test bope 250- 3500#. 24 Hr Sum 3/14/02 00:00 02:00 Install wear ring-lay 2.00 PROD DRILL PULD P 0' O' down 5" hwdp-change out jars. 02:00 07:00 5.00 PROD DRILL PULD P 0' 0' Pick up bha-sperry tools- 6 spiral wt.-etc. 07:00 10:30 3.50 PROD DRILL TRIP P 0' 0' Run in hole to 7610'- pulse test @ 4000'. 10:30 11:30 1.00 PROD DRILL CIRC P 0' 0' Condition mud to 9.5# for csg. test. 11:30 13:00 1.50 PROD DRILL DEQT P 0' 0' Rig up & test 7" csg. to 3500# for 30 mins. OK Drill plugs-float collar- cement-float shoe & 13:00 16:30 3.50 PROD DRILL DRLG P 0' 0' clean out to 7893'-wash down wi no rotation to tag bottom. 16:30 19:00 2.50 PROD DRILL CIRC P 0' 0' Displace well to 9,2# coring fluid. Shut down pumps to finish cleaning pits- 19:00 20:00 1.00 PROD DRILL OBSV P 0' 0' observe well-well flowing-shut in-120# on drill pipe-280# on CS9. Circ, out influx wi drillers method while preparing pits for coring fluid. Max 20:00 00:00 4,00 PROD DRILL OTHR T DH 0' 0' gas at surface when bottoms up 42 units- estimate approx. 2 bbl. kick. 24 Hr Sum 3/15/02 Monitor well for pressure- Clre, bottoms up wi drillers method-monitor well-pump 9,7# kill wt. 00:00 12:00 12.00 PROD DRILL OTHR T DH 0' 0' mud around-hole stili seeping-shut in-O pressure on dp-20# on csg.-pump 9.8# mud around-monitor well. (well Dead) 12:00 13:00 1.00 PROD DRILL TRIP P 0' 0' POH to 6845'. 13:00 13:30 0.50 PROD DRILL OBSV P 0' 0' Monitor well for flow, 13:30 19:00 5,50 PROD DRILL OTHR T EQIP 0' 0' Install new electric motor on top drive, 19:00 21:00 2,00 PROD DRILL TRIP P 0' 0' Pump dry job & poh for core bbl. 00:00 3.00 PROD DRILL PULD P 0' 0' Down load sperry equipment-lay down bha http://bizak. ak. ppco.conllnpr -a_e x p III ookout2/sc ri pts/repons/opsu m. as p ~/30/2002 PAl Drilling Page 8 of II 21:001 1& pick up core bbl. 24 Hr Sum 3/16/02 00:00 03:30 3.50 PROD CORE TRIP P 0' 0' Finish rih to 7880'. 03:30 05:00 1.50 PROD CORE CIRC P 0' 0' Circ, bottoms up & drop ball. Cutting core from 7894' to 7928'. (cut into shale stringer) Change of C. ù¡~ 05:00 10:00 5.00 PROD CORE CORE P 7,894' 7 928' formation-gas units up to , 1070. Penetration slowed-appears to be jammed or hard formation, 10:00 10:30 0.50 PROD CORE CIRC P 7,928' 7,928' Circ,-monitor well-pump slug. 10:30 19:00 8.50 PROD CORE TRIP P 7,928' 0' Pull out of hole as per core pulling schedule. Lay down core, (IL' (Recovered 32,5' of core) CD 19:00 20:00 1.00 PROD CORE RCVR P 7,928' 0' Shale in bottom of core- clean break-appears bbl. wasn't jammed. 20:00 00:00 4,00 PROD CORE TRIP P 7,928' 0' Trip in hole-fill pipe @ 4264'. 24 Hr Sum 3/17/02 00:00 00:30 0.50 PROD CORE TRIP P 0' 0' Trip in hole wI core bbl. to 7893', 00:30 02:00 1.50 PROD CORE CIRC P 0' 0' Circulate bottoms up & drop ball. O(~ 02:00 08:00 6.00 PROD CORE CORE P 7,928' 7 931' Coring hard shale from C , 7928'to7931'. Monitor well-pump dry 08:00 09:00 1.00 PROD CORE OTHR P 7,931' 7,931' job & blow down top drive. 09:00 12:00 3.00 PROD CORE TRIP P 7,931' 0' Pull out of hole for bit. Lay down core & core ¡tJ- 12:00 13:00 1.00 PROD CORE PULD P 7,931' 0' bbl. recovered 2' of core c..C (Shale) 13:00 16:30 3,50 PROD DRILL PULD P 7,931' 0' Make up bha-upload & test mwd, 16:30 19:00 2.50 PROD DRILL TRIP P 7,931' 0' Run in hole-fill pipe @ 5300'. 19:00 20:00 1.00 PROD DRILL OTHR P 7,931' 0' Slip & cut drlg, line. Tie in to pip @ 7" float 20:00 22:30 2,50 PROD DRILL OTHR P 7,931' 0' collar & mad pass to bottom, 22:30 00:00 1.50 PROD DRILL DRLG P 7,931' 7,974' Drlg, as per geologist. 24 Hr Sum 3/18/02 00:00 09:00 9,00 PROD DRILL DRLG P 8,125' 8 200' Drilling to TD from 8125' , to 8200' TD. 09:00 10:00 1.00 PROD DRILL CIRC P 8,200' 8,200' Circ. condition hole for wiper trip. 10:00 10:30 0.50 PROD DRILL WIPR P 8,200' 0' Wiper trip-hole swabbed for 2 stands. http://bi zak. ak. ppco.comJnpr -a_ex pUlookollt2/scripts/reports/opsu In,as p 4/30/2002 PAl Drilling Page 9 of 11 10:30 11:30 1.00 PROD DRILL CIRC P 8,200' 0' Cire. condition hole for logs. Monitor well-pump pill- 11:30 15:00 3,50 PROD DRILL TRIP P 8,200' 0' blow down top drive & poh, 15:00 16:30 1.50 PROD DRILL PULD P 8,200' O' Down load mwd-Iay down bha. 16:30 00:00 7.50 PROD LOG ELOG P 8,200' 0' PJSM-Rlg up sws & run (FMI-dipole-sonic logs. 24 Hr Sum 3/19/02 Run Wire line logs from 8200' to 7883' (7" shoe) 00:00 17:00 17.00 PROD LOG ELOG P 8,200' 8,200' FMI-dlpole sonic-Platform express-rerun cmr, Lay down logging tools & rig down sws, Pull wear ring-set test plug & test bope 250- 3500#. Pull test plug-set 17:00 23:00 6,00 PROD LOG OTHR P 8,200' 0' wear ring-blow down choke lines. (Witness test waived by John Spalding AOGCC) Make up bha & rih to condition. (Hot Oil Arrived @ 2300 Hrs.- 23:00 00:00 1.00 PROD LOG OTHR P 8,200' 0' Rigged up on annulus & attemtlng to break down formation @ 2000 # -no success as of 0600 hrs.) 24 Hr Sum 3/20/02 00:00 04:00 4,00 PROD LOG TRIP P 0' 7,880' Run in hole wi clean out assembly to 7880'. 04:00 04:30 0.50 PROD LOG CIRC P 7,880' 8 200' Wash to bottom from , 7880 to 8200', 04:30 06:00 1.50 PROD LOG CIRC P 8,200' 0' (ire, hole clean. (no gas) 06:00 06:30 0,50 PROD LOG OTHR P 8,200' 0' Wiper trip (no Problems) 06:30 07:30 1.00 PROD LOG CIRC P 8,200' 0' Circulate hole clean. 07:30 11:00 3.50 PROD LOG TRIP P 8,200' 0' Observe well & poh. Rig up sws & run usn- 11:00 15:00 4.00 PROD LOG ELOG P 8,200' 0' rig down sws. (USIT showed 76' cement above 9 5/8" shoe,) 15:00 18:00 3.00 PROD LOG TRIP P 8,200' 0' Make up bha & rih wi clean out assembly, 18:00 22:30 4.50 PROD LOG CIRC P 8,200' 0' Circ, hole clean while waiting on mdt log, 22:30 00:00 1.50 PROD LOG TRIP P 8,200' 0' Tools arrived=observe well & poh for MDT, 24 Hr Sum 3/21/02 00:00 01:30 1.50 PROD LOG TRIP P 0' 0' POH for MDT log. 01:30 05:00 3,50 PROD LOG PULD P 0' 0' PJSM-Make up MDT logging tool. 05:00 09:00 4.00 PROD LOG DLOG P 0' 0' Run in hole wi MDT on h ttp:1 fb izak. ak. ppco .conlln pr -a_ex p III ookou t 2/sc ri pts/reports/ ops U n1. as p 4/30/2002 PAl Drilling Page 10 0 f I 1 drill pipe to 7668', 09:00 10:30 1.50 PROD LOG CIRC P 0' 0' Circ. dp clean for wet connect. Make up side door entry 10:30 13:00 2.50 PROD LOG ELOG P 0' 0' sub & rih wI wire line- latch up & test tool. Take formation & 13:00 00:00 11. 00 PROD LOG OTHR P 0' 0' pressure samples@15 different spots. 24 Hr Sum 3/22/02 00:00 01:30 1.50 PROD LOG PULD P 0' 0' Pull 'E' line & rig down Side entry sub, 01:30 04:00 2.50 PROD LOG DLOG P 0' 0' POH wI MDT on 4" drill pipe. 04:00 07:00 3.00 PROD LOG PULD P 0' 0' Lay down MDT tools. r~1ake up & rih on 'E' line- (IJ~ sidewall samples tool-poh / {L- 07:00 11:30 4,50 PROD LOG ELOG P 0' 0' & lay down same-rig CÒ down sws (recovered 100% on shots,) PJSM-Rig up & pick up 14 11:30 17:00 5,50 PROD CASE RUNL P 0' 0' jts, 4.5" liner & rih to 5200'. 17:00 17:30 0.50 PROD CASE CIRC P 0' O' Circ, bottoms up-max gas 890 units. Run in hole to shoe @ 17:30 19:00 1.50 PROD CASE RUNL P 0' 0' 7883'-make up cement manifold. 19:00 20:30 1.50 PROD CASE CIRC P 0' 0' Cire. bottoms up @ shoe- max gas 2700 units. 20:30 21:00 0,50 PROD CASE RUNL P 0' 0' Run In hole to 8200'-no hole problems. Make up cement manifold 21 :00 00:00 3.00 PROD CASE CIRC P 0' 0' & eire, condition hole for cementing. 24 Hr Sum 3/23/02 00:00 01:00 1.00 CMPLTN CMPLTN CIRC P 0' 0' Clrc. condition mud & hole for cementing. Pump 10 bbls. CW 100- test lines to 4500#-Pump 20 bbls. CW 100-40 bbls. 01 :00 02:30 1.50 CMPLTN CEMENT PUMP P 0' 0' mud push @ 11#-17 bbls. 15.8# cement & displace w/ 40 bbl. perf pill & 46 bbls. mud. (Full returns-Bump plug) Set Packer w/ dowell @ 02:30 03:00 0.50 CMPL TN CEf-1ENT OTHR P 0' 0' 4200# pressure-release from liner. Pump 10 bbls. mud long way & reverse circ,- 03:00 04:30 1.50 CMPLTN CEMENT CIRC P 0' 0' recovered 4 bbl, cement & flushes + 30 bbls, perf pill-eire, hile clean. 04:30 06:00 1.50 Cf-1 PL TN CEMENT CIRC P 0' 0' Displace well to 9.8# Brine, 06:00 12:00 6,00 Cf-1 PL TN CEMENT TRIP P 0' 0' POH laying down 4" DP & http://bizak.ak. ppco,com/n pr -a_ex p Iflookout2/sc ri pts/reports/ opsum .as p 4/30/2002 PAl Drilling Page 11 of 11 HWDP out of derrick. Rig up & run 148 jts, 4,5" 12:00 21:00 9,00 CM PL TN CMPLTN RUNT P 0' 0' tbg. as per program & space out, 21:00 21:30 0.50 CMPL TN CMPLTN CIRC P 0' 0' Clrc. tbg, volume. Attempting to test liner & packer-broke down @ 21 :30 00:00 2.50 CMPLTN CMPLTN DEQT P 0' 0' 2100#-bleeds to 1000#- sting in test tbg, 3500# OK. 24 Hr Sum 3/24/02 Test production csg. to 00:00 01:00 1.00 CM PL TN CM PL TN DEQT P 0' 0' 3500# 30 mins, -chart same. 01:00 03:30 2.50 CM PL TN CMPLTN SOHO P 0' 0' Space out-land hanger & RILDS. Testtbg. 3500# 15 03:30 04:30 1.00 CMPLTN CMPLTN DEQT P 0' 0' mins.-test annulus 3000# 15 mins.-Shear rp valve. 04:30 05:00 0.50 CMPLTN CM PL TN OTHR P 0' 0' Lay down landing jt. & install 2 way check. 05:00 08:30 3.50 CM PL TN CMPLTN OTHR P 0' O' Nipple down bope & nipple up tree. 08:30 09:30 1.00 CM PL TN CM PL TN SEQT P 0' 0' Test packoff to 5000#- test tree 250-5000# OK. 09:30 10:30 1.00 CM PL TN CMPLTN FRZP P 0' 0' Freeze protect well wi 85 bbls. diesel. Rig up Hawco slick line- 10: 30 13: 30 3.00 CMPLTN CMPLTN SLIN P 0' O' run Gauge ring-pull rp valve & set dummy valve. Rig down slick line, Pump down annulus wi 13:30 15:00 1.50 CM PL TN CM PL TN DEQT P 0' 0' hot oil & test liner lap 3500 30 mins. OK. 15:00 18:00 3.00 CM PL TN CM PL TN OTHR P 0' 0' Clean mud tanks & prepare for rig, move, 24 Hr Sum ~. ~ http://bizak.ak . ppco.comln pr -3- ex pIli ookou t2/sc ri pts/reports/ ops um. as p 4/30/1001 Tom J Brassfield " 05/07/2002 07: 17 AM To: Sharon AlIsup-Drake/PPCO@ Phillips cc: Subject: Lookout #2 Sharon, here are the P&A reports for Lookout #2. Thanks, Tom 265-6377 (w) 275-7352 (p) 265-6916 (f) _n_- Forwarded by Tom J Brassfield/PPCQ on 05/07/2002 07:17 AM ----- Donald C Lutrick 05/06/200204:29 PM To: Tom J Brassfield/PPCQ@Phillips, Paul Mazzolini/PPCQ@Phillips cc: Subject: Lookout #2 4/26/02 Halliburton retrieved Spartek gauges from XN nipple at 7680'. Orfice valve was removed from mandrel at 2492' and a dummy valve was installed. SITP - 1000 psi. Bled annulus from 1000 psi to 0 psi. All DV1s holding. 4/27/02 Had blizzard warning Friday night and Saturday morning. Had scaffolding crew and roustabouts on location at 1500 hrs. Remove top 101 of scaffolding. ND upper and lower flow crosses, swab valves and wing valves. Installed tree cap on top of double master valves. Installed visqene on scaffloding and placed heater on outer annulus valve. 4/28/02 RU Dowell. RU Halliburton slickline. PJSM. SITP - 1000 psi. Test lines to 3500 psi. Pump 120 bbls 9.8 brine at 5.5 bpm. Final injection pressure - 20 psi. Well on vacuum. Halliburton ran in hole to check fluid level. 800' in 15 mins. RD Halliburton. Pump 10 bbls FW, appprox 26.1 bbls - 126 sx - 15.8 cement ( 1 st 5 bbls neat, 10 bbls wI 15 ppb aggregate and remaining neat), 50 bbls FW and 46 bbls 9.8 brine. Cement to perfs. Well on vacuum at 3 bpm. Vacuum stop with 5 bbls cement into perfs. Rolled pumps. Sqeezed additional 1.5 bbls cement into perfs at 1200 psi. Bled to 200 psi in 10 min. SWI. Blow down lines. Schlumberger unable to be on location until late Sunday night. Postponed job till 9:00 Monday morning. 4/29/02 Schlumberger did not arrive on location till 11 :00 am. (Got stuck in front of 141 rig move) RU SWS. RIH and tag cement at 65721. Tag witnessed by AOGCC rep John Spalding. Winds gusting in excess of 35 mph. RD SWS. Escort all equipment (excluding Dowell cement van) and personnel to 2L pad with a loader. 4/30/02 Wait on weather. 5-1-02 Wait on road to be opened to location. 5-2/3-02 RU SWS. Punch holes in 4 1/2" tbg at 65651 and 6567'. RU Dowell. Test csg and tbg to 1500 psi for 15 mins OK. Pump 83 bbls 9.8 brine, 10 bbls FW, 16 bbls (77 sx) 15.8 cement, 8 bbls FW and 84 bbls 9.8 brine. Est TOC in tbg and annulus at 60941. RU SWS. RIH w 3.76 GR to 2492'. (Tied into upper GLM) Flag line at 1000'. RIH and set Baker Model K cement retainer at 1000'. RIH wI 3 3/8'1 gun wI 348 HJ charges and perlorate 6 spf fl 9901 to 995'. RD SWS. Esf circulation in 9 5/8" x 7" annulus. Pump 30 bbls brine to clear annulus. Pump 44 bbls (265 sx) 15.8 AS1 down tbg and up 9 5/811 X 7" annulus. Cement to surlace. Open 4 1/2" x 7" annulus and pump 18 bbls (109 sx) 15.8 AS1 cement. Cement to surlace. Pumped 4.5 bbls (27 sx) to empty tub. Had returns out both annuli. Secure well. RD Dowell. 5-4-02 Heavenly #1 Dig out cellar and around conductor with trackhoe. Cut off 9 5/8" csg and 16" conductor 31 below original pad level. Hard cement in 9 5/8" csg. Top off 16" x 9 5/8" with dry cement. Weld on ID plate. Back fill hole. Top off with dirt and gravel from conductor hole. Surface P & A witnessed by AOGCC rep Chuck Scheve. 5-5-02 Lookout #2 Dig out cellar and around conductor with trackhoe. Cut off 16",95/8",7" and 4 1/2" 3' below original pad level. 4 1/2" tbg and all annuli have hard cement at surlace with no channels. Weld on ID plate. Top off with dirt and gravel from conductor hole. Surface P & A witnessed by AOGCC rep Chuck Scheve. ; Phillips Alaska, Inc. Sidewall Sample Description Operator and Well Name Page of Phillips Alaska, Inc. Lookout#2 1 14 Location Date NPRA eastern area Note: These cores are being described several weeks after they were acquired. 4/22/2002 Shot Recovered Shot 24 24 Depth Rae. Descnptlon Oil Odor 011 Fluor Cut Cut Show ft. in. Slain ()c Intensity Color color fluor color sum 7893 0,75 None Faint 80% Medi yellow No Slow Sandstone, light brown, vfL-fL, quartz petro urn visible streamin with 5°10 medium bright green leum cut g blue- glauconite, some glauconite grains are white cut outsized up to fU, subang, mod sorted, slightly calc, appears silty although very invaded with brown drilling mud, Evidence of degassing in drilling mud sheath 7892.5 0.75 Sandstone, medium brown, vfL-fL, None None Non None Instant, quartz with 5% glauconite, 2/3 is e very pale medium bright green, 1/3 is black- milky cut green, very silty, poorly sorted, appears tight, very calc. 7892 0.75 1/2 appears to be sandstone with 1/2 None None 30% Medi None Instant, mudcake, Sandstone, light brown, vfL- urn Yello -very very pale fL, quartz with 5°10 medium bright w pale milky, green glauconite, some glauconite straw with slow grains are outsized up to fU, subang, streamin very calc, mod sorted, appears silty g blue- white 7891.5 0.75 Sandstone, vfL-fU, quartz and 3-4% None Faint 40% Pale Yello none Instant, medium green glauconite, very silty, petro w very pale also appears to be invaded by drilling leum milky cut mud, subang-subrd, poorly sorted, moderately calc. 7891 0.75 Sandstone, vfL-fU, quartz and 5% None Sligh 60% Very Yello none Instant, medium green glauconite, very silty, t pale w very pale subang-subrd, poorly sorted, Petro milky, moderately calc. with slow leum streamin g blue- white 7890.5 1.0 Sandstone, vfL-fU, quartz and 3-4% None Faint 90% Pale Yello none Instant, medium green glauconite, sl silty, petro w pale subang-subrd, mod sorted, very calc. leum milky cut Remarks All of these SWCs were taken from an interval that was drilled with 11.3 mw in 8 %" hole. Casing was set 1 0' off the base of the 8 %' hole. After cementing the well was 7" well bore was drilled with a 9.3 calcium carbonate drilling mud, Both the cement and carbonate maybe effecting how calcareous the formation truly is, Described by D.Bannan AR3B-2389-B Operator and Well Name Page of Phillips Alaska, Inc. Lookout#2 2 14 Location Date NPRA eastern area Note: These cores are being described several weeks after they were acquired. 4/22/2002 Shot Recovered Shot 24 24 Depth Ree. Descnplion Oil Odor 011 Fluor Cut Cut Show ft. in. Slain 0' Intensity Color color fluor color sum :0 7890 1.0 Sandstone, vfL-fL, quartz and 5~~ None None 30% Very Vello None Slow, medium green glauconite, silty, pale w very pale subang-subrd, poorly sorted, mod calc milky cut, with slow streamin g blue- white 7889.5 0.5 . Sandstone, vfL-fL, quartz and 3-4% None None 30% Very Yello None Instant, medium green glauconite, sl silty, pale w pale subang-subrd, mod sorted, slightly milky cut calc., appears invaded with drilling mud 7889 1.0 Sandstone, vfL-fL, quartz and 3-40/0 None None 10% Very Yello None Slow, medium green glauconite, silty, pale w very pale subang-subrd, poorly sorted, slightly milky cut calc., appears invaded with drilling mud 7888.5 1.0 Sandstone, vfL-fL, quartz and 2-3% None None 10% Very Yello None Slow, medium green glauconite, silty, pale w very pale subang-subrd, mod-poorly sorted, mod milky cut calc. 7888 1.0 Sandstone, vfL-fL, quartz and 2-3% None None 40% Pale Vello None Instant, light green glauconite, mod silty, w pale subang-subrd, mod sorted, mod calc. milky cut, Mottled texture with slow streamin g blue- white 7887.5 1.0 Sandstone, vfL-fU, quartz and 2-3% None None 70% Pale Vello None Instant, light green glauconite, sl. silty, subang- w pale subrd, mod sorted, slight calc. Mottled milky cut, texture 7887 0.75 Sandstone, vfL-fL, quartz and 3-4% None None 10% Very Yello None Slow, green glauconite, silty, subang-subrd, pale w very pale poorly sorted, very calc., appears milky cut invaded with drilling mud Remarks Described by 0 Bannan Operator and Well Name Page of Phillips Alaska, Inc, Lookout#2 3 14 Location Date NPRA eastern area Note: These cores are being described several weeks after they were acquired. 4/22/2002 Shot Recovered Shot 24 24 Depth Rec. Descnptlon Oil Odor 011 Fluor Cut Cut Show ft. in. Stam 0 Intensity Color color fluor color sum .0 7886.5 1,0 Sandstone, white to light brown, vfL- Patchy Mod 100 Mode Vello None Instant, fU, quartz and 5% green glauconite, light erate % rate w moderat subang-subrd, mod-well sorted, mod brown petro e, milky calc. Mottled texture leum cut, with slow streamin g blue- white 7886 1.0 Sandstone, white to light brown, vfL- None Faint 100 Mode Vello None Instant, fU, quartz and 3-4% green glauconite, petro 0' rate w moderat 70 subang-subrd, mod-well sorted, sl silty, leum e, milky slightly-mod calc. Mottled texture cut, slow streamin g blue- white 7885.5 0.5 Sandstone, white to light brown, vfL- None None 90% Mode yellow None Instant, fU, quartz and 3-4~.~ green glauconite, rate moderat subang-subrd, mod-well sorted, sl silty, e, milky mod calc. Mottled texture cut, slow streamin g blue- white 7885 0.75 Sandstone, white to light brown, vfL-fL, None Faint 80% Mode Yello None Instant, quartz and 3-4% green glauconite, petro ate w moderat subang-subrd, mod sorted, sl silty, eum e, milky mod calc. Mottled texture, also cut, slow appears invaded by drilling mud stream in g blue- white 7884.5 0.75 Sandstone, light brown, vfL-fU some None None 70% Mode Vello none Instant, outsized grains to mL, quartz and 3- rate w moderat 4% green glauconite, subang-subrd, e, milky mod sorted, sl silty, sl calc. Mottled cut, slow texture, streamin g blue- white 7884 1.0 Sandstone, white-light brown, vfL-fU, None None 100 Mode Vello none Instant, quartz and 5~/o green glauconite, 01 rate w pale, /0 subang-subrd, well sorted, sl calc. milky cut, Mottled textu re. Remarks Described by 0 Bannan Operator and Well Name Page of Phillips Alaska, Inc. Lookout#2 4 14 Location Date NPRA eastern area Note: These cores are being described several weeks after they were acquired. 4/22/2002 Shot Recovered Shot 24 24 Depth Rec Descnption 011 Odor 011 Fluor Cut Cut Show ft. in. Stam 0' Intensity Color color fluor color sum 0 7883.5 0.25 Mudcake 7883 0.25 Mudcake 7882.5 0.5 Sandstone, light-med brown, vfL-fL, None None 90% Mode Yello None Instant, quartz and 2-3% green glauconite, rate w moderat subang-subrd, mod sorted, silty, mod- e, milky very calc. Mottled texture cut 7882 0.75 Sandstone, light brown, vfL-fL, quartz None None 80% Mode Yello none Instant, and 2-3% green glauconite. subang- rate w pale, subrd, mod sorted, silty, mod calc. milky cut 7881.5 0.85 Sandstone, light brown, vfL-fU, quartz None Faint 100 Mode Yello None Instant, and 2-3% green glauconite, subang- etrol % rate- w moderat subrd, mod-well sorted, sl silty, sl calc. eum bright e, milky cut, slow streamin 9 blue- white Remarks Described by 0 Bannan Phillips Alaska, Inc. Core Chip Description Operator and Well Name: Section of Phillips Alaska Lookout #2 I Location: Date NPRA 16-Mar-Q2 Core #1 Recovered: Described by David Bannan, Laura Silliphant, David Katz cut 34' recovered 32.5' Depth Rec Description Oil Oil Fluor. Cut Cut Show fl. in. Stain Odor 0/0 Int Color Color Fluor color Sum -- 4" of medium to dark grey cement wI medium to 7894' coarse sandstone scattered through. Below the cement was a uniform very fine to fine grain sandstone that was not sampled Sandstone, vfL to fU average fL, quartz clear and milky subrounded to sub angular, with 10% glauconite, medium to bright green, slightly mottled texture with slight variations in clay content 7897' (burrows?), non calc., mod, sorting,good visual P&P strong petroleum odor, light to medium brown staining, 100% moderate to bright yellow fluor" instant blue-white cut fluor, straw visible cut, light 100% strong brown visible dried ring, bright yellow dried ring Light petroleu mod to instant blue- fluor. brown m 100 bright yellow straw white excellent Sandstone, vfL to vfU average vfU, quartz clear and milky subrounded to sub angular, with 10-12% glauconite, medium to bright green, flecks of mica, 7899.5' well to moderate sorting, good visual P&P strong petroleum odor, light to medium brown staining. 100% moderate to bright yellow fluor., instant blue- 100% strong white cut fluor, darkstraw visible cut, light brown Light petroleu mod to dark instant blue- visible dried ring, bright yellow dried ring fluor, brown m 100 bright yellow straw white excellent Phillips Alaska, Inc. Core Chip Description Operator and Well Name: Section of Phillips Alaska Lookout #2 I Location: Date NPRA 16-Mar-02 Core #1 Recovered: Described by David Bannan, Laura Silliphant, David Katz cut 341 recovered 32.5' Depth Rec Description Oil Oil Fluor. Cut Cut Show ft. in. Stain Odor DID Int Color Color Fluor color Sum Sandstone, vfL to vfU average vfU, quartz clear and milky subrounded to sub angular, with 10-15% glauconite. medium to bright green, flecks of mica, 7902.5' well sorting, good visual P&P strong petroleum odor, light to medium brown staining, 100% moderate to bright yellow fluor" instant blue-white 100% strong cut fluor, dark straw visible cut, light brown visible Light petroleu mod to dark instant blue- dried ring, bright yellow dried ring fluor. brown m 100 bright yellow straw white excellent Sandstone. vfL to fU average fL, quartz clear and milky sub rounded to sub angular, with 15% glauconite, medium to bright green, mottled texture, 7905.5' slightly calc., well sorting. rare clay clast 1-2 mm in diameter, good visual P&P strong petroleum odor, light to medium brown staining, 100% moderate to bright yellow fluor., instant blue-white cut fluor, pale 100% strong straw visible cut, pale straw visible dried ring, bright Light petroleu mod to instant blue- yellow dried ring fluor. brown m 100 bright yellow pale straw white excellent Phillips Alaska, Inc. Core Chip Description Operator and Well Name: Section of I Phillips Alaska Lookout #2 Location: Date NPRA 16-Mar-02 Core #1 Recovered: Described by David Bannan, Laura Silliphant, David Katz cut 34' recovered 32.5' Depth Rec Description Oil Oil Fluor. Cui Cut Show ft. in. Stain Odor % Int Color Color Fluor color Sum Sandstone, vfL to fU rare mU, average vfU, quartz clear and milky sub rounded to sub angular, with 15% glauconite, medium to bright green, mottled texture, non calc., well sorting, good visual P&P 7908.5' strong petroleum odor, light to medium brown staining, 100% moderate to bright yellow fluor" instant blue-white cut fluor, pale straw visible cut, 100% strong light brown visible dried ring, bright yellow dried ring Light petroleu mod to instant blue- fluor. brown m 100 bright yellow straw white excellent Sandstone, vfL with abundant silt, quartz clear and milky. sub angular, with 5-8% glauconite, medium to bright green, mottled texture, non calc., 7911.5' moderate sorting, light to medium brown staining, 1 oo~,~ moderate to bright yellow fluor., instant blue- 100% strong white cut fluor, light brown visible dried ring, bright Light petroleu mod to instant blue- yellow dried ring fluor. brown m 100 bright yellow white very good Sandstone, vfL to vfU, average vfL, quartz clear and milky subrounded to sub angular, with 5-8% glauconite, medium to bright green, mottled texture, non calc" moderate to well sorted, good visual P&P 7914.5' strong petroleum odor, light to medium brown staining, 100% moderate to bright yellow fluor., instant blue-white cut fluor, pale straw visible cut, 100% strong light brown visible dried ring, bright yellow dried ring Light petroleu mod to instant blue- fluor. brown m 100 bright yellow white very good Phillips Alaska, Inc. Core Chip Description Operator and Well Name: Section of Phillips Alaska Lookout #2 I Location: Date NPRA 16-Mar-Q2 Core #1 Recovered: Described by David Bannan, Laura Silliphant, David Katz cut 34' recovered 32.5' Depth Rec Description Oil Oil Fluor. Cut Cut Show tt in Stain Odor 0' Int Color Color Fluor color Sum ,0 Sandstone, vfL to vfU, average vfU, quartz clear and milky sub rounded to sub angular, with 5-8% glauconite, medium to bright green, mottled texture, non calc., moderate to well sorted, good visual P&P 7917.5' strong petroleum odor, light to medium brown staining, 80-90% moderate to bright yellow fluor., instant blue-white cut fluor, pale straw visible cut, 80-90% strong light brown visible dried ring, bright yellow dried ring Light petroleu mod to instant blue- fluor. brown m 80-90 bright yellow white very good Sandstone, vfL to vfU, average vfL, quartz clear and milky, sub angular, with 5-8% glauconite, medium to bright green, mottled texture, non calc., poor to moderate sorting, reduced visual P&P 7920.5' compared to above, strong petroleum odor, light to medium brown staining, 70-80% dull to moderate yellow fluor., instant blue-white cut fluor, pale straw 70-80% strong visible cut, light brown visible dried ring, bright Light petroleu dull to instant blue- yellow dried ring fluor. brown m 70-80 mod yellow white moderate Phillips Alaska, Inc. Core Chip Description Operator and Well Name: Section of Phillips Alaska Lookout #2 I Location: Date NPRA 16-Mar-02 Core #1 Recovered: Described by David Bannan, Laura Silliphant, David Katz cut 34' recovered 32,5' Depth Rec Description Oil Oil Fluor. Cui Cut Show ft. in. Stain Odor 01 Int Color Color Fluor color Sum 10 Sandstone, vfL to vfU, average vfL, quartz clear and milky, sub angular, with 5-8% glauconite, medium to bright green, mottled texture, non calc., poor to moderate sorting, continued reduction in 7923.5' visual P&P, strong petroleum odor, light to medium brown staining, 70-80% very dull yellow fluor., instant blue-white cut fluor, pale straw visible cut, 70-80% light brown visible dried ring, bright yellow dried ring Light moderat instant blue- fluor, brown e petrol. 70-80 very dull yellow white moderate Silty shale/shaley siltstone, brownish-g ray , highly 7926.5' indurated, trace glauconite, dull green, mottled texture, non calc., little to no visual P&P, minor cut fluor probably due to contamination no no nla nla none 7928' Same as above, without glauconite no no nla nla none Phillips Alaska, Inc. Core Chip Description Operator and Well Name: Section of Phillips Alaska Lookout #2 Location: Date NPRA 17-Mar-02 Core #2 Recovered: Described by Laura Silliphant and David Katz cut 3.8' recovered 2.25' Depth Rec Description Oil Oil Fluor. Cut Cut Show ft. in. Stain Odor % Int Color Color Fluor color Sum 7928' Silty shale/shaley siltstone, brownish-gray, highly no no no n/a pale yellow- poor indurated and dense, dull green, mottled texture, blue-white non calc., little to no visual P&P, minor cut fluor confirmed (probably NOT due to uphole contamination) 7928.3' Silt and clay sized particles (non-lithified), brownish- no no no n/a blue-white poor gray, poor1y sorted, matrix contains cU sized clasts streaming of clay and silt 7930.3' Silty shale, light gray, highly indurated and dense, no no no n/a pale yellow- poor moderate to well sorted, little to no visual P&P, blue-white apparent mica flecks . ,....-'.'---. --.. --.. .-. - .~ Kuparuk River Unit North Slope, Alaska Exploration 2002, Slot Lookout #2 Lookout #2 Job No. AKMW22023, Surveyed: 18 March, 2002 SURVEY REPORT 21 March, 2002 Your Ref: 501032041000 Surface Coordinates: 5955053.92 N, 314046.81 E (70016' 55.7472" H, 151030' 17.4052" W) Kelly Bushing: 49. 10ft above Mean Sea Level SpE!r"'I'Y-SUI'l DRILLING SERViceS A Halliburton Company - - CONFIDENTIAL Survey Ref: svy9848 - - - - - - - - - - - - - - - - - - - ".":"(--':" . . -'::".. . Sperry-Sun Drilling Services Survey Report for Lookout #2 CONFmEN1\~l Your Ref: 501032041000 Job No. AKMW22023, Surveyed: 18 March, 2002 North Slope, Alaska Kuparuk River Unit Exploration 2002 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -49.10 0.00 0.00 N 0.00 E 5955053.92 N 314046.81 E 0.00 MWD Magnetic 110.00 0.000 0.000 60.90 110.00 0.00 N 0.00 E 5955053.92 N 314046.81 E 0.000 0.00 402.24 0.440 230.210 353.14 402.24 0.72 S 0.86W 5955053.22 N 314045.93 E 0.151 -0.72 492.97 0.570 236.060 443.86 492.96 1.19 S 1.50W 5955052.76 N 314045.28 E 0.154 -1.19 584.81 0.570 253.340 535.70 584.80 1.58 S 2.32W 5955052.40 N 314044.45 E 0.186 -1.58 678.16 0.570 249.960 629.04 678,14 1.87 S 3.20W 5955052.13 N 314043.56 E 0.036 -1.87 771.30 0.640 244.570 722.18 771.28 2.25 S 4.11 W 5955051.77 N 314042.65 E 0.097 -2.25 863.94 0.880 255.420 814,81 863.91 2.65 S 5.26W 5955051.40 N 314041 .48 E 0.301 -2.65 956.31 1.100 258.700 907.17 956.27 3.01 S 6.82W 5955051.08 N 314039.92 E 0.246 -3.01 1052.37 1.120 260.850 1003.21 1052.31 3.345 8.65W 5955050.80 N 314038.08 E 0.048 -3.34 1148.86 1.130 274.850 1099.68 1148.78 3.41 S 10.53 W 5955050.77 N 314036.20 E 0.284 -3.41 1243.30 1.200 279.150 1194.10 1243.20 3.17 S 12.43 W 5955051.06 N 314034.30 E 0.119 -3.17 1339.16 1.220 271.870 1289.94 1339.04 2.985 14.44 W 5955051.30 N 314032.30 E 0.162 -2.98 1436.22 0.700 275.080 1386.99 1436.09 2.89 S 16.07 W 5955051.43 N 314030.68 E 0.538 -2.89 1532.42 0.390 288.470 1483.18 1532.28 2.74 S 16.96 W 5955051.60 N 314029.78 E 0.346 -2.74 1625.48 0.470 284.560 1576.24 1625.34 2.54S 17.63 W 5955051.82 N 314029.12 E 0.092 -2.54 1725.07 0.470 286.460 1675.83 1724.93 2.325 18.42 W 5955052.06 N 314028.34 E 0.016 -2.32 1820.80 0.460 286.210 1771.55 1820,65 2.10 S 19.17W 5955052.29 N 314027.60 E 0.011 -2.10 1916.32 0.360 296.940 1867.07 1916.17 1.86 S 19.80 W 5955052.55 N 314026.97 E 0.132 -1.86 2012.70 0.480 302.870 1963.45 2012.55 1.50 S 20.41 W 5955052.92 N 314026.37 E 0.132 -1.50 2108.21 0.510 300.890 2058.95 2108.05 1.075 21,11 W 5955053.37 N 314025.68 E 0.036 -1.07 2204.45 0.460 305.720 2155.19 2204.29 0.62 S 21.79 W 5955053.84 N 314025.01 E 0.067 -0.62 2298.23 0.430 301.850 2248.97 2298.07 0.22 S 22.40 W 5955054,26 N 314024.41 E 0.045 -0.22 2395.45 0.310 295.730 2346,19 2395.29 0.09 N 22.94 W 5955054.58 N 314023.88 E 0.130 0.09 2492.30 0.330 297.080 2443.03 2492.13 0.33 N 23.43 W 5955054.83 N 314023.40 E 0.022 0.33 2587.32 0.250 293.770 2538.05 2587.15 0,54 N 23.86 W 5955055.05 N 314022.97 E 0.086 0.54 2682.78 0.150 329.220 2633.51 2682.61 0.73 N 24.12 W 5955055,25 N 314022.72 E 0.162 0.73 2778.73 0.230 270.600 2729.46 2778.56 0.84 N 24.37 W 5955055.36 N 314022.47 E 0.207 0.84 2874.30 0.230 264.450 2825.03 2874.13 0.82 N 24.76 W 5955055.36 N 314022.08 E 0.026 0.82 2970.75 0.190 286.910 2921.48 2970.58 0.85 N 25.10 W 5955055.39 N 314021.74 E 0.094 0.85 21 March, 2002 - 14:37 Page 20f5 DrillQuest 2.00.08.005 .' ~' -' - -. - -- - - - - - - - - - - - _. ~. . Sperry-Sun Dril/írig Services Survey Report for Lookout #2 Your Ref: 501032041000 Job No. AKMW22023, Surveyed: 18 March, 2002 North Slope, Alaska Kuparuk River Unit Exploration 2002 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 3040.89 0.140 255.270 2991.62 3040.72 0.86 N 25.30 W 5955055.41 N 314021.54 E 0.145 0.86 3197.84 0.210 234.710 3148.57 3197.67 0.65 N 25.72 W 5955055.20 N 314021.12 E 0.059 0.65 3294.66 0.380 231 .130 3245.39 3294.49 0.34 N 26.11 W 5955054.91 N 314020.72 E 0.177 0.34 3391.15 0.370 234.270 3341.88 3390.98 0.04 S 26.61 W 5955054.54 N 314020.20 E 0.024 -0.04 3487.55 0.310 220.240 3438.27 3487.37 0.42 S 27.03 W 5955054.17 N 314019.77 E 0.106 -0.42 3584.16 0.270 238.640 3534.88 3583.98 0.74 S 27.40 W 5955053.86 N 314019.40 E 0.104 -0.74 3678.34 0.280 212.150 3629.06 3678.16 1.05 S 27.71 W 5955053.56 N 314019.08 E 0.134 -1.05 3775.45 0.220 217.540 3726.17 3775.27 1 .40 S 27.95 W 5955053.22 N 314018.84 E 0.066 -1.40 3871.86 0.260 217.550 3822.58 3871.68 1.725 28.19 W 5955052.90 N 314018.58 E 0.041 -1.72 3967.98 0.220 217.330 3918.70 3967.80 2.045 28.44 W 5955052.59 N 314018.33 E 0.042 -2.04 4063.64 0.210 225.850 4014.36 4063.46 2.30 S 28.68 W 5955052.33 N 314018.09 E 0.035 -2.30 4157.78 0.170 249.290 4108.50 4157.60 2.47 5 28.93 W 5955052.16 N 314017,83 E 0.092 -2.4 7 4254.58 0.180 255.630 4205.30 4254.40 2.565 29.21 W 5955052.08 N 314017.54 E 0.022 -2.56 4349.74 0.210 232.800 4300.46 4349.56 2.70 S 29.50 W 5955051.95 N 314017,26 E 0.087 -2.70 4445.25 0.180 236.700 4395.97 4445.07 2.89 S 29.76 W 5955051.76 N 314016.99 E 0.034 -2.89 4540.21 0.190 228.990 4490.93 4540.03 3.085 30.00 W 5955051.58 N 314016.74 E 0.028 -3.08 4637.51 0.330 240.320 4588.23 4637.33 3.325 30.37 W 5955051.35 N 314016.37 E 0.153 -3.32 4732,58 0.450 223.870 4683.29 4732.39 3.73 S 30.87 W 5955050.96 N 314015.86 E 0.171 -3.73 4827.96 0.700 252.080 4778.67 4827.77 4.18 S 31.68 W 5955050.53 N 314015.04 E 0.389 -4.18 4925.23 1.020 265.900 4875.93 4925.03 4.42 5 33.11 W 5955050.32 N 314013.60 E 0.390 -4.42 5021.18 1.290 264.040 4971.86 5020.96 4,595 35.04 W 5955050.19 N 314011.67 E 0,284 -4.59 5116.85 1.190 257.310 5067.51 5116.61 4.92 S 37.08 W 5955049.91 N 314009.62 E 0.184 -4.92 5213.60 1.110 252.110 5164.24 5213.34 5.43 5 38,95 W 5955049.45 N 314007.74 E 0.136 -5.43 5308.46 1.030 255.340 5259.08 5308,18 5.93 S 40.65 W 5955049.00 N 314006,03 E 0.106 -5.93 5404.73 1.000 252.300 5355.33 5404.43 6.41 S 42.28 W 5955048.56 N 314004.38 E 0,064 -6.41 5500.90 0.850 250.320 5451.49 5500.59 6.90 S 43.76 W 5955048.10 N 314002.90 E 0.159 -6.90 5597.55 0.820 246.960 5548.13 5597,23 7.41 S 45.07 W 5955047.62 N 314001.57 E 0.059 -7.41 5692.09 0.850 239.860 5642.66 5691,76 8.03 S 46.30 W 5955047.04 N 314000.33 E 0.114 -8.03 5789.29 0.960 233.600 5739.85 5788.95 8.88 S 47.57 W 5955046.22 N 313999.03 E 0.152 -8.88 5886.16 0.920 244.490 5836.71 5885.81 9.695 48.93 W 5955045.44 N 313997.66 E 0.189 -9.69 21 March, 2002 - 14:37 Page 3 0'5 DrillQuest 2.00.08.005 .. -.. :.. ~ ~ ... ~ .!I!!!!!!!!! . . ~ - Sperry-Sun Drilling Services . Survey Report for Lookout #2 Your Ref: 501032041000 Job No. AKMW22023, Surveyed: 18 March, 2002 North Slope, Alaska Kuparuk River Unit Exploration 2002 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5981.05 0.910 247.210 5931.58 5980.68 10.31 S 50.31 W 5955044.86 N 313996.26 E 0.047 -10.31 6077.23 1.010 237.650 6027.75 6076.85 11.06 S 51.73 W 5955044.14 N 313994.82 E 0.196 -11.06 6173.36 0.990 227.440 6123.87 6172.97 12.08 S 53.06 W 5955043.16 N 313993.47 E 0.186 -12.08 6270.24 0.950 237.170 6220.73 6269.83 13.08 S 54.35 W 5955042.19 N 313992.15 E 0.175 -13.08 6365.60 0.860 233.960 6316.08 6365.18 13.93 S 55.59 W 5955041.37 N 313990.89 E 0.108 -13.93 6455.49 0.810 226.780 6405.96 6455.06 14.76 S 56.60 W 5955040.56 N 313989.86 E 0.129 -14.76 6552.35 0.950 228.980 6502.81 6551.91 15.76 S 57.71 W 5955039.60 N 313988.73 E 0.149 -15.76 6648.08 0.370 237.930 6598.53 6647.63 16.44 S 58.57 W 5955038.93 N 313987.85 E 0.614 -16.44 6743.75 0.520 230.840 6694.20 6743.30 16.88 S 59.17 W 5955038.51 N 313987.24 E 0.167 -16.88 6839.03 0.920 205.710 6789.47 6838.57 17.84 S 59.83 W 5955037.56 N 313986.55 E 0.525 -17.84 6937.20 1.110 199.770 6887.63 6936.73 19.45 S 60.50 W 5955035.98 N 313985.85 E 0.221 -19.45 7032.61 0.790 169.650 6983.02 7032.12 20.96 S 60.69 W 5955034.46 N 313985.62 E 0.610 -20.96 7128.50 0.190 164.980 7078.91 7128,01 21.77 S 60.53 W 5955033.66 N 313985.76 E 0.627 -21.77 7224.02 0.340 129.660 7174.43 7223.53 22.10 S 60.27 W 5955033.32 N 313986.01 E 0.225 -22.10 7319.92 0.380 117.800 7270.33 7319.43 22.43 S 59.77 W 5955032.97 N 313986.50 E 0.088 -22.43 7416.89 0.330 114.890 7367.30 7416.40 22.70 S 59.23 W 5955032.69 N 313987.03 E 0.055 -22.70 7511.98 0.350 109.720 7462.38 7511.48 22.91 S 58.71 W 5955032.47 N 313987.55 E 0.038 -22.91 7607.72 0.490 109.680 7558.12 7607.22 23.15 S 58.05 W 5955032.22 N 313988.20 E 0.146 -23.15 7705.02 0.540 116.360 7655.42 7704.52 23.49 S 57.25 W 5955031.85 N 313989.00 E 0.080 -23.49 7800.90 0.310 131.370 7751.29 7800.39 23.86 S 56.65 W 5955031 .46 N 313989.59 E 0.265 -23.86 7834.21 0.510 111 .450 7784.60 7833,70 23.98 S 56.44 W 5955031.35 N 313989.79 E 0.729 -23.98 7961.24 0.300 150.180 7911.63 7960.73 24.47 S 55.75 W 5955030.83 N 313990.47 E 0.263 -24.47 8056.98 0.420 180.310 8007.37 8056.47 25,04 S 55.63 W 5955030.26 N 313990,58 E 0.230 -25.04 8152.47 0.570 202.890 8102.86 8151.96 25.83 S 55.82 W 5955029.48 N 313990.37 E 0.255 -25.83 8164.10 0.530 202.950 8114.49 8163.59 25.93 S 55.86 W 5955029.38 N 313990.33 E 0.344 -25.93 8200.00 0.530 202.950 8150.38 8199.48 26.24 S 55.99 W 5955029.08 N 313990.19 E 0.000 -26.24 Projected Survey 21 March, 2002 - 14:37 Page 4 0'5 DrillQuest 2.00.08.005 -.. ~~. -' - .. .. - .," - - - - ~ , ,- 'Sp'erry-Sun Drilling Servìées Survey Report for Lookout #2 Your Ref: 501032041000 Job No. AKMW22023, Surveyed: 18 March, 2002 Kuparuk River Unit All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 24,815° (02-Mar-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8200.00ft., The Bottom Hole Displacement is 61.83ft., in the Direction of 244.892° (True). Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastings (ft) (ft) (ft) Comment 8200.00 8199.48 26.24 S 55.99 W Projected Survey Survey tool program for Lookout #2 From To Measured Vertical Measured Vertical Depth Depth Depth Depth ~ ~) ~) ~ Survey Tool Description 0.00 8200.00 0.00 8199.48 MWD Magnetic 21 March, 2002 - 14:37 Page 5 0'5 ~ - -- - -- - . North Slope, Alaska Exploration 2002 DrillQuest 2.00.08.005 r-, ~ ~ 15 ~ /~ÐG ~(L,. / , ' r-I -,.- . CONFIOENTIAL '"I q n~fS BF L CONfID(NTIAL Kuparuk River Unit North Slope, Alaska Exploration 2002, Slot Lookout #2 Lookout #2 Job No. AKMW22023, Surveyed: 18 March, 2002 SURVEY REPORT 21 March, 2002 Your Ref: 501032041000 Surface Coordinates: 5955053.92 N, 314046.81 E (70016' 55.7472" N, 151030' 17.4052" W) Kelly Bushing: 49. 10ft above Mean Sea Level 5pa....,,..,y-SLJIl DRIL.L.ING seRVIc:es A Halliburton Company Survey Ref" svy9848 Sperry-Sun Drilling Services . Survey Report for Lookout #2 Your Ref: 501032041000 CONFIOEN11~L Job No. AKMW22023, Surveyed: 18 March, 2002 North Slope, Alaska Kuparuk River Unit Exploration 2002 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -49.10 0.00 0.00 N 0.00 E 5955053.92 N 314046.81 E 000 MWD M;:)gnp.llr: 110.00 0.000 0.000 60.90 110.00 0.00 N 0.00 E 5955053.92 N 314046.81 E 0000 000 402.24 0.440 230.210 353 14 402.24 0.72 S 0.86W 5955053.22 N 314045.93 E 0.151 -072 492.97 0.570 236.060 443.86 492.96 1.19 S 1.50W 5955052.76 N 314045.28 E 0.154 -1.19 584.81 0570 253.340 535.70 584.80 1.58 S 2.32W 5955052.40 N 314044.45 E 0.186 -1 58 678.16 0.570 249.960 629.04 678.14 1.87 S 3.20W 5955052.13 N 314043.56 E 0036 -1,87 771.30 0640 244.570 722.18 771.28 2.25 S 4.11 W 5955051,77 N 314042.65 E 0.097 -2,25 863.94 0.880 255.420 814.81 863.91 2.65 S 5.26W 5955051.40 N 314041.48 E 0.301 -2.65 956.31 1.100 258,700 907 1 7 956.27 3,01 S 6.82W 5955051.08 N 314039.92 E 0246 -3.01 1052.37 1 120 260.850 1003.21 1052.31 3.34 S 8.65W 5955050.80 N 314038.08 E 0,048 -334 1148.86 1.130 274.850 1099.68 1148.78 3.41 S 10.53 W 5955050,77 N 314036.20 E 0.284 -3.41 1243.30 1 .200 279.150 1194.10 1243.20 3.17 S 12.43 W 5955051.06 N 314034.30 E 0.119 -3.17 1339.16 1.220 271.870 1289.94 1339.04 2.98 S 14.44 W 5955051.30 N 314032.30 E 0.162 -298 1436.22 0.700 275.080 1386.99 1436.09 2.89 S 16.07 W 5955051.43 N 314030.68 E 0.538 -289 1532.42 0.390 288.4 70 1483.18 1532.28 2.74 S 16.96 W 5955051.60 N 314029.78 E 0.346 -274 1625.48 0.4 70 284.560 1576.24 1625.34 2.54 S 17.63 W 5955051.82 N 314029.12 E 0.092 -2.54 1725.07 0470 286.460 1675.83 1724.93 2.32 S 18.42 W 5955052.06 N 314028.34 E 0.016 -2.32 1820.80 0460 286.210 1771.55 1820.65 2.10 S 19.17 W 5955052.29 N 314027.60 E 0011 -2.10 1916.32 0.360 296.940 1867.07 1916.17 1.86 S 19.80 W 5955052.55 N 314026.97 E 0132 -1 86 2012.70 0480 302 870 1963.45 2012.55 1.50 S 20.41 W 5955052.92 N 314026.37 E 0 132 -1 50 2108.21 0.510 300.890 2058.95 2108.05 1.07 S 21.11 W 5955053.37 N 314025.68 E 0036 -1 07 2204.45 0460 305.720 2155.19 2204.29 0.62 S 21.79 W 5955053.84 N 314025.01 E 0067 -0.62 2298.23 0430 301.850 2248.97 2298.07 0.22 S 22.40 W 5955054.26 N 314024.41 E 0045 -022 2395.45 0.310 295.730 2346.19 2395.29 0.09 N 22.94 W 5955054.58 N 314023.88 E 0 130 009 2492.30 0.330 297.080 2443.03 2492.13 0.33 N 23.43 W 5955054.83 N 314023.40 E 0022 033 2587.32 0250 293.770 2538.05 2587.15 0.54 N 23.86 W 5955055.05 N 314022.97 E 0.086 054 2682.78 0150 329.220 2633.51 2682.61 0.73 N 24.12 W 5955055.25 N 314022.72 E 0 162 on 2778.73 0.230 270.600 2729.46 2778.56 0.84 N 24.37 W 5955055.36 N 314022.47 E 0207 084 2874.30 0.230 264.450 2825.03 2874.13 0.82 N 24.76 W 5955055.36 N 314022.08 E 0026 082 2970 75 0 190 286910 2921 48 2970.58 0.85 N 25.10 W 5955055.39 N 314021.74 E 0.094 085 21 March, 2002 - 14:37 Page 20f5 O,i/lOllfJSt 2.00.08.005 Sperry-Sun 'Drilling Services . Survey Report for Lookout #2 Your Ref: 501032041000 Job No. AKMW22023, Surveyed: 18 March, 2002 North Slope, Alaska Kuparuk River Unit Exploration 2002 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim, Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 3040.89 0.140 255.270 2991.62 3040.72 0.86 N 25.30 W 5955055.41 N 314021.54 E 0.145 0.86 3197.84 0.210 234.710 3148.57 3197.67 0.65 N 25.72 W 5955055.20 N 314021.12 E 0.059 065 3294.66 0.380 231.130 3245.39 3294.49 0.34 N 26.11 W 5955054.91 N 314020.72 E 0177 034 3391 .15 0.370 234.270 3341.88 3390.98 0.048 26.61 W 5955054.54 N 314020.20 E 0024 -004 3487.55 0.310 220.240 3438.27 3487.37 0.42 8 27.03 W 5955054.17 N 314019.77 E 0 106 -042 3584.16 0270 238.640 3534.88 3583.98 0.748 27.40 W 5955053.86 N 314019.40 E 0 104 -0.74 3678.34 0.280 212.150 3629.06 3678.16 1.058 27.71 W 5955053.56 N 314019.08 E 0 134 -1 05 3775.45 0.220 217.540 3726.17 3775.27 1.40 8 27.95 W 5955053.22 N 314018.84 E 0.066 -1 40 3871.86 0260 217 550 3822.58 3871.68 1.728 28.19 W 5955052.90 N 314018.58 E 0.041 -1 72 3967.98 0.220 217.330 3918.70 3967.80 2.048 28.44 W 5955052.59 N 314018.33 E 0042 -2,04 4063.64 0210 225.850 4014.36 4063.46 2.30 S 28.68 W 5955052.33 N 314018.09 E 0035 -2.30 4157.78 0.170 249.290 4108.50 4157.60 2.478 28.93 W 5955052.16 N 314017.83 E 0092 -2.47 4254.58 0.180 255.630 4205.30 4254.40 2.568 29.21 W 5955052.08 N 314017.54 E 0.022 -2,56 4349.74 0210 232.800 4300.46 4349.56 2.708 29.50 W 5955051.95 N 314017.26 E 0.087 -270 4445 25 0 180 236.700 4395.97 4445.07 2.898 29.76 W 5955051.76 N 314016.99 E 0034 -2.89 4540.21 0 190 228.990 4490.93 4540.03 3.08 S 30.00 W 5955051.58 N 314016.74 E 0028 -308 4637.51 0330 240.320 4588.23 4637.33 3.32 S 30.37 W 5955051.35 N 314016.37 E 0.153 -332 473258 0450 223.870 4683.29 4732.39 3.738 30.87 W 5955050.96 N 314015.86 E 0 171 -373 4827.96 0.700 252.080 4778.67 4827.77 4.188 31.68 W 5955050.53 N 314015.04 E 0.389 .4.18 4925.23 1 020 265 900 4875.93 4925.03 4.428 33.11 W 5955050.32 N 314013.60 E 0390 -442 5021.18 1,290 264.040 4971.86 5020.96 4.598 35.04 W 5955050.19 N 314011.67 E 0284 -4.59 5116.85 1 190 257.310 5067.51 5116.61 4.928 37.08 W 5955049.91 N 314009.62 E 0 184 -4.92 521 3 60 1 110 252.110 516424 5213.34 5.438 38.95 W 5955049.45 N 314007.74 E 0 136 .54.1 5308.46 1.030 255.340 5259.08 5308.18 5.935 40.65 W 5955049.00 N 314006.03 E 0.106 -5.93 5404 73 1 000 252.300 5355.33 5404.43 6.41 5 42.28 W 5955048.56 N 314004.38 E 0064 .641 5500.90 0.850 250.320 5451.49 5500.59 6.905 43.76 W 5955048.10 N 314002.90 E 0 159 -690 5597.55 0820 246.960 5548.13 5597.23 7.41 5 45.07 W 5955047.62 N 314001.57 E 0059 -741 5692.09 0.850 239.860 5642.66 5691.76 8.038 46.30 W 5955047.04 N 314000.33 E 0 114 .803 5789.29 0.960 233.600 5739.85 5788.95 8.888 47.57 W 5955046.22 N 313999.03 E 0 152 -8 R8 5886.16 0920 244.490 5836 71 5885.81 9.698 48.93 W 5955045.44 N 313997.66 E 0 189 .969 - --- ---------- -- -- - -- --- - -- 21 March, 2002 - 14:37 Page 3 0'5 DrillQ/lest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for Lookout #2 Your Ref: 501032041000 Job No. AKMW22023, Surveyed: 18 March, 2002 North Slope, Alaska Kuparuk River Unit Exploration 2002 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5981.05 0.910 247.210 5931.58 5980.68 10.31 S 50.31 W 5955044.86 N 313996.26 E 0047 -10 31 6077,23 1.010 237.650 6027.75 6076.85 11.06 S 51.73 W 5955044.14 N 313994.82 E 0 196 - 11 Of) 6173.36 0.990 227.440 6123.87 6172.97 12.08 S 53.06 W 5955043.16 N 313993.47 E 0.186 - 12 Of! 6270.24 0950 237.170 6220.73 6269.83 13.08 S 54.35 W 5955042. 19 N 313992.15 E 0.175 -1308 6365.60 0.860 233.960 6316 08 6365.18 13.93 S 55.59 W 5955041.37 N 313990.89 E 0 108 -13.93 6455.49 0.810 226.780 6405.96 6455.06 14.76 S 56.60 W 5955040.56 N 313989.86 E 0 129 -14.76 6552.35 0.950 228.980 6502.81 6551.91 15.76 S 57.71 W 5955039.60 N 313988.73 E 0149 -1576 6648.08 0.370 237.930 6598.53 6647.63 16.44 S 58.57 W 5955038.93 N 313987.85 E 0.614 -1644 6743.75 0520 230,840 6694 20 6743.30 16.88 S 59.17 W 5955038.51 N 313987.24 E 0 167 -1688 6839.03 0.920 205.710 6789.47 6838.57 17.84 S 59.83 W 5955037.56 N 313986.55 E 0525 -17.84 6937.20 1.110 199.770 6887.63 6936.73 19.45 S 60.50 W 5955035.98 N 313985.85 E 0.221 -19.45 7032.61 0790 169.650 6983.02 7032.12 20.96 S 60.69 W 5955034.46 N 313985.62 E 0.610 -20.96 7128.50 0190 164.980 7078.91 7128.01 21.77 S 60.53 W 5955033.66 N 313985.76 E 0627 -21 77 7224.02 0.340 129.660 7174.43 7223.53 22.10 S 60.27 W 5955033.32 N 313986.01 E 0.225 -22 10 7319.92 0380 117.800 7270.33 7319.43 22.43 S 59.77 W 5955032.97 N 313986.50 E 0.088 -2243 7416.89 0.330 114.890 7367.30 7416.40 22.70 S 59.23 W 5955032.69 N 313987.03 E 0055 -2270 7511.98 0.350 109.720 7462.38 7511.48 22.91 S 58.71 W 5955032.47 N 313987.55 E 0.038 -22 91 7607.72 0490 109.680 7558.12 7607.22 23.15 S 58.05 W 5955032.22 N 313988.20 E 0.146 -23.15 7705.02 0.540 116.360 7655.42 7704.52 23.49 S 57.25 W 5955031.85 N 313989.00 E 0.080 -2349 7800.90 0.310 131.370 7751.29 7800.39 23.86 S 56.65 W 5955031.46 N 313989.59 E 0.265 -23 86 7834.21 0510 111.450 7784.60 7833.70 23.98 S 56.44 W 5955031.35 N 313989.79 E 0729 -23.98 7961.24 0.300 150.180 7911.63 7960.73 24.47 S 55.75 W 5955030.83 N 313990.47 E 0.263 -24 47 8056 98 0.420 180.310 8007.37 8056.47 25.04 S 55.63 W 5955030.26 N 313990.58 E 0.230 -25,04 8152.47 0570 202.890 8102.86 8151.96 25.83 S 55.82 W 5955029.48 N 313990.37 E 0.255 -25.83 8164.10 0530 202.950 8114.49 8163.59 25.93 S 55.86 W 5955029.38 N 313990.33 E 0.344 -25 93 8200.00 0.530 202.950 8150.38 8199.48 26.24 S 55.99 W 5955029.08 N 313990.19 E 0.000 -2624 Pro/p.clerl Survey - ---- ----- .-- 21 March, 2002 - 14:37 Page 4 0'5 DrillQllest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for Lookout #2 Your Ref: 501032041000 Job No. AKMW22023, Surveyed: 18 March, 2002 . Kuparuk River Unit North Slope, Alaska Exploration 2002 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. -. Magnetic Declination at Surface is 24.815° (02-Mar-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8200.00ft., The Bottom Hole Displacement is 51.83ft., in the Direction of 244.892° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8200.00 8199.48 26.24 S 55.99 W Projected Survey -- Survey tool program for Lookout #2 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 0.00 8200.00 8199.48 MWD Magnetic -- -------- __n 21 March, 2002 - 14:37 Page 50'5 DrillOuest 2.00.08.005 ) , "" wlw - II ..,.., I -'~' oI.~ ~:i I'::' ... .c. 01.....1 I -II1II- --'~-THIIS ~~OJEc~_-,OOKhUT_2~/~IU\~A;.,Õ=3 oIt I~ £. .c: Q 1--' . , I ~s ~,'_'I I LOOK~l ~.r-:-- -~ -> -~~- ~~'...I - - . ,c.«- 3 '" ~ - '-'-'-- -+- - ------ ~~~~ -- ------- 10.~ I t.1ITRE-l I I -- ------~---l--.-- --1 ---, -- - I , 11 1:: I ... IC£ R04D - /"1 VICINITY M.A.P t¡ T S. L ICE PAD St-ICULDER NOTE s: \, ALASKA STATE PLANE COORDINATES ARE rMD- 27, 2 GEODETIC COORDINATES ARE NAD-2ì. 3. LOOKOUT ICE PAD SCALE F ACTO!~' Q.999939281 4. DISTANCES SHOWN ARE TRUE GROUND DIS:ANCE 5. ELEVATIONS ARE MEAN SEA LEVEL (MSL). 6. DATE OF SURVEY: FEBRUAR Y 24, 20G2. 7. REFERENCE FIELD BOOK: NPRA-02-01, PAGE 64 ZONE - 4- I I "- 10 LOOKOUT-2 ICE PAD -i ,~--SS5illIDio-J~ Æ~(: OF A 't.{J ~"\o:--c ceO 0.0 c. "~~i~t¡-h . "C'o *' < L.YJ- '~0 .,. "</~ °, ,." ill '0 V; ,B*/49 ,\ \*,~ ,~çC~:::J.:~&~:'@ a ~ 0 ~ ~~\" Jeffre y J. Cotton, / ß" &' ~,J'~ ., lS 8306 .° c~ 6' V \,?(; .0 CO ~.s:-~ì ~.o~~ 'o.....'~~~ ~ :'V'-Ess IONþ..L ~ -;S;::-~ J.:rrujS.)SS..~ s ~ ~ :; ~ SURVEYOR'S CERTIFICA TE I HEREBY CERTIFY THAT I AM PROPERL Y REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PL,A. T REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS APE. CORRECT AS OF FEBRUARY 24, 2002 ')oci /~'" ,:-ûrj ... ...--- , ~/' I .-/~, /----- '-'-- LOOKOUT - 2 --\-.-- --- ~ ~ J ~ ~ 1'1 ~ ! ~ \. !- ~ § ~ -~- I LOCATED WITHIN PROTRACTED SEC 25, T 11 r~, R. 2 E., UMIAT MERIDIAtJ, ALASKA WELL A S.P. GEODETIC---¡ GEODETIC TOP OF RIG TUNDRA I StCTION NAME COORDINATES POSITIONI,:DMS) POSITION(D DO) ICE PAD ELE'..'. ELE'/. OFFSETS Y=5.955,053.92 70.16'55 :47" 70.2821519' 3.893' FSL LOOKOUT-2 x= 314,046.81 151.30'17405" 151.5û4834T 21.5' 184' 1.400' FEL Ii f.!!~~~I~~p~!~!~~~J,m~: i~'" I 1 ':)i" 1 ... :i ¡ ! ~ ã I ------ :J --..--- I ----- i ----- I ----------- i------- ~ -;-2/24/02 ~~E:D r~ tNrOJ¡..Þ.TIOOi .:. NO DATE --- ~ 1f~l_t__,e~ ~~,:: ~~;"O2 ------ -~ W FlIBD2 LCO<OUT-2 0'-00 --- -- ~ ~~æmœO K'8 rJO -- -,----- ~-- JJÇ. ED (~..~~ BY lo.u( :~......:~~r-:.~~. ~V;~~~ 2002 WINTER EXPLORATION LOOKOUT-2 CONDUCTOR AS-BUlL T ,"a 200' PC VISION Re: Lookout #2 P&A Subject: Re: Lookout #2 P&A Date: Man, 22 Apr 2002 12:26:17 -0800 From: Tom Maunder <tom_maunder@admin.state.ak,us> To: Greg_Noble@blm.gov Thanks Greg. GreQ_Noble@blm.gov wrote: > Tom, > > Your proposal to plug the Lookout #2 is approved. As to Tom's > concerns...both seem reasonable. The idea of the weephole is to eliminate > any pressure at surface and to be able to easily identify if the plugged > well begins to leak fluid. The weephole is really only useful when using a > standard dryhole marker above surface. > > Please give me a call when you know when this will occur. 80 will be out > until Saturday but will be able to get up there Sunday, If it happens > earlier than that, Pete or I may go up. > > Thanks > > > > > > > "Tom J Brassfield" To: greg_noble@ak,blm,gov, Tom Maunder <tbrass@ppco,c <tom_maunder@admin.state,ak.us> om> cc: bo_brown@ak.blm.gov Subject: Lookout #2 P&A 04/19/02 10:42 AM > > > > > > Greg/Tom, the attached procedures and accompanying forms will be sent out > today. The Explorationists want to install some short term gauges for > approx. one week, so expect the P&A to begin next weekend, Any questions, > please call. > > (See attached file: Lookout #2 P&A Word Schematic.doc)(See attached file: > Lookout #2 BLM AOGCC P&A Proc by TJB4 19 02.doc) > > Thanks, Tom > 265-6377 (w) > 275-7352 (p) > 265-6916 (f)(See attached file: Lookout #2 P&A Word Schematic.doc)(See > attached file: Lookout #2 BLM AOGCC P&A Proc by TJB4 19 02.doc) > > --------------------------------------------------------------------- > > Name: Lookout #2 P&A Word Schematic. doc Lookout #2 P&A Word Schematic,doc Type: WINWORD File (application/msword) Encoding: base64 > > > Name: Lookout #2 BLM AOGCC P&A Proc by TJB4 19 02.doc 1 of 2 4/23/028:33 AM ~e: Lookout #2 P&A Subject: Re: Lookout #2 P&A Date: Fri, 19 Apr 2002 15: 18: 1 0 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Tom J Brassfield <tbrass@ppco.com> CC: greg_noble@ak.blm.gov, bo_brown@ak.blm.gov, lonny Bagley <Ibagley@ak.blm,gov>, AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> Tom, et ai, I have done a quick review on the proposed plugging. I only have 2 comments: 1--Since the largest pipe is 161" it should not be necessary to make the marker plate any larger. Having plate surface outside the conductor just gives a surface to "jack" against if there is any settlement and heave of the cellar fill. 2--1 know the BlM regulations stipulate that a weep hole be drilled in the plate. I request that this be omitted. The reasoning is if there is thaw as the fill settles, there is a potential for water to potentially penetrate into the space below the plate. Although the potential area in there is small, as any water freezes it will expand and could distort the plate and ultimately lead to breaking the welds. If there are any comments, lets discuss. Tom Maunder, PE AOGCC Tom J Brassfield wrote: > Greg/Tom, the attached procedures and accompanying forms will be sent out > today. The Explorationists want to install some short term gauges for > approx, one week, so expect the P&A to begin next weekend. Any questions, > please call, > > (See attached file: Lookout #2 P&A Word Schematic.doc)(See attached file: > Lookout #2 BLM AOGCC P&A Proc by TJB4 19 02.doc) > > Thanks, Tom > 265-6377 (w) > 275-7352 (p) > 265-6916 (r) > >------------------------------------------------------------------------ > > Name: Lookout #2 P&A Word Schematic,doc Lookout #2 P&A Word Schematic. doc Type: WINWORD File (application/msword) Encoding: base64 > > > Name: Lookout #2 BLM AOGCC P&A Proc by TJB4 19 02.doc > Lookout #2 BLM AOGCC P&A Proc by TJB4 19 02.doc Type: WINWORD File (applica tion/m sword) > Encoding: base64 i -- --1 i Tom Maunder <tom maunder(â2admin.state.ak.us> ¡ I Sr. Petroleum Engineer I ¡ Alaska Oil and Gas Conservation Commission ¡ --- 1 of 2 4/23102 8:33 AM ~ ) ~ f:~st~r~!~~'P~!~~~~d~~~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Tom Brassfield Phone (907) 265-6377 Fax: (907) 265-6224 Email: tbrass@ppco.com April 19, 2002 Commissioner Cammy Oechsli Taylor Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Sundry approval to Plug and Abandon Phillips Lookout #2 Surface Location: 1387' FNL, 1400' FEL, Sec. 25, T11 N, R2E, UM or ASP4, NAD 27 coordinates of X=314,047 & V=5,955,054 Target Location: 1413' FNL, 1456' FEL, Sec. 25, T11N, R2E, UM BHL: 1413' FNL, 1456' FEL, Sec.25,T11N,R2E, UM CONFIDENTIAL Dear Commissioner Taylor: Phillips Alaska, Inc. would like to permanently plug and abandon the Lookout #2 wellbore, located in the National Petroleum Reserve-Alaska. Doyon 141 spud this well on 3/2/02 and the testing phase ended 4/18/02, The attached Sundry and back-up information describes the P&A procedure for the existing wellbore and has been discussed with AOGCC personnel. A final decision has been made to complete the P&A before the end of this year's winter exploration season. If you have any questions or require any further information, please contact me at 265-6377 or Paul Mazzolini at 263-4603 Ji.n erely, ~ ~ Tom Brassfield Sr. Drilling Engin r r~ F ¡"" ~.~ ~ \, I ~ f) ~',( - S l-:, '¡ c r 1 ~ " - '. ~ ~ '" J iõ '~. ,:... . ,- ,- . "~I r 'Î " 2 ~~ ,"..: i '/ ,'! 1\ ~ . r I" ''''. ..... 'oJ .. .ö..las!<a Oil 6 Gq:~ L'IIII.. '. .,J' ,,.:11 -.>IL" ì\ r" ( It. 1'- '. ,I, (": ,--) ~ " '. ~ ,: \ \ t I' ~ I, .-"1 II,. J. ~.. \. ~ ... ~.I ¡ , L - II ¡'f""i¡ D/,- :r~ :::5~ /y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _X Suspend - Alter casing - Repair well - Change approved program - 2. Name of Operator Phillips Alaska, Inc. 3. Address p, O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1387' FNL, 1400' FEL See. 25, T11 N-R02E, UM At top of productive interval 1413' FNL, 1456'FEL,Sec.25, T11N-R02E, UM At effective depth At total depth 1413' FNL, 1456' FEL, See 25, T11 N-R02E, UM 12. Present well condition summary Total depth: measured true vertical 8200 8200 Effective depth: measured 8101 PBTD true vertical 8102 PBTD Casing Length Size Conductor 80' 16" Surface 3047' 9-5/8" Intermediate 7833' 7" Liner 464' 4-1 /2" Perforation depth: measured 7890' to 7924' true vertical 7890' to 7924' Tubing (size. grade, and measured depth 4-1/2" 12.6 ppf L-80 to 7734' Packers & SSSV (type & measured depth) Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development - Exploratory _X Stratigraphic - Service - feet feet feet feet Plugs (measured) Junk (measured) Cemented 200 sx AS1 422sx AS Lite... 166sx LlteCRETE 195 sx LlteCRETE 79.5sx CI "G" Monobore completion with seals at 7734' 13. Attachments Description summary of proposal _X- I 14, Estimated date for commencing operation April 23, 2002 16. If proposal was verbally approved Re-enter suspended well - Time extension - Stimulate - Variance - Perforate - 6. Datum elevation (OF or KB feet) RKB 21,5 + 28,5 feet 7. Unit or Property name Other - Rig Change Exploration NPRA 8. Well number Lookout #2 9. Permit number I approval number 202-027 10. API number 50-103-20410-00 11. Field I Pool Exploration Measured Depth 130' 3097' 7883' 7734' to 8198' True vertical Depth 130' 3097' 7883' 7734' to 8198' r-', ra f'" ¡:"" Þ \ ¡ c r') 1\< t: \.. t:'~ ',:' l Il..r 1\ :'-.C¡ 'I :~j :;['0(_1 .,1. -'I w ,\ "- V Ata~Y..J' 1.1',: ::'. ',. . I . ,I " '. I . I' 'I .' . ~ , Detailed operations program - BOP sketch - 15. Status of well classification as: Oil- Name of approver Date approved Service - 17. I hereby certify that the foregomg is true and correct to the best of my knowledge. ---;-) '1 Ýl1 ~A ß \ Signedpa¡JI!:~~ ¡ '(C_'JJ~V~ Gas- Suspended - Questions? Call Tom Brassfield 265-6377 Title: Exploration/Cook Inlet Drilling Team Leader Date ô4-1/9 /2a>2. TJB FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness './ Plug mtegnty ~ BOP Test - Location clearance J:::.. Mechanlcallntegnty Test - Subsequent form required 10- 4u\ Approved by order of the Commission Ca,¡~1;O [LI~J-' ~t~ Form 10-403 Rev 06/15/88 . I ., ~ I . I ... 1\...- I Approval no. . / .30;2.-13, Commissioner ¿J/ . Date /J y/o :r SUBMIT IN TRIPLICATE Lookout #2 Final P&A CONFIDENTIAL Revised 4/19/02 Well Status: Lookout #2 was drilled/completed/tested during the 2002 winter NPRA exploration drilling season. The well is currently 51 after a five day flow test and will be P&A'd this year before the ice road system is secured for the season. The work should be completed prior to 5/1/02. The 9-5/8" x 7" annulus has approximately 60' of cement slurry from the 9-5/8" shoe to 3037' MD. The 4-1/2" x 7" annulus should be full of 9.8 ppg brine with a diesel cap from the GLM at 2492' MD, The 4-1/2" tubing will have produced fluids to surface- note 5ITP. 1, Notify BLM/AOGCC 48 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Confirm with Wells Group that dummy valves are set in all three GLM's at 7653', 7572', and 2492'. 3. Mobilize and rig up D/S for well P&A operation. 4. Bullhead 9.8 ppg NaCI Brine to the top perforation at 7890' or approx. 120 bbl - note injection rate and pressures. RU slickline and pull dummy from the GLM at 7653'. RD slickline. Open the 4-1/2" x 7" annulus and circulate 9.8 ppg NaCI brine until diesel is displaced from backside or approx. 46.4 bbl. Close the 4-1/2"x7" annulus valve. 5. Mix approx. 24 bbls. (1577' of tubing volume) cement (Class G with additives) and displace (w/9.8 ppg brine) down tubing to the top perforation at 7890'. Hesitate squeeze cement (approx 8 bbls planned) into perfs as required. Open 4-1/2"x7" annulus valve and displace an additional 5,6 bbls to the backside- 51. This should leave approx. 300' of cement in the annulus and in the tubing above the GLM at 7653'. 6. Rig up SWS "eline" unit and RIH to tag top of cement plug to verify placement. Record and report results, Pressure test casing to 1500 psi. BLM/AOGCC may want to witness tag of cement and pressure test. 7. RIH with 3.650" gauge ring (or as recommended by SWS) to 1005'. 5et Baker 4-1/2" Model K CIBP (w/ModeI10 E-4 setting tool) at approx. 1005'. Make up 4' of SWS 3- 3/8" gun loaded at 6spf with 34B HJ charges and perforate tubing/casing at approx. 1000'. POOH. Before RD SWS, open 7"x9-5/8" annulus and attempt to establish circulation down the tubing up the annulus. 51. Open 4-1/2"x7" annulus to establish circulation down the tubing up the annulus. 51. RD SWS. 8. RU D/S. Open 7"x9-5/8" annulus, confirm circulation down tubing up the annulus, circulate AS1 cement (approx. 43.4 bbls down tubing into casing/casing annulus) to surface. SI 7"x9-5/8" annulus. Open 4-1/2"x7" annulus. Circulate AS1 cement (approx. 18.6 bbls) down the tubing up the casing/tubing annulus to surface. SI. Open 7"x9-5/8" annulus again and pump cement to verify that the cement is at surface. SI. Check the 4-1/2"x7" annulus the same way. SI. RD SWS. NOTE: Notify BLM/AOGCC Inspectors before setting surface plug(s). 9, Clear lines and shut down pumps. Rig down cementing unit and clean up. 10. Cut off wellhead and all casing strings at 3 feet below original ground level. Verify that cement is back to surface in all strings. Add cement as required. Send casing head with stub to Materials for repair / re-dressing, TJB 4:19/Û2 Lookout #2 Final P&A CONFIDENTIAL Revised 4/19/02 11. Weld "IA" thick cover plate (at least 18" in diameter) over all casing strings with the following information bead welded into the top. Drill 1 /8" weep hole in the cover plate. Phillips Alaska, INC Lookout #2 PTD # 202-027 API # 50-103-20410-00 SHL: 1387' FNL, 1400 FEL, Sec. 25, T11 N, R2E 12. 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. T JB 4/19/02 FILE: Lookout #2 --:2 ~J Y71l~ ¡- o~ I l't° Paul Mazzolini ate Exploration Team Leader {)4-/1 9 / Z<.'-C- 2- TJB 4/19... 02 LOOKOUT #~ ) P&A WELL SCHEMATIC ~ PH )LIPS AI k I ~l IL as a, nc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Surface csg. 9-5/8" 40# L-80 BTC @ 3097' MOITVD Cemented wJ422 sx ASLite + 166 sx LiteCRETE ~ ~ ~ ~I f ~~ ~ ~i ~ TAM 9-5/8" Port Collar /-"J ~ Stnd. Grade BTC Threads ~~ ~ (+1- 1002' MDITVD) ~ ~ ~i! ~ ~~ ~ ~~ ~ ~~ ~ ~~ ~ ~I ~ ~I ~ ~i! ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 16" 62.6# @ +1- 130' MO 4-1/2" FMC Gen V Tubing Hanger, 4-1/2" L-80 IBT pin down 4-1/2" 12.6# L-80 IBT-M Spaceout Pups as Required 4-112" 12.6# L-80 IBT-M Tubing to Surface 4-1/2" Camco 'DB' nipple wI 3.875" No-Go Profile. Set at +1- 914' MD !~ ~~ ~~ ~~ ~~ ~~ ~~ ~ ~ 4-1/2" x 1" Cameo 'KBG-2' mandrel wI shear valve and latch (Max. 005.984",10 ~ ~ 3.833"). @ 2492' MD, 6' L-80 handling pups installed above and below. ~ ~ ~~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Cement to surface 4-112" 12.6# L-80 IBT-M tubing to landing nipple Cement to surface 60' of cement in the 7"x9-5/8" annulus at shoe Est TOC inside annulus & tubing @ 7353' Top-set csg. 7" 26# L-80 BTC @ 7883' MO Cemented wI 195 sx LiteCRETE 4-1/2" x 1" Cameo 'KBG-2' mandrel wI latch & dummy (Max. 005.984".10 3.833") @ 7572' MO, 6' L-80 handling pups installed above and below. 2 jts 4-112" 12.6# L-80 IBT tubing 4-1/2" x 1" Cameo 'KBG-2' mandrel wI latch & dummy (Max. 005.984".10 3,833") @ 7653' MO, 6' L-80 handling pups installed above and below. ~-1/2" Halliburton "XN" nipple wI 3.725" profile @ 7697' MO 1 jt 4-1/2" 12.6# L-80 IBT-M tubing 1 jt 4-1/2" 12.6# L-80 IBT-M tubing Baker locator sub 4-1/2" Baker GBH-22 casing seal assembly w/12 Ft. stroke. 4-112" L-80 IBT box up Liner Assembly (run on drillcipe) (Õ) 7734' MO Baker 7" x 4-112" 'ZXP' Liner Top Isolation Packer with C-2 Profile & 12 Ft. PBR Baker 7" x 4-112" 'HMC' Liner Hanger Perfs f/7890' to 7924' 4-1/2" 12.6# L-80 IBT-M liner as needed Production Lmer 4-112" 12.6# L-80 from 7734' to 8198' MO Cemented wI 79.5 sx CI G GasBLOK 4-1/2" Baker Landing Collar 1jt 4-1/2" 12.6# L-80 IBT-M 4-1/2" Baker Float Collar .... ~ 2 Jts 4-1/2" 12.6# L-80 IBT-M 4-1/2" Baker Float Shoe T JB 4/18/02 Jlitre #1/Lookout #1 & #2 Weekly Status- CONFIDF~TIAL "I Subject: Mitre #1/Lookout #1 & #2 Weekly Status- CONFIDENTIAL Date: Tue, 2 Apr 2002 11 :32:20 -0900 From: "Tom J Brassfield" <tbrass@PPco.com>---'-- -_. .. --.- To: greg_noble@ak.blm.gov, Tom Maunder <tom_maunder@admin.state.ak.us> CC: bo_brown@ak.blm.gov, "Paul Mazzolini" <pmazzol@ppco.com> "') Greg/Tom, the weekly update on the above wells: Lookout #2- Halliburton Testers are rigging-up to test this well. The Wells group should be perforating today. lookout #1- Doyon 141 completed the well with 4-1/2" tubing and was released to Heavenly at 0600 hrs 3/28/02. This well will aslo be perforated today or tomorrow and gauges installed for monitoring during the lookout #2 test. Mitre #1- Drilled to 7" casing point at 7906' MD. Ran & cemented casing with shoe at 7905'- full returns throughout job, did not bump the plug, set emergency slips to set casing close to TD. Tested BOPE's- waived by AOGCC & BlM. RIH with DP, tagged cement at 7669' (150' high), and tested casing to 3500 psi for 30 minutes-OK. Drilled out shoe plus one foot of formation. Currently out of the hole to PU 60' core bbl. Thanks, Tom 265-6377 (w) 275-7352 (p) 265-6916 (f) 1 of 1 a~-CB. 7 4/2102 12:47 PM . -... ----..--'''' -..- ..--'''1 --.-- --... .--......- .) J Subject: Mitre #1 & Lookout #1 & #2 Weekly Status- CONFIDENTIAL Date: Wed, 27 Mar 2002 10:55:53 -0900 From: "Tom J Brassfield" <tbrass@ppco.com> . To: greg_noble@ak.blm.gov, Tom Maunder <tom_maunder@admin.state.ak.us> CC: "Paul Mazzolini" <pmazzol@ppco.com> Greg/ Tom, an update on the above wells Lookout #2- Completed e-line logs, ran 4-1/2" liner to 8198', cemented same with full returns. Ran 4-1/2" monobore completion, tested tubing and annulus to 3500 psi-OK. ND BOPE/NU Tree and tested-OK. Doyon 141 released to Lookout #1 completion 1800 hrs 3/24/02. ~D Tree/NU BOPE. RIH with DP and milled-up CIBP at 7832'. Cleaned out to PBTD at 8253'. Circulate hole clean. RU SWS and set isolation paker at 7930'. Currently RIH with 4-1/2" tubing and packer. Expect Doyon 141 to move to the Heavenly location tonight/tomorrow morning. Ó>C8- Od J ~. ~u~ - \)~~-7- .-- G:w.~'- ~çp~ ~~ Mitre #1- Drilled pilot hole to 8090' MDITVD. Set two downhole cement plugs. The bottom 400' plug was set from 8090' to 7690'- good returns "'- - throughout job. Set top kick-9ft f)tt.y (~fi5') 'kQ..m 6305' to 5850' MD- 1 ~\~~ ~~~\)J'l\\~\'I[çø good returns throughout jobQested BOPE's)Kick-off pilot hole at 5871' ~ ~o ~ ~ MD. Currently drilling below 6;-00' MD. Estimate 7" casing point at 79051 ~~'t ~~ M~. Plan ~o drillout, core, TD well and eline log. Completion or P~&A ~ A- stili undecIded. \. '\ - - ~, . ~~ ~~~'t..-.~~c:.~ ' ...... ~ Thanks, Tom 265-6377 (w) 275-7352 (p) 265-6916 (f) 1 of 1 3/27/02 11: 12 AM PHilliPS Alaska, Inc. ~ ':,ut. :."j,;:,r ,~,' PHILLlF::; PE ïR¡:'LEur 1 c: .::.1 W - r I , PO. BOX 100360 ANCHORAGE, ALASKA 99510-0360 SAMPLE TRANSMITTAL TO: AOGCC 333 WEST 7TH SUITE 100 ANCH, AK. 99501 279 1433 DATE: MARCH 25, 2002 AIR BILL: 5131159 PBV: 02-03-25-11 CHARGE CODE: AX2200 OPERATOR: PAl ¡-fAME: LOOKûUT 2 SAMPLE TYPE: DRIES API NO: N/A NUMBER OF BOXES: 1 Bundle (6 bxs) SAMPLES SENT: LOOKOUT2 108-8200 SENT BY: M. McCRACKEN UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: RECEIVED: PHILLIPS BAYVIEW GEOLOGICAL FACILITY 619 EAST SHIP CREEK AVE SUITE 102 ANCHORAGE, AK. 99510 tJ (JlÜ: DAN PRZYWOJSKI ABV100 flf-~).~J.. - 0 ()v) 5n<¡(t SA:t tt::- [D ~ 7 lAJ~ i l ~. ( e- PHilliPS Alaska Inc. Lookout #2 See 28- T9N-RR7E UM North Slope Borough Alaska March 2, 2002 Bob Nichol Sr. Logging Geologist Robert Schneider Sr. Logging Geologist [~ 3:?OC= = d o;)-~7 TABLE OF CONTENTS Phillips Alaska Inc. Lookout #2 North Slope Borough TABLE OF CONTENTS ......................................................... ...... .................................. 2 WELL RESU M E.......".......".. ........... ............. ..... ................ ...... ... ...................................... 3 LITHOLOGY AN D REMARKS ....................................................................................... 4 RIG ACTIVITI ES .......................... ........... .............. .... .............. ....... ............ ................... 32 MUD RECORD............................... .'........................................ ..................................... 34 SU RVEY RECORD......................................... ............ ............. ..... ...... ...... .................... 36 BIT RECORD....................... .............................................. ........................................... 39 DAYS VS. DEPTH................ ....... .......... .... ................ ... ................. ............................... 40 MORNING REPORT...................................................................... .APPENDIX 1 FINAL LOGS..... ..... .................................. ............ .............. ..... .... ................ APPEN DIX 2 [:I F.P( )CH 2 PHilliPS Alaska, Inc. ~ ~ lookout #2 WEll RESUME Operator Well Name: Phillips Alaska Inc. Lookout #2 Location: Sec. 28 T9N -RR7E UM N70° 16' 55.747", W151 0 30' 17.405" Y=5944277.05, X=305725.96 Coordinates: Elevation: Rig floor: 27.61 Pad: 21.5' AMSL North Slope Borough County: State: Alaska AFE No.: Spud Date: AK 0231 March 2, 2002 Contractor: Foremen: Doyon Drilling Ray Springer, Dink Heim Rig: Logging Unit: #141 - Land MLOA3 Geologists: Co. Geologist: Bob Nicholl Bob Schneider Laurie S1. Auban LOG Interval: Dates: 110' to 8200' 3/2/2002 to 3/18/2002 Casing Data: Hole Size: Spud Mud to 3105' LSND to 8200' 16" @ 110', 9-5/8" @ 3105',7" @ 7883' Mud Types: 6.336" to 7883',6.125" to 8200' (.:I EP()(~H 3 PHilliPS Alaska, Inc. PHilliPS m lookout #2 liTHOLOGY AND REMARKS 100-360' M D GRAVEL, CONGLOMERATIC SAND, CLAY, DOMINANTLY LIGHT GRAY TUFFACEOUS CLA YSTONE= CURDY TO AMORPHOUS FORM SUPPORTS HIGHLY VARIABLE SIZED QUARTZ/CHERT PEBBLES; PEBBLES ARE POORLY SORTED, TO 2CM DIAMETER, DOMINANTLY SUBROUNDED TO OVOID, OCCASIONALLY FLATTENED; COLORS RANGE FROM LIGHT BROWN/BLACK TO LIGHT GREEN TO TRANSLUCENT TO FROSTED WHITE QUARTZ; COARSE SAND GRAINS DISSEMINATED VARIABLY ARE MODERATE TO LOW SPHERICITY; QUARTZ FRAGS COMMONLY ABRAIDED WHILE CHERTY FRAGS HAVE POLISHED APPEARANCE; MINOR BLACK/BURNT WOOD FLAKES DISSEMINATED; OTHER DISSEMINATED LITHICS ARE LIMESTONE, DOLOMITE, VOLCANICS, AND ITINERANT SANDSTONE; RARE ANHEDRAL PYRITE DISSEMINATED. 360-410' MD CLAYSTONE = LIGHT BROWNISH GRAY TO BROWNISH GRAY, OCCASIONAL OLIVE GRAY; LUMPY, NODULAR ROUNDED CUTTINGS ARE OCCASIONALLY SILTY APPEARING; EARTHY LUSTER; NON-CALCAREOUS; APPEARS TO BE INTERBEDDED WI ) DOMINANTLY PEBBLE HORIZONS. 410' MD CONGLOMERATIC SAND I SAND = VARIOUS PEBBLE COLORS RANGING FROM BLACK TO OLIVE GRAY, LIGHT GREEN, TRANSLUCENT; DOMINANTLY SUBANGULAR TO SUBROUNDED; MORE ANGULAR PEBBLES USUALLY W/ BROKEN MARGINS EXHIBITING ABRASION; POORLY SORTED; DOMINANTLY MODERATE SPHERICITY; NON-CALCAREOUS; PROBABLE PEBBLE BEDS WI CONSTANT SAND INFLUX. 460' M D CONGLOMERATIC SAND I SAND = VARIOUS PEBBLE COLORS RANGING FROM BLACK TO OLIVE GRAY, LIGHT GREEN, TRANSLUCENT; DOMINANTLY SUBANGULAR TO SUBROUNDED; MORE ANGULAR PEBBLES USUALLY WI BROKEN MARGINS EXHIBITING ABRASION; POORLY SORTED; DOMINANTLY MODERATE SPHERICITY; NON-CALCAREOUS; PROBABLE PEBBLE BEDS W/ CONSTANT SAND INFLUX; NO APPARENT OIL INDICATORS. 510' MD CLAYSTONE = OLIVE GRAY, MEDIUM BROWNISH GRAY; VERY SOFT TO SOFT; MUSHY, RUNNY, STIFF CONSISTENCY; APPEARS AS SLIGHTLY FIRM LUMPS OF CLAY; OCCASIONALLY APPEARS AS ROUGHLY FORMEDIUM IRREGULAR CUTTINGS; MATTE, I' EARTHY LUSTER; SMOOTH TO MODERATE [=I FP()( ~H 4 PHilliPS Alaska, Inc. PHIlliPS W lookout #2 GRITTY TEXTURE; NON CALCAREOUS; SCATTERED SIL TV ZONES; LOCALLY COMMON CARBONACEOUS SPECKS AND STREAKS. 560' MD CONGLOMERATIC SAND I SAND = MULTI-COLORED, ABUNDANT CLEAR, MODERATE BROWN, GRAY, LIGHT GREEN, TRANSLUCENT; CLASTS RANGE FROM FINE TO VERY COARSE; ANGULAR 610' MD CLAYSTONE = LIGHT BROWNISH GRAY TO OLIVE GRAY; VERY SOFT TO SOFT; THICK TO RUNNY, PASTY TO OCCASIONAL L Y CRUMBLY; DOMINANTLY APPEARS AS LUMPY CLAY IN SAMPLES; MATTE, EARTHY LUSTER; DOMINANTLY SMOOTH TO OCCASIONAL MODERATE GRITTY TEXTURE; NON CALCAREOUS; OCCASIONAL SILTY ZONES; COMMON CARBONACEOUS MATERIAL APPEARING AS FLAKES, STREAKS AND SPECKS; RARE WOOD FIBERS FREE IN SAMPLE. 660' MD SAND = MULTICOLORED, COMMONLY WHITE, FROSTED, BLACK, MODERATE BROWN; CLASTS RANGE FROM FINE TO VERY COARSE; ANGULAR TO ROUNDED, DOMINANTLY SUBROUNDED; MOST ANGULAR FRACTION IS PROBABLY ) DUE TO BIT SHEARING ACTION; POORLY SORTED; COMPOSED OF QUARTZ WITH ABUNDANT METAMORPHIC AND VOLCANIC LITHICS. 710' MD COAL = BLACK TO DUSKY BROWNISH BLACK; FIRM; CRUMBLY TO RARELY SIGHTLY BRITTLE; FLAKY, TABULAR AND IRREGULAR CUTTINGS; SLIGHTLY SHINY LUSTER; SMOOTH TEXTURE; LIGNITE GRADE; POSSIBLY OCCURS AS CLASTS IN THE SURROUNDING CLAYSTONE. 760' M D CLAYSTONE = OLIVE GRAY TO MEDIUM GREENISH GRAY; VERY SOFT TO SOFT; THICK TO OCCASIONAL RUNNY, PASTY TO OCCASIONALLY CRUMBLY; DOMINANTLY APPEARS AS CLAY WI LUMPS IN SAMPLES; MATTE, EARTHY LUSTER; DOMINANTLY SMOOTH TO OCCASIONAL MODERATELY GRITTY TEXTURE; NON CALCAREOUS; OCCASIONAL SILTY ZONES; COMMON CARBONACEOUS MATERIAL APPEARING AS FLAKES, STREAKS AND SPECKS; RARE WOOD FIBERS FREE IN SAMPLE. 810' MD SAND = CLEAR, WHITE, LIGHT TO MEDIUM GRAY, BLACK, LIGHT TO MEDIUM GREEN; CLASTS RANGE FROM FINE TO MEDIUM; ANGULAR TO ROUNDED, DOMINANTLY SUBANGULAR TO SUBROUNDED; MODERATE SORTED; RARE PEBBLE FRAGMENTS, l' [=I FP()('H 5 PHilliPS Alaska, Inc. PHilliPS m lookout #2 PROBABLY CAVINGS; 70% QUARTZ WITH 300k VOLCANIC AND METAMORPHIC LITHICS; LOOSE IN SAMPLE; CLAY MATRIX IS INFERRED. 860' M D CLAYSTONE = OLIVE GRAY TO MEDIUM BROWNISH GRAY; VERY SOFT TO SOFT; THICK TO OCCASIONAL RUNNY, PASTY TO OCCASIONALLY CRUMBLY; DOMINANTLY APPEARS AS LUMPY CLAY IN SAMPLES; DULL, EARTHY LUSTER; DOMINANTLY SMOOTH TO OCCASIONAL MODERATE GRITTY TEXTURE; NON CALCAREOUS; OCCASIONAL SILTY ZONES; SCATTERED CARBONACEOUS MATERIAL APPEARING AS FLAKES, STREAKS AND SPECKS; RARE WOOD FIBERS FREE IN SAMPLE. 910' MD SAND = NOTE SIGNIFICANT INCREASE IN LIGHT TO MEDIUM GREENISH GRAY GRAINS; NOW MEDIUM GREENISH GRAY OVERALL; CLASTS RANGE FROM FINE TO COARSE, DOMINANTLY MEDIUM RANGE; ANGULAR TO ROUNDED, DOMINANTLY SUBANGULAR TO SUBROUNDED, MODERATELY SORTED IN THE MEDIUM RANGE; COMPOSED OF 40% QUARTZ, 600/0 METAMORPHIC AND VOLCANIC LITHICS; GRAINS ARE LOOSE IN SAMPLE; NO EVIDENCE OF MATRIX. , 960' MD CLAYSTONE = LIGHT BROWNISH GRAY WITH MINOR OLIVE GRAY; VERY SOFT TO RARELY FIRM; DOMINANTLY APPEARS AS LUMPY CLAY, RARELY AS PLATEY BRITTLE WELL CONSOLIDATED CUTTINGS; DOMINANTLY EARTHY LUSTER, RARELY SLIGHTLY RESINOUS; LOCALLY MODERATELY SILTY; SCATTERED CARBONACEOUS MATERIAL; NON CALCAREOUS; NO EVIDENT STRUCTURE. 1010' MD CLAYSTONE = LIGHT BROWNISH GRAY WITH MINOR OLIVE GRAY; VERY SOFT TO RARELY FIRM; DOMINANTLY APPEARS AS LUMPY CLAY, RARELY AS PLATEY BRITTLE WELL CONSOLIDATED CUTTINGS; DOMINANTLY EARTHY LUSTER, RARELY SLIGHTLY RESINOUS LUSTER; NON TO RARELY SLIGHTLY CALCAREOUS; SCATTERED CARBONACEOUS MATERIAL; FIRMER CUTTINGS APPEARANCE; MICACEOUS IN PART. 1060' MD SAND = NOTE SIGNIFICANT DECREASE IN LIGHT TO MEDIUM GREENISH GRAY GRAINS; NOW MEDIUM GRAY WITH SALT & PEPPER APPEARANCE; CLASTS RANGE FROM FINE TO COARSE, DOMINANTLY MEDIUM RANGE; ANGULAR TO ROUNDED, DOMINANTLY SUBANGULAR TO SUBROUND; MODERATELY SORTED IN THE MEDIUM RANGE; COMPOSED OF look QUARTZ, 300k METAMORPHIC AND VOLCANIC LlTHICS; GRAINS ARE LOOSE IN SAMPLE; NO EVIDENCE OF MATRIX. [=I FP()(' H 6 PHilliPS Alaska, Inc. ''HIUI~ m lookout #2 1110'MD CLAYSTONE = LIGHT BROWNISH GRAY WITH MINOR OLIVE GRAY; VERY SOFT TO RARELY FIRM; DOMINANTLY APPEARS AS LUMPY CLAY, RARELY AS PLATEY BRITTLE WELL CONSOLIDATED CUTTINGS; DOMINANTLY EARTHY LUSTER, RARELY SLIGHTLY RESINOUS; LOCALLY MODERATELY SILTY; SCATTERED CARBONACEOUS MATERIAL; NON CALCAREOUS; NO STRUCTURE. 1160' MD SAND = LIGHT GREENISH GRAY OVERALL; CLASTS RANGE FROM FINE LOWER TO COARSE, DOMINANTLY FINE TO MEDIUM RANGE; ANGULAR TO ROUNDED, DOMINANTLY SUBANGULAR TO SUBROUND; MODERATELY SORTED IN THE FINE TO MEDIUM RANGE; COMPOSED OF 600/0 QUARTZ, 40% VOLCANIC AND META LITHICS; RARE CLUSTER OF FREE MICROCRYSTALLINE PYRITE; CLAY MATRIX INFERRED. 1210' MD CLAYSTONE = LIGHT TO MEDIUM BROWNISH GRAY, OLIVE GRAY; VERY SOFT TO SOFT; MUSHY TO RARELY BRITTLE; DOMINANTLY APPEARS AS AMORPHOUS CLAY WITH COMMON SLIGHTLY FIRM LUMPS; MATTE LUSTER; DOMINANTLY SMOOTH TO LOCALLY MODERATE GRITTY TEXTURE; NON CALCAREOUS; SCATTERED TO COMMON ) FINE SAND GRAINS EMBEDDED IN LUMPS; SCATTERED CARBONACEOUS SPECKS AND STREAKS. 1260' MD SAND = LIGHT GRAY WITH SLIGHTLY GREENISH HUE; CLASTS RANGE FROM FINE LOWER TO COARSE, DOMINANTLY FINE TO MEDIUM RANGE; ANGULAR TO ROUNDED, DOMINANTLY SUBANGULAR TO SUBROUND; MODERATELY SORTED IN THE FINE TO MEDIUM RANGE; COMPOSED OF 70% QUARTZ, 30% VOLCANICS AND META LITHICS; RARE CLUSTERS OF FREE MICROCRYSTALLINE PYRITE; CLAY MATRIX MATERIAL IN THIN CRUSTS ON A FEW GRAINS. 1310' MD SHALE = MEDIUM BROWNISH GRAY; SOFT TO MODERATELY FIRM; CRUMBLY TO SLIGHTLY BRITTLE; SMALL IRREGULAR AND PLATEY CUTTINGS; MATTE LUSTER; SMOOTH TO SLIGHTLY GRITTY TEXTURE; NON CALCAREOUS; SCATTERED CARBONACEOUS LAMINATIONS; SCATTERED ASHY APPEARING LAMINATIONS; POOR TO RARELY FAIR FISSILITY. 1360' MD TUFF = WHITE, LIGHT GRAY, PALE YELLOWISH BROWN; VERY SOFT TO RARELY FIRM; DOMINANTLY MATTE, RARELY WAXY LUSTER; SMOOTH TO ~ OCCASIONAL MODERATELY GRAINY TEXTURE; NON CALCAREOUS; [=I EP( )CH 7 PHilliPS Alaska, Inc. , SMALL SUBBLOCKY AND AMORPHOUS CUTTINGS; APPEARS BOTH FREE IN SAMPLE AND AS OCCASIONAL LAMINATIONS OR BLEBS IN THE CLAYSTONE. PHIlIlDS m Lookout #2 1410' MD SHALE = BROWNISH GRAY; SOFT TO MODERATELY FIRM; MALLEABLE TO SLIGHTLY CRUMBLY; SMALL IRREGULAR AND PLATEY CUTTINGS; MATTE LUSTER; SMOOTH TO SLIGHTLY GRITTY TEXTURE; NON CALCAREOUS; SCATTERED WEAK CARBONACEOUS AND ASHY APPEARING LAMINATIONS; POOR TO OCCASIONAL MODERATE FISSILITY; ANGULAR BREAKOUT; OFTEN GRADES TO CLAYSTONE; EASILY SCORED WI PROBE; TENDS TO BE DARKER BROWN THAN CLAYSTONE. 1460' MD TUFF = WHITE, LIGHT GRAY, PALE YELLOWISH BROWN; VERY SOFT TO OCCASIONAL FIRM; DOMINANTLY MATTE, WAXY LUSTER CONFINED TO RESINOUS PALE YELLOWISH TUFF PARTICLES; OCCASIONAL L Y MODERATELY GRAINY TEXTURE; NON-CALCAREOUS; SMALL SUBBLOCKY AND AMORPHOUS CUTTINGS; APPEARS BOTH FREE IN SAMPLE AND AS OCCASIONAL LAMINATIONS / SEGREGATIONS WITHIN CLAYSTONE HOST. ) 1540' MD CLAYSTONE = DOMINANTLY MEDIUM BROWNISH GRAY, RRL Y OLIVE GRAY; SOFT TO FIRM; MUSHY TO RARELY BRITTLE; DOMINANTLY APPEARS AS AMORPHOUS CLAY WITH COMMON SLIGHTLY FIRM LUMPS; MATTE LUSTER; DOMINANTLY SMOOTH TO LOCALLY FN GRITTY TEXTURE; NON- CALCAREOUS; SCATTERED TO OCCASIONAL COMMON FINE SAND GRAINS EMBEDDED AS SPARKLES; RARE FINE, DARK GRAY CARBONACEOUS MATERIAL; 1570' MD TUFF = WHITE, LIGHT GRAY, PALE YELLOWISH BROWN; GELATINOUS - RARELY FIRM; DOMINANTLY MATTE, OCCAS WAXY LUSTER; SMOOTH TO OCCASIONAL MODERATE GRAINY TEXTURE; NON CALCAREOUS; SMALL SUBBLOCKY AND AMORPHOUS CUTTINGS; APPEARS BOTH FREE IN SAMPLE AND AS OCCASIONAL THIN LAMINAE WITHIN CLAYSTONE PALE YELLOWISH TUFF IS BLOCKY, MODERATELY FIRM AND WAXY/RESINOUS. 1600' MD SAND = TRANSPARENT OVERALL, LIGHT GRAY QUARTZ GRAINS RANGE FROM MODERATE FINE » COARSE, DOMINANTLY CLEAR, SUCROSIC FINE TO UPPER FINE GRAINED; UBIQUITOUS COARSE GRAINED QUARTZ; SUBANGULAR TO SUBROUND; POORLY SORTED; PALE YELLOW/BROWN AND PALE GREEN LITHIC FRAGS DISSEMINATED RANDOMLY; (1 FP( )(~H 8 PHilliPS Alaska, Inc. ~ ~) lookout #2 1680' MD CLAYSTONE = DOMINANTLY MEDIUM BROWNISH GRAY, RRL Y OLIVE GRAY; SOFT TO FIRM; MUSHY TO RARELY BRITTLE; DOMINANTLY APPEARS AS AMORPHOUS CLAY WITH COMMON SLIGHTLY FIRM LUMPS; MATTE LUSTER; DOMINANTLY SMOOTH TO LOCALLY FINE GRITTY TEXTURE; NON- CALCAREOUS; SCATTERED TO OCCASIONALLY COMMON FINE SAND GRAINS EMBEDDED AS SPARKLES; RARE FINE, DARK GRAY CARBONACEOUS MATERIAL; 1730' MD SAND = TRANSPARENT OVERALL, LIGHT GRAY QUARTZ GRAINS RANGE FROM MODERATE FINE » COARSE, DOMINANTLY CLEAR, SUCROSIC FINE TO UPPER FINE GRAINED; OCCASIONAL COARSE GRAINED QUARTZ; DOMINANTLY SUBANGULAR; POORLY SORTED; PALE YELLOW/BROWN AND PALE GREEN LITHIC FRAGMENTS DISSEMINATED; COPIOUS, MINUTE DARK GRAY LITHIC FRAGMENTS THROUGHOUT; TRACE PYRITE; OCCASIONAL WHITE CaC03 CHUNKS RANDOMLY 1790' MD TUFF = WHITE, LIGHT GRAY, PALE YELLOWISH BROWN; GELATINOUS - RARELY FIRM; DOMINANTLY MATTE, OCCAS WAXY LUSTER; SMOOTH TO OCCASIONALLY MODERATE GRAINY TEXTURE; NON CALCAREOUS; SMALL ) SUBBLOCKY AND AMORPHOUS CUTTINGS; APPEARS BOTH FREE IN SAMPLE AND AS OCCASIONAL THIN LAMINAE WITHIN CLAYSTONE PALE YELLOWISH TUFF IS BLOCKY, MODERATELY FIRM AND WAXY/RESINOUS; DARK GRAY/BLACK CARBONACEOUS FLECKS COMMONLY PRESENT IN TUFFS. 1830' MD SAND = TRANSPARENT OVERALL, LIGHT GRAY QUARTZ GRAINS VARY FROM MODERATE FINE » COARSE, DOMINANTLY CLEAR, SUCROSIC FINE TO UPPER FINE GRAINED; OCCASIONAL COARSE GRAINED QUARTZ; DOMINANTLY SUBANGULAR; POORLY SORTED; OCCASIONAL PALE YELLOW/BROWN AND PALE GREEN LITHIC FRAGS DISSEMINATED; COPIOUS, MINUTE DARK GRAY LITHIC FRAGS THROUGHOUT; RARE PYRITE; OCCASIONAL WHITE CaC03 CHUNKS RANDOML Y 1890' MD CLAYSTONE = LIGHT TO MEDIUM BROWNISH GRAY; SOFT TO OCCASIONAL L Y FIRM; MUSHY TO RARELY BRITTLE; DOMINANTLY APPEARS AS AMORPHOUS CLAY WITH COMMON SLIGHTLY FIRM LUMPS; MATTE LUSTER; DOMINANTLY SMOOTH TO LOCALLY FINE GRITTY TEXTURE; NON-CALCAREOUS; SCATTERED TO OCCASIONAL COMMON FINE SAND GRAINS EMBEDDED AS SPARKLES; INCREASINGLY COMMON, FINE, DARK GRAY CARBONACEOUS MATERIAL; 11 1960' MD (:I EP()( ','H 9 PHilliPS Alaska, Inc. r~IlIlPS m lookout #2 TUFFACEOUS CLAYSTONE = LIGHT GRAY; SOFT TO MODERATELY FIRM; DOMINANTLY MATTE LUSTER; SMOOTH TO OCCASIONAL MODERATELY GRAINY TEXTURE; GENERALLY NON-CALCAREOUS; SMALL, AMORPHOUS CUTTINGS W/ ROUNDED MARGINS; PRESENT BOTH AS THIN LAMINAE WITHIN CLAYSTONE HOST AND AS INDIVIDUAL PARTICLES; DARK GRAY I BLACK CARBONACEOUS FLECKS COMMONLY DISTRIBUTED EVENLY THROUGHOUT, VERY CLAY-RICH; 2010' MD CLAYSTONE = LIGHT TO MEDiUM BROWNISH GRAY; SOFT TO OCCASIONAL L Y FIRM; MUSHY TO RARELY BRITTLE; DOMINANTLY APPEARS AS AMORPHOUS CLAY WITH COMMON SLIGHTLY FIRM LUMPS; MATTE LUSTER; DOMINANTLY SMOOTH TO LOCALLY FINE GRITTY TEXTURE; NON-CALCAREOUS; SCATTERED FINE SAND GRAINS EMBEDDED; COMMON DARK GRAY LITHIC MATERIAL 2060' MD SILTSTONE = MEDIUM TO DARK GRAY; PASTY TO MUSHY CONSISTENCY; CLAY-RICH; FINE DARK GRAY CARBONACEOUS INCLUSIONS COMMON; SILTY TO GRITTY TEXTURE; GRADES TO CLAYSTONE; OCCASIONALLY GRADES TO LOWER FINE SAND GRAINS; NON-CALCAREOUS; NO APPARENT FRACTURE; NODULAR ) APPEARANCE TO CUTTINGS; 2110' MD SAND = TRANSPARENT OVERALL, LIGHT GRAY QUARTZ; DOMINANTLY CLEAR SUCROSIC FINE TO UPPER FINE GRAINED; OCCASIONAL COARSE GRAINED QUARTZ; DOMINANTLY SUBANGULAR; POORLY SORTED; OCCASIONAL PALE YELLOW/BROWN AND PALE GREEN LITHIC FRAGMENTS DISSEMINATED; COPIOUS, MINUTE DARK GRAY LITHIC FRAGMENTS THROUGHOUT; RARE PYRITE; TRACE SHELL FRAGMENTS ARE LIGHT BROWNIYELLOW. 2160' MD CLAYSTONE = LIGHT TO MEDIUM BROWNISH GRAY; SOFT TO OCCASIONAL L Y FIRM; MUSHY TO RARELY BRITTLE; DOMINANTLY APPEARS AS AMORPHOUS CLAY WITH COMMON SLIGHTLY FIRM LUMPS; MATTE LUSTER; DOMINANTLY SMOOTH TO LOCALLY FN GRITTY TEXTURE; NON-CALCAREOUS; SCATTERED FINE SAND GRAINS INCORPORATED; GRADES TO SILTSTONE COM; DARK GRAY CARBONACEOUS SPECKS COMMON. 2210' MD SILTSTONE = MEDIUM GRAY; PASTY TO MUSHY CONSISTENCY; CLAY-RICH; FINE, DARK GRAY CARBONACEOUS INCLUSIONS COMMON; SILTY TO GRITTY TEXTURE; GRADES TO CLAYSTONE; CONTAINS LOWER FINE SAND GRAINS; NON-CALCAREOUS; , NO APPARENT FRACTURE; NODULAR APPEARANCE TO CUTTINGS; (:I FP( )(~H 10 PHilliPS Alaska, Inc. m lookout #2 2260' M D TUFFACEOUS CLAYSTONE = LIGHT GRAY; SOFT TO MODERATELY FIRM; DOMINANTLY MATTE LUSTER; SMOOTH TO OCCASIONAL MODERATE GRAINY TEXTURE; GENERALLY NON-CALCAREOUS; SMALL, AMORPHOUS CUTTINGS WI ROUNDED MARGINS; PRESENT BOTH AS THIN LAMINAE WITHIN CLAYSTONE HOST AND AS INDIVIDUAL PARTICLES; DARK GRAY I BLACK CARBONACEOUS FLECKS COMMONLY DISTRIBUTED EVENLY THROUGHOUT 2310' MD CLAYSTONE = LIGHT TO MEDIUM BROWNISH GRAY; SOFT TO RARELY FIRM; MUSHY TO RARELY BRITTLE: DOMINANTLY APPEARS AS AMORPHOUS CLAY WITH COMMON SLIGHTLY FIRM LUMPS; MATTE LUSTER; DOMINANTLY SMOOTH TO LOCALLY FINE GRITTY TEXTURE; NON-CALCAREOUS; SCATTERED FINE SAND GRAINS INCORPORATED; GRADES TO SILTSTONE; DARK GRAY CARBONACEOUS SPECKS COMMON. 2360' MD ASH FALL TUFF = WHITE, VERY LIGHT GRAY, PALE YELLOWISH BROWN; VERY SOFT TO FIRM; MUSHY TO MODERATELY BRITTLE; AMORPHOUS, PLATEY AND BLOCKY ) CUTTINGS; MATTE, CHALKY AND WAXY LUSTER; SMOOTH , TO SLIGHTLY GRITTY TEXTURE; NON CALCAREOUS; SCATTERED BLACK PINPOINT INCLUSIONS; OCCUR FREE IN SAMPLES AND AS BLEBS OR LAMINATIONS IN CLAYSTONES. 2410' MD CLAYSTONE = MEDIUM BROWNISH GRAY, LIGHT GRAY, RARELY OLIVE GRAY; VERY SOFT TO FIRM; MUSHY TO CRUMBLY, OCCASIONAL MODERATE BRITTLE; MATTE, EARTHY LUSTER; DOMINANTLY SMOOTH TO OCCASIONAL GRITTY/SIL TY; SUBBLOCKY AND AMORPHOUS CUTTINGS; NON TO LOCALLY MODERATELY CALCAREOUS; COMMONLY WITH ASHY APPEARANCE; COMMON STREAKS AND BLEBS OF DEVITRIFIED ASH; SCATTERED CARBONACEOUS SPECKS AND STREAKS. 2460' M D SILTSTONE = MEDIUM BROWNISH GRAY; SOFT TO FIRM; MUSHY TO CRUMBLY, OCCASIONALLY MODERATE TOUGH; IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE LUSTER WITH COMMON SPARKLES; GRITTY, ABRASIVE TEXTURE; LOCALLY COMMON ASHY APPEARANCE; ARGILLACEOUS, GRADING IN PART TO AND INTERBEDDED WITH CLAYSTONE. 2510' MD [=I F P( )( ~ H 11 PHilliPS Alaska, Inc. ) CLAYSTONE = MEDIUM BROWNISH GRAY, LIGHT GRAY, RARELY OLIVE GRAY; VERY SOFT TO FIRM; MUSHY TO CRUMBLY, OCCASIONALLY MODERATE TOUGH; DULL, EARTHY LUSTER; DOMINANTLY SMOOTH TO OCCASIONALLY ABRASIVE; SUBBLOCKY AND AMORPHOUS CUTTINGS; NON TO LOCALLY MODERATELY CALCAREOUS; COMMONLY WITH ASHY APPEARANCE; COMMON STREAKS AND BLEBS OF DEVITRIFIED ASH; SCATTERED CARBONACEOUS SPECKS AND STREAKS I'IIIILlPS m;J lookout #2 2560' M D ASH FALL TUFF = WHITE, VERY LIGHT GRAY, PALE YELLOWISH BROWN, MODERATE REDDISH ORANGE; FIRM; MUSHY TO MODERATELY BRITTLE, AMORPHOUS, PLATEY AND BLOCKY CUTTINGS; MATTE, CHALKY AND WAXY LUSTER; SMOOTH TO SLIGHTLY GRITTY TEXTURE; NON CALCAREOUS; SCATTERED BLACK PINPOINT INCLUSIONS; OCCURS FREE IN SAMPLE S AND AS BLESS OR LAMINATIONS IN CLAYSTONES. 2610' MD SILTSTONE = MEDIUM BROWNISH GRAY; SOFT TO FIRM; MUSHY TO CRUMBLY, RARELY MODERATELY TOUGH; IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE LUSTER WITH COMMON SPARKLES; GRITTY, ABRASIVE TEXTURE; LOCALLY COMMON J ASHY APPEARANCE; GRADES TO AND IS INTERBEDDED WITH CLAYSTONE. 2660' MD CLAYSTONE = MEDIUM BROWNISH GRAY, LIGHT GRAY, DARK BROWNISH GRAY; SOFT TO OCCASIONALLY FIRM; MUSHY TO CRUMBL Y, OCCASIONAL MODERATE BRITTLE; DULL, EARTHY LUSTER; DOMINANTLY SMOOTH TO OCCASIONAL GRAINY TEXTURE; IRREGULAR AND BLOCKY CUTTINGS; NON TO LOCALLY SLIGHTLY CALCAREOUS; COMMON CHALKY APPEARANCE; COMMON STREAKS AND BLEBS OF DEVITRIFIED ASH; SCATTERED CARBONACEOUS SPECKS AND STREAKS. 2710' MD SILTSTONE = MEDIUM BROWNISH GRAY; SOFT TO FIRM; MUSHY TO CRUMBLY, OCCASIONALLY MODERATE TOUGH; IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE LUSTER WITH COMMON SPARKLES; GRITTY, ABRASIVE TEXTURE; LOCALLY COMMON ASHY APPEARANCE; NON TO OCCASIONAL SLIGHTLY CALCAREOUS; GRADES TOAND IS INTERBEDDED WITH CLAYSTONE. 2760' M 0 SHALE = DARK GRAY WITH SLIGHTLY BROWNISH HUES; FIRM TO OCCASIONALLY MODERATELY HARD; SUBTABULAR, BLOCKY, OCCASIONALLY [:I FP()( 'H 12 PHilliPS Alaska, Inc. P~IILIPS m lookout #2 PLATEY CUTTINGS; DULL LUSTER WITH SCATTERED SPARKLES; DOMINANTLY SMOOTH TO SLIGHTLY GRAINY TEXTURE; NON CALCAREOUS; SCATTERED STREAKS AND LAMINATIONS OFASHY APPEARING MATERIAL; POOR TO FAIR FISSILITY. 2810' MD CLAYSTONE = MEDIUM OLIVE GRAY, LIGHT GRAY, MEDIUM BROWNISH GRAY; SOFT TO OCCASIONAL FIRM; MUSHY TO CRUMBLY, OCCASIONALLY SLIGHTLY BRITTLE; DULL, EARTHY LUSTER; DOMINANTLY SMOOTH TO OCCASIONAL GRITTY TEXTURE; SUBBLOCKY AND IRREGULAR CUTTINGS; NON TO LOCALLY SLIGHTLY CALCAREOUS; COMMON BLACK PINPOINT SPECKS; COMMON STREAKS AND BLESS OF DEVITRIFIED ASH; LOCALLY SILTY, GRADING IN PART TO SILTSTONE. 2860' MD ASH FALL TUFF = WHITE, VERY LIGHT GRAY, PALE YELSH BROWN, MODERATE REDDISH ORANGE; SOFT TO FIRM, OCCASIONALLY MODERATE HARD; AMORPHOUS, PLATEY AND BLOCKY CUTTINGS; MATTE, CHALKY AND WAXY LUSTER; SMOOTH TO SLIGHTLY GRITTY TEXTURE; NON CALCAREOUS; SCATTERED BLACK PINPOINT INCLUSIONS; OCCURS FREE IN SAMPLE S AND AS BLE8S OR LAMINATIONS IN CLAYSTONES AND SILTSTONE 2910' MD CLAYSTONE = MEDIUM OLIVE GRAY, LIGHT TO MEDIUM BROWNISH GRAY; SOFT TO OCCASIONAL FIRM; MUSHY TO CRUMBLY, OCCASIONAL SLIGHTLY BRITTLE; DULL, EARTHY LUSTER; DOMINANTLY SMOOTH TO OCCASIONAL GRITTY TEXTURE; AMORPHOUS AND BLOCKY CUTTINGS, RARELY TABULAR; NON TO SLIGHTLY CALCAREOUS; COMMON BLACK PINPOINT SPECKS; COMMON STREAKS AND BLESS OF DEVITRIFIED ASH; LOCALLY SIL TV, GRADING IN PART TO SILTSTONE. 2960' MD SILTSTONE = MEDIUM BROWNISH GRAY; SOFT TO FIRM; MUSHY TO CRUMBLY, OCCASIONAL MODERATE TOUGH; IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE LUSTER WITH COMMON SPARKLES; GRITTY, ABRASIVE TEXTURE; LOCALLY COMMON ASHY APPEARANCE; NON TO OCCASIONAL SLIGHTLY CALCAREOUS; GRADES TO AND IS INTERBEDDED WITH CLAYSTONE. 3010' MD CLAYSTONE = MEDIUM OLIVE GRAY, LIGHT TO MEDIUM BROWNISH GRAY; SOFT TO OCCASIONAL FIRM; MUSHY TO CRUMBL Y, OCCASIONAL SLIGHTLY BRITTLE; DULL, EARTHY LUSTER; DOMINANTLY SMOOTH TO OCCASIONAL GRITTY TEXTURE; AMORPHOUS AND BLOCKY CUTTINGS, RARELY TABULAR; NON TO SLIGHTLY (:I F.l)()(' H 13 PHilliPS Alaska, Inc. PHilliPS W lookout #2 CALCAREOUS; COMMON BLACK PINPOINT SPECKS; COMMON STREAKS AND BLEBS OF DEVITRIFIED ASH; LOCALLY SILTY, GRADING IN PART TO SILTSTONE. 3060' MD SILTSTONE = MEDIUM BROWNISH GRAY; SOFT TO FIRM; MUSHY TO CRUMBLY, OCCASIONALLY MODERATE TOUGH; IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE LUSTER WITH COMMON SPARKLES; GRITTY, ABRASIVE TEXTURE; STRONG CLAYITUFF MATRIX. NON TO OCCASIONAL SLIGHTLY CALCAREOUS; GRADES TO AND IS INTERBEDDED WITH CLAYSTONE 3150' MD CLAYSTONE = OLIVE BROWN, OCCASIONAL MEDIUM GRAY BROWN;; VERY SOFT TO SLIGHTLY FIRM; ROUNDED, BLOCKY HABIT; EARTHY LUSTER; MODERATELY EXPANSIVE WHEN HYDRATED; OCCASIONAL SCATTERED MICRO-MICA FLAKES; CLAY SUPPORTS LOWER FINE GRAINED, ANGULAR CLEAR DARK GRAY/BLACK CARBONACEOUS FLECKS DISSEMINATED THROUGHOUT CLAYS; CLAY SUPPORTS LOWER FINE GRAINED, ANGULAR CLEAR QUARTZ GRAINS IN VARIABLE AMOUNTS 1-2°/Ó. 3200' M D ) SILTSTONE = DOMINANTLY MEDIUM GRAY; CLAY MATRIX SUPPORTS GRITTY QUARTZ/FELDSPAR/LITHIC GRAINS; OCCASIONAL LIGHT GRAYISH BROWN; GRADES TO CLAYSTONE; TENDS TO BE THIN, mm THICK LAYERS VISIBLE IN CLAYSTONE HOST; NON-REACTIVE W/ DILUTE HCL 3250' M D SHALE = DARK GRAY TO MEDIUM DARK GRAY W/ GREENISH BLACK HUES; SOFT TO FRIABLE; CRUMBLY TO OCCASIONAL CRUNCHY TENACITY; FAIR TO MODERATELY FISSILE; IRREGULAR CUTTINGS HABIT; EARTHY LUSTER; SILTY TO OCCASIONAL ABRASIVE TEXTURE. 3300' MD SILTSTONE = MEDIUM LIGHT GRAY TO LIGHT BROWN GRAY; SOFT TO FRIABLE; CRUMBLY TENACITY; IRREGULAR FRACTURE AND CUTTINGS HABIT; SILTY TO CLAYEY TEXTURE; EARTHY LUSTER; OCCASIONAL ASHY SHARDS; NO VISIBLE FOSSILS OR STRUCTURES; TRACE OF UNCONSOLIDATED SAND GRAIN; QUARTZ DOMINANT; VERY FINE LOWER; ROUNDED TO SUBROUNDED; MODERATE TO HIGH SPHERICITY; NO VISIBLE SURFACE ETCHINGS. 3350' MD CLAYSTONE = PALE YELLOWISH BROWN W/ PALE BROWN HUES TO LIGHT BROWNISH GRAY W/ GREENISH GRAY HUES; SOFT TO EASILY FRIABLE; CRUMBLY TO MUSHY (1 EP()CH 14 PHilliPS Alaska, Inc. ~I\IIPS W lookout #2 ) TENACITY; IRREGULAR FRACTURE; IRREGULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO OCCASIONAL SILTY TEXTURE; OCCASIONALLY GRADES TO TUFFACEOUS CLAYSTONE. 3400' MD ARGILLACEOUS SANDSTONE = PALE YELLOWISH BROWN WI PALE BROWN HUES; VERY FINE LOW TO OCCASIONAL VERY FINE UPPER GRAINED; FRIABLE TO FIRMLY FRIABLE; CRUMBLY TO CRUNCHY; SLIGHTLY SILICA CEMENTING; GRAIN SUPPORTED; MODERATE TO WELL SORTED; SUBROUNDED TO ROUNDED GRAINS; MODERATETO HIGH SPHERICITY; QUARTZ DOMINANT WI <10% MAFICS; NO OIL INDICATORS. 3450' MD ARGILLACEOUS SANDSTONE = PALE YELLOWISH BROWN WI PALE BROWN HUES; SOFT TO EASILY FRIABLE; CRUMBLY; POORLY CEMENTED; CLAY MATRIX SUPPORT; UPPER FINE TO LOWER MEDIUM GRAINED; FAIR TO MODERATE SORTING; SUBANGULAR TO SUBROUNDED GRAINS; MODERATE SPHERICITY; POOR TO FAIR ESTIMATED PERMEABLIL TY AND POROSITY NO OIL INDICATORS. ) 3500' MD , SANDSTONE = PALE YELLOWISH BROWN TO GRAYISH ORANGE; FRIABLE; SLIGHTLY SILICA CEMEMTED; LOWER VERY FINE GRAINED; GRAIN SUPPORT; MODERATE TO WELL SORTED; SUBANGULAR TO SUBROUNDED; MODERATE SPHERICITY; POOR ESTIMATED POROSITY AND PERMEABILITY; NO OIL INDICATORS. 3550' M D CLAYSTONE = PALE YELLOWISH BROWN TO GRAYISH ORANGE; VERY SOFT TO SOFT; MUSHY TO CRUMBLY TENACITY; IRREGULAR FRACTURING AND IRREGULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TEXTURE; OCCASIONAL FISSILE, GRADING TO SHALE; OCCASIONAL FINE WHITE LAMINATIONS; LOOSE SAND IS QUARTZ DOMINANT, SUBROUNDED TO ROUNDED, LOWER FINE TO UPPER VERY FINE GRAINED; SPOTTY PALE YELLOW TO OCCASIONALLY BRIGHT YELLOW FLUORESCENCE; VERY SLIGHT OIL INDICATORS. 3600' M D SAND = CLEAR TO TRANSLUCENT; QUARTZ DOMINANT; UNCONSOLIDATED; LOWER FINE TO UPPER VERY FINE GRAIN-SIZE; SUBROUNDED TO ROUNDED; MODERATETO HIGH SPHERICITY; NO VISIBLE SURFACE ETCHINGS; NO FLUORESCENCE. 3650' M D [:I El)()(':H 15 PHilliPS Alaska, Inc. PHilliPS W lookout #2 ) CLAYSTONE = PALE YELLOWISH BROWN TO GRAYISH ORANGE; VERY SOFT TO SOFT, MUSHY TO CRUMBLY TENACITY; IRREGULAR FRACTURING AND IRREGULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TEXTURE; NO VISIBLE FOSSILS OR STRUCTURES; NO FLUORESCENCE. 3700' MD SANDSTONE = PALE YELLOWISH BROWN TO GRAYISH ORANGE; FRIABLE; SLIGHTLY SILICA CEMENT; LOWER VERY FINE GRAINED; GRAIN SUPPORTED; MODERATE TO WELL SORTED; SUBANGULAR TO SUBROUNDED; MODERATE SPHERICITY; POOR ESTIMATED POROSITY AND PERMEABILITY; NO FLUORESCENCE. 3750' MD SILTSTONE = MEDIUM GRAY TO MEDIUM LIGHT GRAY; FRIABLE TO FIRMLY FRIABLE; CRUNCHY TO OCCASIONAL CRUMBLY TENACITY; IRREGULAR FRACTURING & CUTTINGS HABIT; DULL TO EARTHY LUSTER; GRITTY TEXTURE; GRADES INTO SILTY CLAYSTONE; NO FLUORESCENCE. 3800' MD SAND = CLEAR TO TRANSLUCENT; QUARTZ DOMINANT; UNCONSOLIDATED; LOWER FINE TO GRAIN-SIZE; SUBROUNDED TO ROUNDED; MODERATE TO HIGH SPHERICITY; ) NO VISIBLE SURFACE ETCHINGS; NO FLUORESCENCE 3850' MD SHALE = DARK GRAY TO BROWNISH BLACK; FIRMLY FRIABLE TO MODERATE HARD; PLANAR FRAC; SUBPLANAR TO IRREGULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER, SMOOTH TEXTURE; MODERATE FISSILE; NO FLUORESCENCE. 3900' MD SILTSTONE = MEDIUM GRAY TO MEDIUM LIGHT GRAY; FRIABLE TO FIRMLY FRIABLE; CRUNCHY TO OCCASIONAL CRUMBLY TENACITY; IRREGULAR FRACTURING & CUTTINGS HABIT; DULL TO EARTHY LUSTER; GRITTY TEXTURE; GRADES INTO SILTY SANDSTONE; NO FLUORESCENCE. 3950' MD CLAYSTONE = PALE BROWN TO PALE YELLOW BROWN; SOFT TO VERY SOFT; MUSHY TO CRUMBLY; IRREGULAR FRACTURE & CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO OCCASIONAL SILTY TEXTURE; OCCASIONAL BLACK LAMINATIONS; NOFLUORESCENCE. 4000' MD TUFFACEOUS CLAYSTONE = LIGHT-MEDIUM GRAY; SOFT; DOMINANTLY MATTE . LUSTER; SMOOTH TO OCCASIONAL MODERATE GRAINY TEXTURE; GENERALLY ~ [:I F l)()("' H 16 PHilliPS Alaska, Inc. PHlllIP~ m lookout #2 NON-CALCAREOUS; SMALL, AMORPHOUS CUTTINGS W/ ROUNDED MARGINS; PRESENT BOTH AS THIN LAMINAE WITHIN CLAYSTONE HOST AND AS SEPARATE CUTTINGS; TENDS TO HYDRATE MORE QUICKLY THAN CLAYSTONE; DARK GRAY/ BLACK FLECKS AND BANDS COMMON.VERY ADHESIVE / COHESIVE / MALLEABLE 4050' MD SILTSTONE = MEDIUM LIGHT GRAY TO LIGHT BROWN GRAY; SOFT TO FRIABLE; CRUMBLY TENACITY; IRREGULAR FRACTURE AND CUTTINGS HABIT; SILTY TO CLAYEY TEXTURE; EARTHY LUSTER; OCCASIONAL ASHY SHARDS; CRUDE LAMELLAR STRUCTURES; TRACE OF UNCONSOLIDATED SAND GRAINS; QUARTZ DOMINANT; VERY FINE LOWER; ANGULAR TO SUBANGULAR; LOW-MODERATE SPHERICITY; 4100' MD CLAYSTONE = BROWNISH GRAY TO PALE BROWN; VERY SOFT TO RARELY FIRM; DOMINANTLY APPEARS AS LUMPY CLAY, RARELY AS PLATEY, SUB-SHALE, WEAKLY FISSILE CUTTINGS; EARTHY LUSTER; VARIABLY SILTY TRANSGRESSES INTO MUDSTONE; VERY STICKY; COMMON DARK GRAY/BLACK CARBONACEOUS FLECKS AND RARE PYRITE PARTICLES. , 4150' MD SHALE = BROWNISH GRAY, MEDIUM DARK GRAY; CRUDELY FISSILE; DEVELOPING SHALEY CLEAVAGE; COMMON DARK GRAY/BLACK CARBON- ACEOUS MATERIAL DISSEMINATED ALONG BEDDING PLANES; EARTHY LUSTER; WEAK-MODERATE COHESION, STRONG ADHESION; DEVITRIFIED VOLCANIC GLASS/ASH AND WEAK MICROSPARKLES SCATTERED UNEVENLY; PREDOMINANTLY NON-CALCAREOUS; GRADES TO CLAYSTONE. 4200' MD CLAYSTONE = BROWNISH GRAY TO PALE BROWN; VERY SOFT TO RARELY FIRM; DOMINANTLY APPEARS AS LUMPY CLAY, RARELY AS PLATEY, SUB-SHALE, WEAKLY FISSILE CUTTINGS; EARTHY LUSTER; VARIABLY SILTY TRANSGRESSES INTO MUDSTONE; VERY STICKY; COMMON DARK GRAY/BLACK CARBONACEOUS FLECKS AND RARE ANHEDRAL PYRITE; DOMINANTLY SMOOTH; MODERATE-STRONGLY EXPANSIVE WHEN HYDRATED. 4250' MD SILTSTONE = MEDIUM LIGHT GRAY TO LIGHT BROWN GRAY; SOFT TO FRIABLE; CRUMBLY TENACITY; IRREGULAR FRACTURE AND CUTTINGS HABIT; SIL TV TO CLAYEY TEXTURE; EARTHY LUSTER; OCCASIONAL ASHY DEVITRIFIED GLASS SHARDS; CRUDE LAMELLAR STRUCTURES; TRACE OF UNCONSOLIDATED SAND l' GRAINS; QUARTZ DOMINANT; VERY FINE [=I FP()t'H 17 PHilliPS Alaska, Inc. ) LOWER; ANGULAR TO SUBANGULAR; LOW-MODERATE SPHERICITY; GRITTY TEXTURE; GRADES TO CLAYSTONE; DARK GRAY/BLACK CARBONACEOUS SPECKS THROUGHOUT. P~llllpo; m lookout #2 4300' MD SHALE = DOMINANTLY MEDIUM DARK GRAY- BROWNISH GRAY CRUDELY FISSILE; DEVELOPING SHALEY CLEAVAGE: COMMON DARK GRAY/BLACK CARBONACEOUS MATERIAL DISSEMINATED ALONG BEDDING PLANES; EARTHY LUSTER; WEAK-MODERATE COHESION, STRONG ADHESION; DEVITRIFIED VOLCANIC GLASS/ASH AND WEAK MICROSPARKLES SCATTERED UNEVENLY; APPEARS MICACEOUS, FOLIATED. 4350' M D CLAYSTONE = BROWNISH GRAY TO MEDIUM DARK BROWN; VERY SOFT TO RARELY FIRM; DOMINANTLY APPEARS AS LUMPY CLAY, RARELY AS PLATEY, SUB-SHALE, WEAKLY FISSILE CUTTINGS; EARTHY LUSTER; VARIABLY SIL TV, OFTEN COLLOIDAL APPEARING; VERY STICKY; COMMON DARK GRAY/BLACK CARBONACEOUS FLECKS AND RARE ANHEDRAL PYRITE; DOMINANTLY SMOOTH; MODERATELY-STRONGLY EXPANSIVE WHEN HYDRATED. ~ 4400' MD SILTSTONE = MEDIUM LIGHT GRAV TO LIGHT BROWN GRAY; TWO DISTINCT SILT POPULATIONS PRESENT: SOFT TO FRIABLE; CRUMBLY TENDENCY; IRREGULAR FRACTURE AND CUTTINGS HABIT, SILTY TO CLAYEY TEXTURE; EARTHY LUSTER; OCCASIONAL ASHY DEVIT GLASS SHARDS; CRUDE LAMELLAR STRUCTURE; TRACE OF UNCONSOLIDATED SAND GRAINS; QUARTZ DOMINANT; VERY FINE LOWER; ANGULAR TO SUBANGULAR; LOW- MODERATE SPHERICITY; GRITTY TEXTURE; MED-LIGHT GRAY SILTSTONE TENDS TO BE DRIER, MORE CRUMBLY, SLIGHTLY COARSER; SLOWLY REACTIVE W/ DILUTE HCL. 4500' M D COARSE QUARTZ PEBBLES / GLASS GRAINS = LIGHT BROWN, MODERATE BROWN TO VELlOW, SUBROUNDED TO OVOID, TRANSPORTED; ASSOCIATED WITH TRANSPARENT TO LIGHT LOWER TO UPPER FINE GRAINED QUARTZ GRAIN LOCAL INCREASE; PEBBLES ARE RESINOUS; COAL FRAGMENTS TO 5°/Ó DISSEMINATED LOOSEL Y. 4550' M D SHALE = DOMINANTLY MEDIUM LIGHT GRAY- BROWNISH GRAY INCREASINGLY FISSILE; SHALEY CLEAVAGE; COMMON DARK GRAY/BLACK CARBONACEOUS MATERIAL DISSEMINATED ALONG BEDDING PLANES; EARTHY LUSTER; MODERATE- STRONG COHESION; DEVITRIFIED VOLCANIC GLASS/ASH AND NUMEROUS [=I FP()( ~H 18 PHilliPS Alaska, Inc. ~ W lookout #2 MICROSPARKLES SCATTERED UNEVENLY; APPEARS MICACEOUS, FOLIATED; LARGE >2cm CHUNKS NOTED ON SHAKER TABLE. 4600' MD SAND = TRANSPARENT OVERALL, LIGHT GRAY QUARTZ DOMINANTLY CLEAR, SUCROSIC LOWER FN TO UPR FN GRAINED; OCCASIONAL COARSER GRAINED QUARTZ; DOMINANTLY SUBANGULAR; WELL SORTED; OCCASIONAL PALE YELLOW/BROWN AND PALE GREEN LITHIC FRAGMENTS DISSEMINATED; COPIOUS, MINUTE DARK GRAY LITHIC FRAGS PLUS COAL TO 3-40/0 THRUOUT; RARE ANHEDRAL PYRITE SPOTTY PL YELLOW FLUORESCENCE ONLY; 4650' MD SILTSTONE = MEDIUM LIGHT GRAY W/ LIGHT BROWN GRAY; INCREASL Y HARD; CRUMBLY TENSION; SUB PLATEY CUTTINGS HABIT; IRREGULAR FRACTURE; DOMINANTLY SIL TV TEXTURE; EARTHY LUSTER; OCCASIONAL ASHY DEVITRIFIED GLASS SHARDS; LAMELLAR BEDDING DEFINED BY BLACK CARBONACEOUS MATERIAL; TRACE TO 30/0 UNCONSOLIDATED, VERY FINE QUARTZ GRAINS; WITHIN SIL T- SIZED PARTICLES IN CALCITE MATRIX; ASSOCIATED LOOSE, WHITE CALCITE PARTICLES RANDOMLY: EXHIBITS PALE YELLOW FLUORESCENCE; SPOTTY BLUE/WHITE CUT FLUORESCENCE OVERALL IN SAMPLE. 4700' MD CLAYSTONE = BROWNISH GRAY TO MEDIUM DARK BROWN; VERY SOFT TO RARELY FIRM; DOMINANTLY APPEARS AS LUMPY CLAY, OCCASIONAL GRADES TO PLA TEY, PROTO-SHALE -IE- WEAKLY FISSILE CUTTINGS; EARTHY LUSTER; VARIABLY SILTY; OFTEN COLLOIDAL APPEARING; ADHESIVE; COMMON DARK GRAY/BLACK CARBONACEOUS FLECKS AND RARE ANHEDRAL PYRITE; DOMINANTLY SMOOTH; MODERATELY-STRONGLY EXPANSIVE WHEN HYDRATED. 4750' MD SHALE = DOMINANTLY MEDIUM LIGHT GRAY- BROWNISH GRAY INCREASINGLY FISSILE; SHALEY CLEAVAGE; COMMON DARK GRAY/BLACK CARBONACEOUS MATERIAL DISSEMINATED ALONG BEDDING PLANES; EARTHY LUSTER; MODERATEL Y- STRONG COHESION; DEVITRIFIED VOLCANIC GLASS/ASH AND NUMEROUS MICROSPARKLES SCATTERED UNEVENLY; APPEARS MICACEOUS, FOLIATED; 4800' MD CLAYSTONE = BROWNISH GRAY TO LIGHT BROWNISH GRAY; VERY SOFT; MUSHY TO CLUMPY; IRREGULAR FRACTURE; IRREGULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO RARELY SILTY TEXTURE; TRACE AMOUNT OF LOWER VERY FINE QUARTZ GRAINS, SUBROUNDED TO ROUNDED, HIGH SPHERICITY; NO DISCERNABLE STRUCTURES; NO FLUORESCENCE. [=I fP()('H 19 PHilliPS Alaska, Inc. ~ 4850' MD CLAYSTONE = BROWNISH GRAY TO LIGHT BROWNISH GRAY; VERY SOFT; MUSHY TO CLUMPY; IRREGULAR FRACTURE; IRREGULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO RARELY SILTY TEXTURE; TRACE AMOUNT OF LOWER VERY FINE QUARTZ GRAINS, SUBROUNDED TO ROUNDED, HIGH SPHERICITY; NO DISCERNABLE STRUCTURES; NO FLUORESCENCE. PHilLIPS f:D lookout #2 4950' MD CLAYSTONE = BROWNISH GRAY TO LIGHT BROWNISH GRAY; VERY SOFT TO SOFT; CRUMBLY TO MUSHY; IRREGULAR FRACTURE; IRREGULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO OCCASIONAL SIL TV TEXTURE; NO DISCERNABLE STRUCTURES; NO FLUORESCENCE 5000' M D SHALE = DARK YELLOWISH BROWN TO DUSKY YELLOWISH BROWN GRAYISH BROWN HUES; FRIABLE; SUBBLOCKY TO IRREGULAR FRACTURE; BLOCKY TO IRREGULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TO OCCASIONAL SILTY TEXTURE; OCCASIONAL THIN BLACK LAMINAE; NO FLUORESCENCE. 5050' M D ~ SHALE = DARK YELLOWISH BROWN TO DUSKY YELLOWISH BROWN WI GRAYISH BROWN HUES; FRIABLE; SUBBLOCKY TO PLATEY FRACTURE; BLOCKY TO IRREGULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TO OCCASIONAL SIL TV TEXTURE; OCCASIONAL THIN BLACK LAMINAE; NO FLUORESCENCE. 5100' MD SANDSTONE = MEDIUM GRAY TO BROWNISH GRAY POORLY CONSOLIDATED; LOWER VERY FINE GRAINED; CLAY MATRIX SUPPORTED; UNCEMENTED QUARTZ GRAINS; SUBROUNDED TO ROUNDED; MODERATE TO HIGH SPHERICITY; NO VISIBLE SURFACE ETCHINGS; NO FLUORESCENCE. 5150' MD SILTSTONE = DUSKY BROWN TO BROWNISH BLACK; MODERATE SOFT TO FRIABLE; BLOCKY TO IRREGULAR FRACTURE; IRREGULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; SIL TV TEXT SILT PARTICLES GRADE INTO LOWER VERY FINE GRAIN QUARTZ SAND; NO FLUORESCENCE. 5200' MD CLAYSTONE = PALE BROWN TO PALE YELLOW BROWN; VERY SOFT TO SOFT; CRUMBLY TO MUSHY; IRREGULAR TO PLANAR FRACTURE ALONG BEDDING PLANES; IRREGULAR CUTTINGS HABIT; EARTHY TO DULL LUSTER; CLAYEY TO OCCASIONAL , SILTY TEXTURE; VERY THIN BEDDING, -1 MM THICK; NO FLUORESCENCE. i [:I FP()(", H 20 PHilliPS Alaska, Inc. ~HIIIIP5 m lookout #2 5250' M D SHALE = MEDIUM DARK GRAY TO BROWNISH GRAY; DEVELOPING FISSILlTY W/ DEPTH; INTERBEDDED W/ CLAYSTONE; WEAKLY HYDRATED SOFT W/OCCASIONAL BRITTLE WITH BETTER INDURATED SECTIONS; CRUDELY PLANAR CUTTINGS; EASILY SCORED W/ PROBE; DARK GRAY/BLACK CARBONACEOUS MATERIAL DISSEMINATED AND CONCENTRATED ALONG BEDDING PLANES; SMOOTH TO OCCASIONAL GRITTY; SCATTERED MICROSPARKLES; GREASY, SOAPY TEXTURE. 5350' M D SILTSTONE = MEDIUM DARK GRAY W/ LIGHT BROWNISH GRAY; INCREASINGLY HARD; CRUMBLY TENSION; MASSIVE -PLANAR CUTTINGS HABIT; IRREGULAR FRACTURE; DOMINANTLY SILTY TEXTURE; EARTHY LUSTER;OCCASIONAL ASHY DEVITRIFIED GLASS SHARDS; LAMELLAR BEDDING DEFINED BY BLACK CARBONACEOUS MATERIAL; TRACE TO 3°k UNCONSOLIDATED VERY FINE QUARTZ GRAINS WITH IN SILT SIZED PARTICLES IN CALCITE MATRIX; THIN, BRITTLE, HARD CLAYSTONE ZONES DEVELOPING W/ DEPTH - GOOD POROSITY/PERMEABILITY. 5400' MD CLAYSTONE = BROWNISH GRAY; VERY SOFT OCCASIONAL FIRMS ADJACENT TO ì, CLAYSTONE/SHALES THOUGH DOMINANTLY APPEARS AS LUMPYRITECLA Y, OCCASIONAL GRADES TO PLATEY, PROTO-SHALE -IE- WEAKLY FISSILE CUTTINGS; EARTHY LUSTER; VARIABLY SILTY; OFTEN COLLOIDAL APPEARING; ADHESIVE; SCATTERED DARK GRAY/BLACK CARBONACEOUS FLECKS DOMINANTLY SMOOTH; PERSISTENT ANHEDRAL PYRITE; «1 %; OCCASIONAL CALCITE PARTICLES INVARIABLY FLUORESCE 5450' MD TUFFACEOUS CLAYSTONE = LIGHT-MEDIUM GRAY; SOFT; DOMINANTLY MATTE LUSTER; SMOOTH TO OCCASIONAL MODERATE GRAINY TEXTURE; GENERALLY NON-CALCAREOUS; SMALL, AMORPHOUS CUTTINGS W/ROUNDED MARGINS; TENDS TO HYDRATE / SWELL QUICKLY; COMMON BLACK CARBONACEOUS FLECKS DISSEMINATED; UNIT COLOR-DISTINCT FROM CLAYSTONE. 5500' M D SILTSTONE = MEDIUM DARK GRAY W/ LIGHT BROWN GRAY; SOFT-MODERATE HARD; CRUMBLY TENSION; MASSIVE -PLANAR CUTTINGS HABIT; IRREGULAR FRACTURE; DOMINANTLY SILTY TEXTURE; EARTHY LUSTER; OCCASIONAL ASHY DEVITRIFIED GLASS SHARDS; BLACK CARBONACEOUS MATERIAL DISSEMINATED SPARSELY; CALCAREOUS MATRIX CALCITE PARTICLES TO mm DIAMETER ASSOCIATED. 5550' M D [=I F 1"){ )(' H 21 PHilliPS Alaska, Inc. , CLAYSTONE = BROWNISH GRAY; VERY SOFT OCCASIONAL FIRMS ADJACENT TO SILTSTONE; DOMINANTLY AMORPHOUS CLAY, OCCASIONAL GRADES TO SOFT, PLATEY, PROTO-SHALE -IE- WEAKLY FISSILE CUTTINGS; EARTHY LUSTER; VARIABLY SIL TV; OFTEN COLLOIDAL APPEARING; ADHESIVE; SCATTERED DARK GRA YIBLACK CARBONACEOUS FLECKS DOMINANTLY SMOOTH; PERSISTENT ANHEDRAL PYRITE; PHIlIIP5 W lookout #2 5600' MD SHALE = MEDIUM DARK GRAY TO BROWNISH GRAY; VARIABLE FISSILITY; GRADES TO AND INTERBEDDED WI CLAYSTONE; WEAKLY HYDRATED SOFT W/OCCASIONAL BRITTLE, BETTER INDURATED SECTIONS; CRUDELY PLANAR CUTTINGS; EASILY SCORED WI PROBE; DARK GRAYIBLACK CARBONACEOUS MATERIAL DISSEMINATED AND DEFINING BEDDING PLANES GENERALLY NON-CALCAREOUS; 5650' M D SILTSTONE = MEDIUM DARK GRAY WI LIGHT BROWN GRAY; SOFT-MODERATEHARD; CRUMBLY TENSION; MASSIVE -PLANAR CUTTINGS HABIT; IRREGULAR FRACTURE; DOMINANTLY SIL TV TEXTURE; EARTHY LUSTER; OCCASIONAL ASHY DEVITRIFIED GLASS SHARDS; BLACK CARBONACEOUS MATERIAL DISSEMINATED SPARSELY; CALCAREOUS MATRIX CALCITE PARTICLES TO mm DIAMETER ASSOCIATED. CALCITE POSSESSES DARK GOLD FLUORESCENCE. 5700' MD CLAYSTONE = DARK YELLOWISH BROWN TO PALE YELLOWISH BROWN; VERY SOFT TO SOFT; CRUMBLY TO MUSHY; IRREGULAR TO SUBBLOCKY FRACTURE; IRREGULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO OCCASIONAL SILTY TEXTURE; OCCASIONAL ASHY GLASS SHARDS; NO FLUORESCENCE. 5750' MD SANDSTONE = LIGHT GRAY TO MEDIUM LIGHT GRAY WI MEDIUM DARK GRAY TO DARK GRAY HUES; WEAKLY CONSOLIDATED; WEAK TO FAIR CALCITIC CEMENT; QUARTZ DOMINANT WI <100k MAFICS; LOWER VERY FINE GRAINS WI MODERATETO HIGH SPHERICITY; GRAIN SUPPORTED; WELL SORTED NO VISIBLE SURFACE ETCHINGS; NO FLUORESCENCE. 5800' MD SANDSTONE = LIGHT GRAY TO MEDIUM LIGHT GRAY WI MEDIUM DARK GRAY TO DARK GRAY HUES; FAIRLY CONSOLIDATED; FAIR TO MODERATELY CALCAREOUS CEMENT; QUARTZ DOMINANT WI <100/0 MAFICS; LOWER VERY FINE GRAINS WI MODERATE TO HIGH SPHERICITY; SUBANGULAR TO SUBROUNDED; GRAIN SUPPORTED; MODERATETO WELL SORTED; NO VISIBLE SURFACE ETCHINGS; NO FLUORESCENCE. 1. 5850' MD (:I Fl )()(' H 22 PHilliPS Alaska, Inc. PHilliPS W Lookout #2 CLAYSTONE = PALE BROWN TO BROWNISH GRAY WI GRAYISH BROWN HUES; VERY SOFT TO SOFT MUSHY TO OCCASIONAL CRUMBLY; DULL TO EARTHY LUSTER; CLAYEY TO OCCASIONAL SILTY TEXTURE; NO DISCERNABLE STRUCTURES OR FOSSILS; TRACE OF QUARTZ SAND GRAINS, LOWER FINE TO UPPER VERY FINE, SUBROUNDED TO ROUNDED, MODERATE TO HIGH SPHERICITY; EXTREMELY SPOTTY VERY PALE YELLOW FLUORESCENCE IN THE CLAYSTONE; REACTS WEAKLY TO MODERATELY WITH HCL. 5900' M D SILTSTONE = GRAYISH BROWN TO BROWNISH GRAY; FRIABLE TO MODERATELY FIRM; DULL TO EARTH LUSTER; CRUMBLY TO CRUNCHY TENACITY; GRITTY TO SILTY TEXTURE; OCCASIONAL BLACK CARBONACEOUS LENSES; REACTS MODERATELY WITH HCL; NO FLUORESCENCE. 5950' M D TUFFACEOUS CLAYSTONE = VERY LIGHT GRAY TO LIGHT GRAY; SOFT TO VERY SOFT; MUSHY; DULL TO EARTHY LUSTER, SHARD INCLUSIONS ARE VITREOUS; CLAYEY TO OCCASIONALLY CRUNCHY TEXTURE; NO DISCERNABLE STRUCTURES; REACTS VIGOROUSLY WITH HCL; NO FLUORESCENCE. ~ 6000' MD CLAYSTONE = LIGHT BROWNISH GRAY TO BROWN GRAY; SOFT TO VERY SOFT; MUSHY TO OCCASIONALLY CRUMBLY TENACITY; DULL TO EARTHY LUSTER; CLAYEY TEXTURE; CONTAINS BLACK LENSES & LAMINATIONS; WEAKLY FISSILE; OCCASIONAL GLASSY SHARD INCLUSTIONS; GRADES INTO TUFFACEOUS CLAYSTONE; NO FLUORESCENCE. 6050' MD CLAYSTONE = PALE BROWN TO PALE YELLOWISH BROWN WI LIGHT GRAY TO VERY LIGHT GRAY HUES; SOFT; MUSHY TO CLUMPY; CRUMBLY TENACITY; DULL TO EARTHY LUSTER; CLAYEY TO OCCASIONALLY SILTY TEXTURE; WEAKLY FISSILE; IRREGULAR TO BLOCKY FRACTURE; FRACTURES ALONG FISSILE PLANES; OCCASIONAL BLACK LAMINAE; NO FLUORESCENCE. 6100' MD TUFF = WHITE, VERY LIGHT GRAY, TO MODERATE REDDISH ORANGE; SOFT TO EASILY FRIABLE; IRREGULAR FRACTURE AND CUTTINGS HABIT; WAXY TO OCCASIONALLY RESINOUS LUSTER; SMOOTH TEXTURE; NO DISCERNABLE STRUCTURES; PALE TO MODERATE YELLOW FLUORESCENCE TYPICAL OF VOLCANICS 6150' MD [:I r P( )( " H 23 PHilliPS Alaska, Inc. Ø~IIIIPS m lookout #2 CLAYSTONE = PALE BROWN TO LIGHT BROWNISH GRAY; SOFT TO MUSHY; CRUMBLY; IRREGULAR FRACTURE; IRREGULAR CUTTINGS HABIT; EARTHY TO DULL LUSTER; CLAYEY TO SILTY TEXTURE; OCCASIONAL THIN BLACK LAMINATIONS; SPOTTY PALE YELLOW FLUORESCENCE DUE TO THE PRESENCE OF CALCITE. 6200' MD TUFFACEOUS CLAYSTONE = LIGHT-MEDIUM GRAY; SOFT; MATTE LUSTER; SMOOTH TO OCCASIONAL MODERATE GRAINY TEXTURE; GENERALLY NON-CALCAREOUS; SMALL! AMORPHOUS CUTTINGS W/ ROUNDED MARGINS; TENDS TO HYDRATE / SWELL QUICKLY; COMMON BLACK CARBONACEOUS FLECKS DISSEMINATED; UNIT COLOR-DISTINCT FROM CLAYSTONE; TYPICAL WEAK SPOTTY FLUORESCENCE; FINE CLAYSTONE BANDING. 6250' M D SANDSTONE = LIGHT GRAY; VERY FINE LOWER SIZED; SLIGHTLY VARIATION TO SULANGULAR; WELL SORTED; DOMINANTLY ANGULAR TO SUBANGULAR; MODERATE SPHERICITY; MATRIX-SUPPORTED BY CLAY/SILICA AND LESSER CALCITE CEMENT; MODERATE POROSITY/PERMEABILITY; THIN LAYERS WITHIN DARKER GRAY TO BLACK VERY THIN TURBIDITE BANDING; SALT AND PEPPER APPEARANCE; CHERT, MAFICS AND <30°/Ó VERY FINE GRAINED ARGILLITE PROVIDES DARKER LAMELLAE; WEAK ~ LIGHT YELLOW SAMPLE FLUORESCENCE; QUICK BRIGHT YELLOW GREEN CUT FLUORESCENCE CONCENTRATED IN CALCITIC ZONES; UNCONSOLIDATED QUARTZ GRAINS RANGE FROM mL TO mU; SUCROSIC DOMINANTLY SUBANGULAR TO ANGULAR; CLEAR, TRANSLUCENT TO LIGHT GRAY; MICACEOUS. 6300' MD SANDSTONE = LIGHT GRAY; VERY FINE LOWER SIZED; VARIATION TO VFL; WELL SORTED; DOMINANTLY ANGULAR TO SUBANGULAR; MODERATE SPHERICITY; MATRIX- SUPPORTED BY CLAY/SILICA AND LESSER CALCITE CEMENT; MODERATE POROSITY/PERMEABILITY; THIN LAYERS WITHIN DARKER GRAY TO BLACK VERY THIN TURBIDITE BANDING; SALT AND PEPPER APPEARANCE; CHERT, MAFICS AND <30% VERY FINE GRAINED ARGILLITE PROVIDE DARKER LAMELLAE; WEAK LIGHT YELLOW SAMPLE FLUORESCENCE; QUICK BRIGHT YELLOW GREEN CUT FLUORESCENCE CONCENTRATED IN CALCITIC ZONES. UNCONSOLIDATED QUARTZ GRAINS RANGE FROM mL TO mU; SUCROSIC DOMINANTLY SUBANGULAR TO ANGULAR; CLEAR! TRANSLUCENT TO LIGHT GRAY; MICACEOUS. 6400' MD SILTSTONE =MEDIUM GRAY TO BROWNISH GRAY; DOMINANTLY SOFT TO MODERATELY HARD AND, WHERE BETTER INDURATED, CRUMBLY; PLATEY TO " BLOCKY CUTTINGS; THINLY BANDED APPEARANCE- LAMINATED W/ DARK GRAY ~ [=I Fl)()(' H 24 PHilliPS Alaska, Inc. r~lIIlp'; W lookout #2 CARBONACEOUS MATERIAL; EASILY HYDRATED; SCATTERED QUARTZ GRAINS; DARK ORANGE YELLOW, SUBROUNDED, 2-3mm OXIDIZED VOLCANIC DETRITUS SCATTERED TO 5%; WEAK-MODERATELY CALCAREOUS; GRITTY W/ VARIABLE AMOUNTS OF COARSE QUARTZ GRAINS. 6500' MD SANDSTONE = LIGHT-MEDIUM GRAY; vfL TO vfU; POORLY CONSOLIDATED; CLAY MATRIX IS WEAK-MODERATELY REACTIVE W/ DILUTE HCI; ANGULAR-SUBANGULAR; WELL SORTED; VERY THIN BEDDED - DEFINED BY BLACK SILTY TO CRUSHED ARGILLACEOUS TURBIDITE BANDING; MODERATE OIL ODOR ON SHAKERS; SALT AND PEPPER APPEARANCE; FREE OIL NOTED IN SAMPLE @ 6530'; UNCONSOLIDATED SAND GRAINS ASSOCIATED; OCCASIONAL FELDSPARS, CaC03 PARTICLES AND LITHICNOLCANIC DETRITAL GRAINS VARIABLY; PALE GOLD CUT FLUORESCENCE- STREAMING CUT FROM 6520- 6540' - SPOTTY YELLOW FLUORESCENCE COMMON. 6600' M D SILTSTONE = MEDIUM/LIGHT GRAY TO MEDIUM DARK GRAY; OCCASIONAL BROWNISH HUES; CRUMBLY, EASILY CRUSHED; GRITTY; EARTHY LUSTER; COMMON MICROSPARKLES; VERY THINLY LAMINATED BEDDING; OCCASIONAL BLACK BROWN AND ORANGE OXIDIZED DETRITALS; WEAKLY CALCAREOUS; OCCASIONAL LIGHT ) YELLOW SAMPLE FLUORESCENCE AND SPOTTY FLUORESCENCE; COMMON QUARTZ GRAINS FROM DESTROYED SANDSTONE; CLAY MATRIX; BLOCKY TO OCCASIONALLY PLATEY CUTTINGS. 6650' M D CLAYSTONE = DUSKY YELLOWISH BROWN TO BROWNISH GRAY; SOFT TO MUSHY; CRUMBLY; IRREGULAR FRAC; IRREGULAR CUTTINGS HABIT W/ ROUNDED EDGES; EARTHY TO DULL LUSTER; CLAYEY TO SIL TV TEXTURE; OCCASIONAL THIN BLACK LAMINATIONS; SPOTTY PALE YELLOW FLUORESCENCE; EASILY HYDRATED; WEAK- MODERATELY ADHESIVE; SUB-PLATEY IN PART; 6700' MD SANDSTONE = LIGHT-MEDIUM GRAY; vfL TO vfU; WELL CONSOLIDATED; SILICA/CLAY MATRIX WEAKLY REACTIVE WI DILUTE HCI; ANGULAR-SUBANGULAR; WELL SORTED; VERY THIN BEDDED - DEFINED BY BLACK SILTY TO CRUSHED ARGILLACEOUS TURBIDITE BANDING; MODERATE OIL ODOR ON SHAKERS; SALT AND PEPPER APPEARANCE; WEAK SLOW BLUEIWHITE FLUORESCENCE. 6750' MD SANDSTONE = LIGHT-MEDIUM GRAY; vfL TO vfU; WELL CONSOLIDATED; SILICA/CLAY MATRIX WEAKLY REACTIVE W/ DILUTE HCI; ANGULAR-SUBANGULAR; WELL SORTED; ~ VERY THIN BEDDED - DEFINED BY BLACK SIL TV [=I FP()CH 25 PHilliPS Alaska, Inc. OHIIIIPS m lookout #2 TO CRUSHED ARGILLACEOUS TURBIDITE BANDING; MODERATE OIL ODOR ON SHAKERS; SAL T/PEPPER APPEARANCE; WEAK BLUEIWHITE SLOW CUT. 6800' MD SHALE = MEDIUM DARK GRAY TO BROWNISH GRAY; EASILY FRIABLE TO FRIABLE; IRREGULAR FRACTURE; IRREGULAR TO PLATEY CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TO OCCASIONALLY SIL TV TEXTURE; COMMON VERY PALE YELLOW FLUORESCENCE. 6850' MD SANDSTONE = QUARTZ DOMINANT, <5% MAFICS, VERY LIGHT GRAY TO LIGHT GRAY; LIGHT GRAY VERY FINE GRAIN TO UPPER VERY FINE GRAINED SLIGHTLY CALCIC CEMENT; CRUMBLY; MODERATELY CONSOLIDATED; SUBANGULAR TO SUB-ROUNDED; NO VISIBLE SURFACE ETCHINGS; WELL SORTED; MODERATE TO HIGH SPHERICITY; SLIGHTLY TO MODERATE VISIBLE OIL STAIN; COMMON PALE YELLOW FLUORESCENCE TO OCCASIONAL BRIGHT YELLOW FLUORESCENCE; VERY SLIGHT ODOR. 6850' MD SANDSTONE = QUARTZ DOMINANT, <5% MAFICS; VERY LIGHT GRAY TO LIGHT GRAY; ) LIGHT GRAY VERY FINE GRAIN TO UPPER VERY FINE GRAINED; SLIGHTLY CALCAREOUS CEMENT; CRUMBLY; MODERATELY CONSOLIDATED; SUBANGULAR TO SUB-ROUNDED; NO VISIBLE SURFACE ETCHINGS; WELL SORTED; MODERATETO HIGH SPHERICITY; SLIGHT TO MODERATE VISIBLE OIL STAIN; COMMON PALE YELLOW FLUORESCENCE TO OCCASIONAL BRIGHT YELLOW FLUORESCENCE; VERY SLIGHT OIL ODOR. 6900' MD SHALE = MEDIUM LIGHT GRAY TO LIGHT BROWNISH GRAY; EASILY FRIABLE TO FRIABLE; IRREGULAR TO BLOCKY FRACTURE; IRREGULAR TO BLOCKY CUTTINGS HABIT; SMOOTH TO CLAYEY TEXTURE; DULL TO EARTHY LUSTER; NO FLUORESCENCE; NO ODOR. 6950' M D SANDSTONE = VERY LIGHT GRAY TO LIGHT GRAY QUARTZ DOMINANT; GRAIN SUPPORTED; SLIGHTLY CALCITIC CEMENT; MODERATELY CONSOLIDATED; SLIGHTLY CLAYEY MATRIX; LOWER VERY FINE TO UPPER VERY FINE GRAINED; SUBROUNDED TO ROUNDED; WELL SORTED; NO VISIBLE SURFACE ETCHINGS; MODERATE TO HIGH SPHERICITY; COMMON VERY PALE YELLOW FLUORESCENCE; SLIGHT OIL STAIN; NO ODOR; GRADES TO SILTSTONE. ," 7000' M D [=I E 1)( )( , H 26 PHilliPS Alaska, Inc. ) SAND = CLEAR, TRANSLUCENT, TO WHITE; UNCONSOLIDATED QUARTZ GRAINS; LOWER FINE TO UPPER MEDIUM GRAIN SIZE; SUBANGULAR TO SUBROUNDED, OCCASIONAL ROUND; COARSER GRAINS TEND TO BE SUBANGULAR WITH LOW TO MODERATE SPHERICITY; FINER GRAINS TEND TO BE SUB-ROUNDED TO ROUND WITH MODERATE TO HIGH SPHERICITY; NO VISIBLE SURFACE ETCHINGS; TRACE AMOUNTS OF MODERATE REDDISH ORANGE TO ORANGE DEVITRIFIED VOLCANIC SHARDS. P~IIIIPS W lookout #2 7050' MD SHALE = DARK YELLLOWISH BROWN TO BROWNISH; GRAY; SOFT TO EASILY FRIABLE; WEAKLY FISSILE; IRREGULAR TO BLOCKY FRACTURE, OCCASIONALLY PLANAR ALONG FISSILE PLANES; PLATEY TO BLOCKY CUTTINGS HABIT; GRADES TO CLAYSTONE; FREQUENT BLACK/CARBONACEOUS LAMINAE; NO ODOR; NO FLUORESCENCE. 7100' MD TUFFACEOUS CLAYSTONE = LIGHT GRAY TO MEDIUM LIGHT GRAY; SOFT TO VERY SOFT; CRUMBLY; IRREGULAR CUTTINGS HABIT; IRREGULAR FRACTURE; CLAYEY TO SILTY, OCCASIONAL GRITTY TEXTURE; DULL TO EARTHY LUSTER, OCCASIONALLY RESINOUS APPEARANCE. 7150' MD SHALE = DARK YELLLOWISH BROWN TO BROWNISH; GRAY; FRIABLE TO EASILY FRIABLE; WEAK TO MODERATELY FISSILE; IRREGULAR TO BLOCKY FRACTURE, OCCASIONAL PLANAR ALONG FISSILE PLANES; PLATEY TO BLOCKY CUTTINGS HABIT; FREQUENT BLACK/CARBONACEOUS LAMINAE NO ODOR; NO FLUORESCENCE. 7200' MD TUFFACEOUS CLAYSTONE = WHITE, VERY PALE ORANGE TO VERY PALE YELLOWISH BROWN; VERY SOFT TO SOFT; IRREGULAR FRACTURE; IRREGULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER, OCCASIONAL WAXY; SMOOTH TO CLAYEY TEXTURE;OCCASIONAL FINE BLACK/CARBONACEOUS LAMINAE; NO ODOR. 7250' M D SHALE = DUSKY BROWN, BROWNISH GRAY TO BROWNISH BLACK; FRIABLE TO MODERATELY FIRM; IRREGULAR, PLATEY TO WEDGELIKE CUTTINGS HABIT; IRREGULAR, BLOCKY TO PLATEY FRACTURE; DULL TO EARTHY LUSTER; SMOOTH TEXTURE; POOR TO MODERATELY FISSILE; NO VISIBLE STRUCTURE; NO ODOR; NO FLUORESCENCE. 7300' MD [:1 EP( )(" H 27 PHilliPS Alaska, Inc. ~ W Lookout #2 TUFFACEOUS CLAYSTONE = WHITE, VERY PALE ORANGE TO VERY PALE YELLOWISH BROWN; VERY SOFT TO SOFT; IRREGULAR FRACTURE; IRREGULAR CUTTINGS HABIT; DULL TO EARTHY LUSTER, OCCASIONAL WAXY; SMOOTH TO CLAYEY TEXTURE; OCCASIONAL FINE BLACK/CARBONACEOUS LAMINAE; NO ODOR. 7350' MD CLAYSTONE = VERY PALE YELLOWISH BROWN TO GRAYISH ORANGE; SOFT TO OCCASIONALLY FIRM; CRUMBLY TO OCCASIONAL BRITTLE; IRREGULAR FRACTURE; IRREGULAR TO BLOCKY CUTTINGS HABIT; DULL TO EARTHY, OCCASIONAL WAXY LUSTER; SMOOTH TO CLAYEY TEXTURE; NO DISCERNABLE STRUCTURES; NO ODOR; NO FLUORESCENCE. 7400' MD SHALE = DOMINANTLY BROWNISH BLACK W/10% BROWNISH GRAY @ 7380',40% @ 7410' COLOR CHANGE; THIN, LAMELLAR BEDDING DEFINED BY ALTERNATING BROWNISH GRAY AND DARK YELLOWISH BROWN LAYERS; DARK YELLOWISH BROWN LAYERS ARE MUCH HARDER WHILE BROWNISH GRAY IS CLAYEY TO GRITTY EXHIBITING WEAK-MODERATE REACTION W/ DILUTE HCI; BREAKS POORLY ALONG BEDDING PLANES; SUBVITREOUS ) LUSTER; PERSISTENT mm SIZED CALCITE PARTICLES AND ANHEDRAL PYRITE ACCRETIONS; TR CPY; RARE SUBROUNDED QUARTZ GRAINS ON mm SCALE. 7450' MD CLAYSTONE = DUSKY YELLOWISH BROWN TO DUSKY BROWN; SOFT TO OCCASIONALLY FIRM; CRUMBLY TO OCCASIONALLY BRITTLE; IRREGULAR FRACTURE; IRREGULAR TO BLOCKY CUTTINGS HABIT; DULL TO EARTHY LUSTER; DOMINANTLY SMOOTH TO CLAYEY TEXTURE; NO DISCERNABLE STRUCTURES; NO ODOR; NO FLUORESCENCE. 7500' MD SILTSTONE = MEDIUM/LIGHT GRAY TO MEDIUM DARK GRAY; OCCASIONAL GRAINSH HUES; CRUMBLY, EASILY CRUSHED; GRITTY; EARTHY LUSTER; COMMON MICROSPARKLES; WEAKLY CALCAREOUS; NO APPARENT OIL ASSOCIATIONS; OCCASIONAL SANDSTONE SIZED QUARTZ GRAINS; DOMINANTLY PLATEY W/ OCCASIONAL BLOCKY CUTTINGS; RARE MEDIUM/LIGHT GREEN VOLCANIC CHIPS FLUORESCE; NOTE - SHALE COLOR CHANGE @ 7560' 7550' MD SHALE = DOMINANTLY BROWNISH BLACK TO GRAYISH BLACK W/ REDDISH HUES; INCREASINGLY MASSIVE BEDDING OCCASIONAL LAMELLAR DEFINED BY , ALTERNATING GRAYISH BLACK AND BROWNISH BLACK LAYERS; INCREASINGLY WELL ~ INDURATED; CRUNCHY; BREAKS POORLY ALONG BEDDING PLANES; SUBVITREOUS ~ FP()(~H 28 PHilliPS Alaska, Inc. PNIIIIPS m lookout #2 LUSTER; MICACEOUS (METAMORPHIC?) SHEEN; PERSISTENT mm SIZED CALCITE PARTICLES AND ANHEDRAL PYRITE ACCRETIONS; TRACE CHALCOPYRITE; COMMON MICROSPARKLES DISSEMINATED; WEAKY REACTIVE W/ DILUTE HCI; SOME CLAYSTONE IS THE PRODUCT OF PDC BIT ACTION; 20°/Ó DUSKY BROWN TO DUSKY YELLOWISH BROWN SHALE IN TRANSITION ZONE 7530-60. RARE SUBROUNDED QUARTZ GRAINS ON mm SCALE. 7600' MD CLAYSTONE = DUSKY YELLOWISH BROWN TO DUSKY BROWN; SOFT TO OCCASIONALLY FIRM; CRUMBLY TO OCCASIONALLY BRITTLE; IRREGULAR FRACTURE; IRREGULAR TO BLOCKY CUTTINGS HABIT; DULL TO EARTHY LUSTER; DOMINANTLY SMOOTH TO CLAYEY TEXTURE; NO DISCERNABLE STRUCTURES; NO ODOR; NO FLUORESCENCE; SOME CLAYSTONE PROBABLY DUE TO PDC BIT ACTION. 7650' MD TUFFACEOUS CLAYSTONE = DOMINANTLY BROWNISH GRAY TO BROWNISH GRAY; MOTTLED APPEARANCE; SLIGHTLY DARKER, ANGULAR TUFF CLAYSTONE BRECCIA CLASTS SUPPORTED BY LIGHTER COLORED CLAY-RICH MATRIX; SOFT, GELLATINOUS IN PART; MODERATELY CALCAREOUS; ~ POORLY INDURATED; ANGULAR SHARP EDGED CUTTINGS; EASILY HYDRATED. 7700' MD SHALE = DOMINANTLY BROWNISH BLACK TO GRAYISH BLACK W/ REDDISH HUES; INCREASINGLY MASSIVE BEDDING OCCASIONALLY LAMELLAR: DEFINED BY ALTERNATING GRAYISH BLACK AND BROWNISH BLACK LAYERS; INCREASINGLY WELL INDURATED; CRUNCHY; BREAKS POORLY ALONG BEDDING PLANES; SUBVITREOUS LUSTER; MICACEOUS (METAMORPHIC?) SHEEN; PERSISTENT mm SIZED CALCITE PARTICLES & RARE ANHEDRAL PYRITE ACCRETIONS; TRACE CHALCOPYRITE; COMMON MICROSPARKLES DISSEMINATED; WEAKY REACTIVE W/ DILUTE HCI; RARE ROUNDED DETRITAL QUARTZ GRAINS DISSEMINATED SPARSELY; CALCITE PARTICLES HAVE LIMONITIC/HEMATIZED COATINGS. 7835' MD SANDSTONE = DOMINANTLY TRANSPARENT, LIGHT BROWN; OCCASIONALLY OIL STAINED; SCATTERED CLAYSTONE CHIPS; WELL SORTED DOMINANTLY vfL W/ LESSER VFu SIZED GRAINS; PERVASIVE LIGHT YELLOW/GOLD FLUORESCENCE; INSTANT MILKY CUT FLUORESCENCE; BLUEIWHITE STREAMERS; GOOD SHOW; OIL ODOR FROM 7868' WI OIL ON SHAKER TABLE. GOOD POROSITY/PERMEABILITY; GRADES TO COARSER GRAINS DEEPER! fL TO vfU, OCCASIONAL fU; GLAUCONITE IS PRESENT. 7900' M D [=I FP()( 'H 29 PHilliPS Alaska, Inc. PHilliPS m Lookout #2 SANDSTONE = PALE TO MODERATE YELLOWISH BROWN; QUARTZ DOMINANT; vfL TO fU; POOR TO MODERATELY CONSOLIDATED; POOR TO MODERATE SORTING; SUBANGULAR TO SUBROUNDED; MODERATE TO HIGH SPHERICITY; PARTIAL CLAY MATRIX; GRAIN SUPPORTED; GLAUCONITIC; PERVASIVE PALE YELLOW FLUORESCENCE. TRACES CHALCOPYRITE/PYRITE DISSEMINATION; OCCASIONALLY COARSER, SUBROUNDED QUARTZ DETRITALS; 7950' MD SHAlEY SILTSTONE = BROWNISH BLACK TO DARK GRAY; WELL INDURATED; OCCASIONALLY SANDY; MODERATELY SOFT TO CRUNCHY; PLANAR BEDDING/CUTTiNGS; GRITTY; MICROSPARKLES ARE COPIOUS; PYRITE REPLACEMENT NOTED ALONG BEDDING PLANES; BEDDING DEFINED BY SLIGHTLY COARSER GRADE QUARTZ; SPOTTY LIGHT YELLOW FLUORESCENCE CUT; 1-2% mU SIZED, SUBROUNDED CLEAR-TRANSLUCENT QUARTZ GRAINS; EARTHY LUSTER; MATTE TEXT BROKEN BY MICACEOUS DISSEMINATIONS. 8000' M D SHALE = DOMINANTLY DARK GRAY TO GRAYISH BLACK; MODERATELY HARD; SCORES EASILY W/PROBE; WAXY APPEARANCE; BLOCKY TO PLANAR CUTTINGS; COMMON DISSEMINATED MICAS; NO APPARENT OIL INDICATORS; PERSISTENT THIN HORIZONS ) OR vfL SIZED SANDSTONE SELDOM REACHING 100k OF SAMPLE; OCCASIONALLY GLAUCONITE INTERSTITIALLY; SUBROUNDED mL QUARTZ GRAINS COMMON; PYRITE/CHALCOPYRITE TO 1 % LOCALLY; 8060' MD SHALEY SILTSTONE = BROWNISH BLACK TO DARK GRAY; WELL INDURATED; OCCASIONALLY SANDY; MODERATELY SOFT TO CRUNCHY; PLANAR BEDDING/CUTTINGS; GRITTY; MICROSPARKLES THROUGHOUT; PYRITE REPLACEMENT NOTED ALONG BEDDING PLANES; BEDDING DEFINED BY SLIGHTLY COARSER GRADE QUARTZ; WEAK YELLOWISH GREEN CUT FLUORESCENCE; 1-2% mU SIZED, SUBROUNDED CLEAR-TRANSLUCENT QUARTZ GRAINS; EARTHY LUSTER; MATTE TEXTURE BROKEN BY MICACEOUS DISSEMINATIONS. 8110' MD TUFF = WHITE, VERY PALE ORANGE, PALE ORANGE, OCCASIONALLY REDDISH ORANGE; SOFT TO EASILY FRIABLE; IRREGULAR TO BLOCKY FRACTURE; IRREGULAR CUTTINGS HABIT; WAXY TO OCCASIONALLY RESINOUS LUSTER; SMOOTH TEXTURE; NO DISCERNABLE STRUCTURES. 8145' MD , SILTSTONE = BROWNISH GRAY; FRIABLE TO SLIGHTLY CRUNCHY; GENERALLY ; UNIFORM GRITTY TEXTURE; MARKED MICRO-BEDDING DEFINED BY MINOR [=I FP()(". H 30 PHilliPS Alaska, Inc. ~ COLOR VARIATIONS, GRITTY TO SATINY LUSTER; FINE SILT OR CLAY CEMENT; ABUNDANT FINE PYRITEON BEDDING PLANES; GRAIN SIZE RANGES TO ULTRA-FINE SAND, WELL SORTED QUARTZ, SHARPLY ANGULAR AND SPHERICAL; LOW POROCITY; NO OIL INDICATORS NOTED. PHilliPS m lookout #2 [=I FP()CH 31 PHilliPS Alaska, Inc. PKIlUPS m lookout #2 RIG ACTIVITIES 3/02/02 Run abbreviated BHA. Spud and drill 12.25" hole from 115-500'. Circulate. Run into hole wI BHA. Drill ahead 3/03/02 Drill ahead. Short trip to shoe. Run in and continue drilling ahead. 3/04/02 Drill Ahead. Wipe hole @ 1309' & 2365'. 3/05/02 Drill ahead. Circulate Bottoms up. Wipe hole and POOH 3/06/02 Circulate I condition mud. Run 9-518" casing to 3097'. Test, nipple up. Run BOP tests. RIH with new BHA. Drill 20' and pressure test. 3/07/02 ) Drill ahead. Circulate regular sweeps 3/08/02 Drill ahead. Wiper trip to shoe @ 5249'. Work tight spots. RIH. Drill ahead. 3/09/02 Drill ahead. Short trip to 5140' @ 6400'. RIH. Drill ahead. 3/10/02 Drill ahead. Wiper trip. Pull out of hole - MWD tool failure. 3/11/02 Replace MWD tool. Add mud motor to new BHA. Run into hole, drill ahead. 3/12/02 Drill ahead. TD @ 7893'. Wiper trip. Come out of hole preparatory to cementing, run casing. 3/13/02 POOH. Download MWD tools. Rig up and run casing. 3/14/02 r Run 7" casing. Hit bridge @7838'. P/U cement head. Test BOPs. [:I E 1){ )(" H 32 PHilliPS Alaska, Inc. , 3/15/02 RIH. Test MWD. Well flowing Shut in (Sbbl gain). Weight mud up to 9.8. Monitor well, stable, ROH to 6845', monitor weil, pump dry job. POOH make up BHA and core assembly! PlllIlIP'5 m lookout #2 3/16/02 RIH and circulate bottoms up Core from 7894' to 7928'. Circulate and POOH due to poor ROP. RIH with new core bit. 3/17/02 Circulate bottoms up and core from 7928' to 7931 . Pump dry job. Circulate and POOH due to poor ROP. RIH with new BHA and PDC bit Mad pass. Drill ahead. 3/18/02 Drill ahead. TO @8200'. Wiper trip. POOH. Run wire line logs. 3/19/02 Continue wire line logging (1 FP()(-'H 33 PHilliPS Alaska, Inc. ~ ~ Lookout #2 MUD RECORD œ Phillips 2L-03 DAILY MUD REPORTS FIL TRA T DATE DEPTH WEIGHT VIS PV YP GELS E CAKE SOLIDS SAND pH Pm Pf/Mf CI Ca 312102 300 10.00 100 25 35 13/15/17 5,0 1.0/0.0 9.8 0 8.90 0.40 0.30/1.10 29000 160 3/3/02 1900 10.00 60 19 34 10/12/16 3.8 1.0/0,0 10,3 1.75 8.50 0,25 0.15/0.80 29000 160 3/4/02 3105 10.00 45 14 22 8/10/12 4.0 1.0/0.0 9.8 2.00 8.90 0.40 0.30/1.00 29000 80 3/5/02 3105 10.00 42 12 16 5/7/8 5,0 2.0/0,0 80 3.00 9.00 0,30 0.15/0.80 26000 320 3/6/02 3043 10.00 49 14 20 5/7/8 5.0 2.0/0.0 8.0 2.00 11.50 0,60 0.40/0,80 26000 320 3/7/02 4450 9.60 48 15 17 4/6/8 4.0 2.0/0.0 4,6 0.50 8.70 0.35 0.35/1,10 30000 200 3/8/02 5450 9.65 46 17 19 3/8/1 2 3.8 2.0/0,0 4.5 0.75 9.40 0.50 0.50/1.60 32000 160 3/9/02 6400 10.20 49 20 24 4/7/11 3.2 2.0/4,0 6.6 0.50 9.00 0.40 0.40/1.50 31000 140 3/10/02 6525 11.30 57 25 25 4/10/15 28 2.0/4,0 10.8 0.50 9.50 0.65 0.40/1,60 30000 120 3/11/02 7759 11.30 55 30 25 3/9/15 2.2 2,0/4,0 10.6 0.50 9.40 0,60 0.40/1.80 32000 120 3/12/02 7893 11.30 56 30 25 3/9/15 2,2 2.0/4.0 10.6 0,50 9.40 0.60 0.40/2.00 32000 120 3/13/02 7893 9,90 51 16 14 2/3/5 2.8 2,0/4,0 5.6 0.25 9,40 0.60 0.40/2.00 31000 120 3/14/02 7893 9.20 56 20 14 3/4/5 2.2 2.0/4,0 5,7 0.00 8.00 0.00 0.05/0,70 15000 240 3/15/02 7893 9.80 63 22 15 3/4/6 2.5 2,0/4.0 9.7 0.00 10.90 2.50 0.30/0.80 17000 200 3/16/02 7928 9.95 92 28 22 6/8/10 22 2.0/4.0 10.9 0.00 11.40 1.80 0.20/0.80 16000 160 3/17/02 7973 9.80 72 25 19 4/8/1 0 2.1 2,0/4.0 10,2 0,00 11.30 1.90 0.40/1.40 16000 120 3/18/02 8200 9.80 73 25 18 5/8/1 0 2.0 2.0/4.0 10.0 0.00 10.40 1.00 0.70/1.40 14000 40 [=I EP()(~H 34 PHilliPS Alaska, Inc. ~ ~ lookout #2 LOOKOUT2 MUD PARAMETERS i~wEI~~.VIS [JpH D~ 450 -. - -, -. . ~ 'r.~ - - .- .- --. -"" --- -.... --- ..."- ---- ~-------- _._--. -"".-" - - - -_."-"._" -.- "r--"- '--.- - -....., - -=- '''---".- -".--- -.... --_or ""--'-. -."--- ~-_.- -r'--='_..'r-~_--_-. - .,"- --... .-_........,.-~- ..."'-".-- "' - -Or -.. ~- '--"'.'--- -- --".'" 400 - 350 - 300 - U'J n: ~ 250 - w :: ~ 200- c:r: Q. 150 . 50 100 0 300 1900 3105 3105 3043 4450 5450 6400 6525 DEPTH 7759 7893 7893 7893 7893 7928 797: [:I EP()(~H 35 PHilliPS Alaska, Inc. ~ ~ lookout #2 SURVEY RECORD Depth feet 0 Inclination degrees 0 Azimuth degrees 0 Vertical Depth feet 0 N/S Departure feet 0 EfW Departure feet 0 Vertical Section feet 0 DogLeg Severity degrees/100 feet TIE-IN 402.24 0.44 230.21 402.24 -0,71 -0.86 -0,71 0.15 492.97 0.57 236.06 492.96 -1,18 -1.49 -1.18 0.15 584.81 0.57 253.34 584.80 -1.57 -2.31 -1.57 0.19 678.16 0.57 249.96 678.14 -1.86 -3,19 -1.86 0.04 771.30 0.64 244.57 771 .28 -2.25 -4.10 -2.25 0.10 863.94 0.88 255.42 863.91 -2.65 -5.26 -2.65 0.30 956.31 1.10 258.70 956.27 -3.00 -6.82 -3.00 0.25 1052.37 1.12 260.85 1052.31 -3.33 -8.65 -3.33 0.05 1148.86 1.13 274.85 1148,78 -3.40 -1 0.54 -3.40 0.28 1243.30 1.20 279.15 1243,20 -3.17 -12.44 -3,17 0.12 1339.16 1.22 271.87 1339,04 -2.97 -14.45 -2.97 0,16 1436.22 0.70 275.08 1436,09 -2.89 -16.08 -2.89 0.54 1532.42 0.39 288.4 7 1532.28 -2.73 -16.97 -2.73 0.35 1625.48 0.47 284.56 1625,34 -2.54 -17.63 -2.54 0.09 1725.07 0.47 286.46 1724,93 -2.32 -18,41 -2.32 0.02 1820.80 0.46 286.21 1820.65 -2.10 -19.16 -2.10 0.01 1916.32 0.36 296.94 1916,17 -1.86 -19.79 -1.86 0.13 2012.70 0.48 302.87 2012.55 -1.51 -20.39 -1.51 0.14 2108.21 0.51 300.89 2108,05 -1.07 -21.09 -1.07 0.04 2204.45 0.46 305.72 2204,29 -0.63 -21.78 -0.63 0.07 2298.23 0.43 301.85 2298,07 -0.22 -22.38 -0.22 0.04 2395.45 0.31 295.73 2395.29 0,09 -22.93 0,09 0.13 2492.30 0.33 297.08 2492,13 0.33 -23.41 0.33 0.02 2587.32 0.25 293.77 2587.15 0.54 -23.85 0.54 0.08 2682.78 0.15 329.22 2682.61 0.73 -24.11 0.73 0.17 [=I EP()C'H 36 PHilliPS Alaska, Inc. {I m lookout #2 Depth Inclination Azimuth Vertical Depth N/S Departure EIW Departure Vertical Section DogLeg Severity feet degrees degrees feet feet feet feet degrees/100 feet 2778.73 0.23 270.6 2778.56 0.84 -24.36 0.84 0.20 2874.30 0.23 264.45 2874.13 0.82 -24.74 0,82 0.03 2970.75 0.19 286.91 2970.58 085 -25.08 0.85 0.09 3040.89 0.14 255.27 3040.72 0,86 -25.28 0,86 0.15 3197.84 0.21 234.71 3197.67 0.65 -25.70 0.65 0.06 3294.66 0.38 231.13 3294.49 0,35 -26.09 0.35 0.18 3391 .15 0.37 234.27 3390.98 -0.03 -26.59 -0,03 0.02 3487.55 0.31 220.24 3487.37 -0,42 -27.01 -0.42 0.11 3584.16 0.27 238.64 3583.98 -0.73 -27.38 -0.73 0.11 3678.34 0.28 212.15 3678.16 -1,04 -27.69 -1.04 0.13 3775.45 0.22 217,54 3775.27 -1.40 -27.93 -1,40 0.07 3871.86 0.26 217.55 3871.68 -1.72 -28.18 01.72 0.04 3967,98 0.22 217.33 3967.80 -2,04 -28.42 -2.04 0.04 4063,64 0.21 225.85 4063.46 -2.30 -28.66 -2.30 0.03 4157.78 0.17 249.29 4157.60 -2,47 -28.91 -2.47 0.09 4254.58 0.18 255.63 4254.40 -2.56 -29,20 -2.56 0.02 4349.74 0.21 232.80 4349.56 -2.71 -29.49 -2,71 0.09 4445,25 0.18 236.70 4445.07 -2.90 -29.76 -2.90 0.04 4540,21 0.19 228.99 4540.03 -3,08 -30.00 -3,08 0.03 4637.51 0.33 240.32 4637.32 -3.33 -30.36 -3.33 0.16 4732.58 0.45 223,87 4732,39 -3.73 -30.86 -3,73 0.17 4827.96 0.70 252,08 4827.77 -4,18 -31.68 -4,18 0.39 4925.23 1.02 265.90 4925.03 -4.43 -33.11 -4,43 0.39 5021.18 1.29 264.04 5020,96 -4,60 -35.04 -4,60 0.28 5116.85 1.19 257.31 5116,61 -4,93 -37.08 -4.93 0.18 5213.60 1,11 252,11 5213.34 -544 -38.95 -5.44 0.14 5308.46 1.03 255.34 5308.18 -5,94 -40.66 -5.94 0.11 5404.73 1.00 252.30 5404.43 -6.42 -42.30 -6,42 0.07 5500.90 0.85 250.32 5500,59 -6,91 -43.77 -6.91 0,15 5597.55 0.82 246.96 5597,23 -7.43 -45.09 -7.43 0.06 5692.09 0.85 239.86 5691 .76 -805 -46.32 -8.05 0.12 5789.29 0.96 233.60 5788.95 -8,89 -47.60 -8.89 0.15 [~ EP()C:H 37 PHilliPS Alaska, Inc. œ m Lookout #2 Depth Inclination Azimuth Vertical Depth N/S Departure EfW Departure Vertical Section DogLeg Severity feet degrees degrees feet feet feet feet degrees/100 feet 5886.16 0.92 244.49 5885.81 -9.71 -48.95 -9.71 0.19 5981.05 0.91 247.21 5980.68 -10,33 -50.33 -10.33 0.05 6077.23 1.01 237.65 6076.85 -11 .08 -51.75 -11,08 0.20 6173.36 0.99 227.44 6172.97 -12,09 -53.08 -12.09 0.19 6270.24 0.95 237.17 6269.83 -13,10 -54.38 -13.10 0.18 6365.60 0.86 233.96 6365,18 -13,95 -55.62 -13.95 0.11 6552.35 0.95 228.98 6551.91 -1 5,79 -57.92 -15,79 0.07 6648.08 0.37 237.93 6647,63 -16,47 -58.78 -16.47 0.62 6743.75 0.52 230.84 6743.30 -16,91 -59.38 -16,91 0.17 6839.03 0.92 205.71 6838,57 -17,87 -60.05 -17.87 0.52 6937.20 1.11 199.77 6936.72 -19,48 -60.71 -19.48 0,22 7032.61 0.79 169.65 7032.12 -20,99 -60,90 -20,99 0.61 7128.50 0.19 164,98 7128.01 -21,80 -60,74 E21.80 0.63 7224.02 0.34 129.66 7223.53 -22,13 -60.48 -22.13 0.23 7319.92 0.38 117.80 7319.42 -22.46 -59,98 -22.46 0.08 7416.89 0.33 114.89 7416.40 -2271 -59.26 -22.71 0.05 7511.98 0.35 109.72 7511.48 -22,92 - 58,74 -22.92 0.04 7607.72 0.49 109.68 7607.22 -23.16 -58,08 -23.16 0.15 7705.02 0.54 116.36 7704.52 -23.50 -57.28 -23.50 0.08 7800.90 0.31 131,37 7800.39 -23,87 -56,68 -23.87 0.27 7834.21 0.51 111.45 7833.70 -23.98 -5648 -23.98 0.74 7961.24 0.30 150.18 7960.73 -24,48 -55,78 -24.48 0.26 8056.98 0.42 180.31 8056.47 -2505 -55.66 -25.05 0.23 8152.47 0,57 202.89 8151.96 -25,84 -55.84 -25.84 0.25 8164.1 0 0.53 202.95 8163,58 -25,94 -55.88 -25.94 0.28 8200.00 0.53 202.95 8199.48 -26,25 - 56.01 -26.25 0.01 [=I EP()(~H 38 PHilliPS Alaska, Inc. W m lookout #2 BIT RECORD [~ EPOCH BIT GRADING -0 C - DJ 0 :E Zc: z.... C:o ~G) 5! ::t '"~ r- (") :þ m -< :a:;v r-:þ:;v ::a ." :a:;v (") -I - c:: (') c:: =>0 ::E: - Z Ii) ï »0 1i)'n ::E: r- ~~ :::a Z en :þ m :::a c JETS TOTAL AVG BIT SERIAL SIZE (in 32nds) DEPTH DEPTH FEET BIT AVG AVG AVG PUMP NUMBER NUMBER INCHES MAKE TYPE 1 2 3 4 IN OUT DRILLED HOURS FT/HR WOB RPM PSI 1 5002280 12.25 HTC MXC1 110 3105 2995 25.95 120.38 9,25 108 1297 2 4 ER A E I PN TD 2 200975 8.5 HYCA DS70 3105 6488 3383 53.78 79.36 5.80 165 2092 0 0 NO A X I NO DTF 2R1 20198 8.5 HYCA DS70 6488 7893 1405 23.43 70.26 4.84 99 3283 1 1 CT A X I BT TD 3 CD328 6.125 RBI SS21 RPSP 7893 7893 0 0 0 0 0 0 3 3 ER A X I PN Core #1/2 7100433 6.125 HTC AXC 425 7893 7931 38 6 6,33 7.25 76 1360 4 0325087 6.125 HTC STX 604 7931 8200 269 9.6 42.50 6.28 111 2185 TD [1 EP()(~H 39 PHilliPS Alaska, Inc. ~ ~ lookout #2 DAYS VS. DEPTH Depth 7 8 9 1 0 11 1 2 1 3 1 4 1 5 1 6 1 ï 1 8 1 9 20 -- - --- ---- 7893 [=I EP()( ~H 21 --...L-------L-- 7" Casing ----=1 -I -- 1 -- I ---I 7~ 82QQ. I - --I I -] -- --------- I _I ------ ~ '" 22 ! -+- Depth I 40 Dai 1 y Report PHILLIPS ALASKA Ray Skinner Lookout #2 REPORT FOR DATE Mar 03.2002 TIM E 06:00:00 Page I of 1 DAILY WELLSITE REPORT [~ EPOC,l-I DEPTH 500 YESTERDAY 0 PRESENT OPERATION= DRILL AHEAD 24 Hour Footage 500 SURVEY DATA CASING INFORMATION 15.25u @ 100' DEPTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE 1 12.25 MXC1 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW FC VIS SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBONSHO~ INTERVAL INCLINATION AZIMUTH SIN 5002280 JETS 1.14/3./22 INTERVAL IN OUT 500 HOURS 0 CONDITION T IBIC REASON PULLED FOOTAGE 0 HIGH LOW AVERAGE CURRENT AVG 206.1 @ 132 19.4 @ 217 86.3 112.0 1982 @ 492 347 @ 131 969.3 1361.8 17 @ 458 0 @ 314 7.1 12.5 74 @ 408 27 @ 131 519 74 523 @ 476 216 @ 101 320.7 454 DEPTH. UNAVAILABLE P\I YP FL Gels CL- SD OIL MBl pH Ca+ ftIhr amps KJbs RPM psi CCI HIGH LOW AVERAGE 1 0 @ 334 0 @ 207 @ 00@500 CHROMATOGRAPHY(ppm) 334 1 @ 207 6.3 500 0 @ 500 0.0 500 0 @ 500 0.0 500 0 @ 500 0.0 500 0 @ 500 0 0 NIL LlTHOLOGY/REMARKS DESCRIPTION 04 0 TRIP GAS= 0 WIPER GAS= 0 SURVEY= 0 19 @ 0 @ 0 @ 0 @ 0 @ CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 1u GAS LITHOLOGY PRESENT LITHOLOGY Claystone 90%. Conglomerate Sand 10% DAILY ACTIVITY SUMMARY Run abbreviated BHA - Spudldril/12.25Þ suñaœ hole from 115-500'. Circ - rih wI BHA, drill ahead Epoch Personal On Board= John Morris I Bob Nichol Daily Cost 2540 Report by: Bob Nichol fi le:/ /D :\Morni ne%20Reoorts\20020303 . htm 4/?f../700'> Oai I y Report PHILLIPS ALASKA North Slope Lookout #2 REPORT FOR Ray Skinner DATE Mar 04. 2002 TIME 06:00:00 DAILY WELLSITE REPORT DE PTH 2365 YESTERDAY 501 24 Hour Footage 1864 CASING INFORMATION 15.25" @ 100' DEPTH 1339.16 1625.48 1820.80 2012.70 2298.23 SURVEY DATA BIT INFORMATION NO. SIZE TYPE 1 12.25 MXC1 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10 FC VIS SOL MWD SUMMARY iNTERVAL TO TOOLS GAS SUMMARY(units) DITC H GAS CUTTING GAS METHANE(C~1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBONSHO~ INTERVAL SIN 5002280 JETS 3x20.1x14 INCLINATION 1.22 0.47 0.46 0.48 0.43 INTERVAL IN OUT 500 FOOTAGE 1865.4 HIGH LOW 303.2 @ 978 8.5 @ 501 2544 @ 2294 298 @ 1311 22 @ 1556 0 @ 2182 129 @ 1141 26 @ 1311 1747 @ 2294 560 @ 501 DEPTH: 1900 60 PV 19 YP 34 FL Gels 10.3 SO 1.75 OIL MBL pH HIGH LOW AVERAGE 10.2 0 40 @ 2213 0 @ 813 0 @ 0 0 @ 0 9604 0 0 0 0 CH ROMATOGRAPHY(ppm) @ 2213 1 @ 813 @ 2365 0 @ 2365 @ 2365 0 @ 2365 @ 2365 0 @ 2365 @ 2365 0 @ 2365 2077.8 0.0 0.0 0.0 0.0 NO SIGNIFICANT SHOWS LlTHOLOGY/R EMAR KS LITHOLOGY PRESENT liTHOLOGY Claystone 70%, Siltstone 20%, Tuffaceous Claystone 10% DAilY ACTIVITY SUMMARY Drill ahead -wipe hole @ 1309' & 2365' Epoch Personal On Board= 4 Daily Cost 2660 Report by: Bob Nichol fi Ie:! /D: \Morning%20Reports\20020304 .htm Page 1 of 1 [~ EPOCH PRESENT OPERATION= WIPE HOLE AZIMUTH 271.87 284.56 286.21 302.87 301.85 HOURS 16.5 AVERAGE 132.7 1470.7 7.4 113.4 1323.2 10/12/16 8.5 VERTICAL DEPTH 1339.04 1625.34 1820.65 2012.55 2298.07 CONDITION T/B/C REASON PULLED CURRENT AVG 127.3 2058.7 7.7 122 1627 ft/hr amps Klbs RPM psi CL- 29000 160 CCI Ca+ TRIP GAS= 0 WIPER GAS= 8 SURVEY:: 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG nla GAS DESCRIPTION 4/26/2002 Daily Report PHILLIPS ALASKA North Slope Lookout #2 REPORT FOR Ray Skinner DATE Mar 05.2002 TIM E 06.00:00 Page I of I DAILY WELLSITE REPORT [1 EPOCH DEPTH 3105 YESTERDAY 2366 PRESENT OPERATION= Out of Hole - Casing Depth 24 Hour Footage 739 CASING INFORMATION 7" @ 100' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 1225 MXC1 5002280 3x20.1x14 500 3105 2605' 25.95 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 176.7 @ 2994 6.0 @ 2382 95.9 0.0 ft/hr SURFACE TORQUE 2389 @ 3054 770 @ 3035 1802.0 1784.1 amps WEIGHT ON BIT 23 @ 2500 2 @ 2370 14.2 16.5 Klbs ROTARY RPM 122 @ 2366 85 @ 3054 118.8 120 RPM PUMP PRESSURE 1867 @ 3099 888 @ 2370 1705.0 1839 psi DRILLING MUD REPORT DEPTH: 3205 MW 10.0 VIS 45 P\I 14 YP 22 FL Gels 8/10/12 CL- 29000 FC SOL 9.5 SD 2 OIL MBL pH 8.90 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL HIGH LOW AVERAGE 39 @ 3100 2 @ 2383 0 @ 0 0 @ 3105 CHROMATOGRAPHY(ppm) 9052 @ 3100 491 @ 2383 32 @ 3060 1 @ 2765 15 @ 3098 1 @ 2912 12 @ 3098 1 @ 3053 1 @ 3093 1 @ 3105 17.7 0 TRIP GAS= 0 WIPER GAS= 61u SURVEY= 0 3838.2 8.3 1 7 0.7 00 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG N/A LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Claystone 60%, Siltstone 10%. Tuffaceous Claystone 30%. DAILY ACTIVITY SUMMARY Drill ahead - Circulate Bottoms Up - Wipe Hole - POOH Epoch Personal On Board= 4 Daily Cost 2540 Report by: Bob Nichol file:/ /D:\Momjng%20Reoorts\20020305 . htm 4/26/2002 Daily Report PHILLIPS ALASKA North Slope Lookout #2 REPORT FOR Ray Skinner DATE Mar 06.2002 TIME 06:00:00 Page I of I DAILY WELLSITE REPORT [1 EPOCH DEPTH 3105 YESTERDAY 3105 PRESENT OPERATION= CEMENTING OPERATIONS CASING INFORMATION 16" @ 108' 9-518- @ 3097' 24 Hour Footage 0 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA Bn INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRilLING PARAMETERS HIGH lOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 3105 0 @ 3105 0 0 ftlhr SURFACE TORQUE 1784 @ 3105 1784 @ 3105 0 0 amps WEIGHT ON 81T 16 @ 3105 16 @ 3105 0 0 Klbs ROTARY RPM 120 @ 3105 120 @ 3105 0 0 RPM PUMP PRESSURE 1839 @ 3105 1839 @ 3105 0 0 psi DRilLING MUD REPORT DEPTH: N/A MW VIS PV yp Fl Gels CL- FC SOL SD Oil MBl pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITC H GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHO\NS INTERVAL HIGH LOW AVERAGE 31 @ 3105 31 @ 3105 0 TRIP GAS= 0 0 @ 3105 0 @ 3105 0 WIPER GAS= 0 CHROMA TOGRAPHY(ppm) SURVEY= 0 7424 @ 3105 7424 @ 3105 0 CONNECTION GAS HIGH= 0 10 @ 3105 10 @ 3105 0 AVG= 0 13 @ 3105 13 @ 3105 0 CURRENT 0 10 @ 3105 10 @ 3105 0 CURRENT BACKGROUND/AVG NIA 1 @ 3105 1 @ 3105 0 N/A LlTHOlOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Claystone 60%. Siltstone 10%, Tuffaceous Claystone 30% DAILY ACTIVITY SUMMARY Circulate/condition mud - Run Casing - Run 9-518"' casing to 3097' - Test - Nipple up - BOP test - Epoch Personel On Board= 4 Report by: Bob Nichol Daily Cost 2465 filp'lIn'\MnminoO/n?nRpnnrt~\?OO?OlOh htm 4/?ft/?OO? Daily Report Page 1 of I PHilLIPS ALASKA North Slope DAILY WELLSITE REPORT [~ EPOCH lookout #2 REPORT FOR Ray Skinner DATE Mar 07.2002 TIME 06:00:00 DEPTH 3190 YESTERDAY 3106 PRESENT OPERATION", DRill AHEAD 24 Hour Footage 84 CASING INFORMATION 16" @ 108' 9-5188 @ 3097' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HYCAlOG DS70 200975 6x12 3105 100 2.86 DRilLING PARAMETERS HIGH lOW AVERAGE CURRENT AVG RATE OF PENETRATION 137.7 @ 3140 3.1 @ 3126 61.2 55.2 ftlhr SURFACE TORQUE 2631 @ 3106 342 @ 3126 1727.0 1619.9 amps WEIGHT ON BIT 14 @ 3146 0 @ 3126 10.1 13.7 Klbs ROTARY RPM 103 @ 3134 41 @ 3126 82.1 84 RPM PUMP PRESSURE 1829 @ 3116 915 @ 3108 1594.3 1706 psi DRilLING MUD REPORT DEPTH: 3105 MW 10.0 VIS 42 PV 12 YP 16 FL Gels 5/7/8 Cl- 26000 FC SOL 6.0 SD 3.0 Oil MBl pH 9.0 Ca+ 320 eCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(umts) DITCH GAS CUTTING GAS HIGH lOW AVERAGE 10.0 0 TRIP GAS= 0 WIPER GAS= 0 SURVEY= 0 25 @ 3178 1 @ 3115 0 @ 0 0 @ 0 METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUT AN E(C-4) PE N TAN E(C-5) HYDROCARBON SHOWS INTERVAL 5523 @ 24 @ B @ 7 @ 1 @ CHROMATOGRAPHYwpm) 3178 310 @ 3115 3178 1 @ 3125 3106 1 @ 3188 3106 1 @ 3188 3106 1 @ 3108 Nil LITHOLOGY/REMARKS 2273.7 9.5 2.4 0.9 0.0 CONNECTION GAS HIGH= 13u AVG= 13u CURRENT CURRENT BACKGROUND/AVG 9u GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Claystone 60%, Siltstone 20%, Tuffaceous Claystone 10%, Tuff 10% DAILY ACTIVITY SUMMARY Test BOPE (5000 psi hig f/10minutes) Run into hole. Test 9-5/8" casing. Drill out cement. Drill ahead Epoch Personel On Board= 4 Daily Cost 2465 Report by~ Bob Nichol hi p'¡ tn.\ l\¡f"rnino~1.. ?OR pn('\rt~\ ?OO?O107 htm 4I?h/?O()~ Daily Report PHILLIPS ALASKA North Slope Lookout #2 REPORT FOR Ray Skinner DATE Mar 08.2002 TIME 04:00:00 Page I of I DAILY WELLSITE REPORT [~ EPOCH DEPTH 4774 YESTERDAY 3191 PRESENT OPERATION= DRILL AHEAD 24 Hour Footage 1583 CASING INFORMATION 16" @ 108' 9-518- @ 3097 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3487.55 0.31 220.24 3487.37 3584.16 0.27 238.64 3583.98 SURVEY OAT A 3578.34 0.28 212.15 3678.16 3775.45 0.22 217.54 3775.27 3871.86 0.26 217.55 3871.68 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/BfC PULLED 2 8.5" HYCALOG DS70 200975 6X12 3105 1728.12 2526 DRILLING PARAMETERS HIGH lOW AVERAGE CURRENT AVG RATE OF PENETRATION 196.8 @ 4225 10.2 @ 4461 98.7 101 1 ftlhr SURFACE TORQUE 3056 @ 4591 555 @ 3472 1948.0 2506.1 amps WEIGHT ON BIT 22 @ 3287 0 @ 3472 6.8 3.5 KJbs ROTARY R PM 179 @ 3391 73 @ 3619 157.8 164 RPM PUMP PRESSURE 2205 @ 4562 1379 @ 3526 1909.3 2127 psi DRILLING MUD REPORT DEPTH' 4450 MW 9.60 VIS 48 PV 15 VP 17 FL Gels 4/6/8 CL- 30000 FC SOL 4.6 SD 0.50 OIL MBL pH 8.7 Ca+ 200 eCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL HIGH LOW AVERAGE 115 @ 3480 0 @ 4142 19.3 TRIP GAS= 0 0 @ 0 0 @ 0 0 WIPER GAS= 0 CHROMATOGRAPHY(ppm) SU RVEY= 0 26698 @ 3480 130 @ 4142 4509.3 CONNECTION GAS HIGH= 19u 859 @ 3646 1 @ 4216 72.8 AVG= 19 344 @ 3646 1 @ 4232 176 CURRENT 227 @ 3646 1 @ 4684 10.1 CURRENT BACKGROUND/AVG 14u 122 @ 3646 1 @ 4436 3.8 see log - spotty 4505-4540' associated wI siltstone I pebbly sand LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PR ESENT LITHOLOGY Claystone 80%, Siltstone 20% DAILY ACTIVITY SUMMARY Drill ahead. Wipe hole. Dnll ahead Epoch Personel On Board= 4 Daily Cost 2465 Report by: Bob Nichol fa Ie:! /D:\Momi ng%20Reoorts\20020308. htm 4/26/2002 Daily Report PHILLIPS ALASKA North Slope lookout #2 REPORT FOR Ray Skinner DATE Mar 09.2002 TIM E 04:00:00 Page 1 of 1 DAILY WELLSITE REPORT [~ EPOCH DEPTH 5645 YESTERDAY 4775 PRESENT OPERATION= DRILL AHEAD CASING INFORMATION 16" @ 108' 9.5/8D @ 3105' 24 Hour Footage 870 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA Unavailable BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TfB/C PULLED 2 8.5 HYCAlOG DS70 200975 6><12 3105 2569 36.48 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 152.8 @ 4991 10.0 @ 5481 71.8 63.1 ftIhr SURFACE TORQUE 2923 @ 4983 604 @ 5154 2049.5 1940.3 amps WEIGHT ON BIT 10 @ 5012 0 @ 4868 4.9 4.0 KJbs ROTARY RPM 181 @ 5072 118 @ 4867 172.9 180 RPM PUMP PRESSURE 2487 @ 5251 1729 @ 5272 2168.1 2304 psi DRILLING MUD REPORT DEPTH: 5450 MW 9.65 VIS 46 PV 17 yp 19 Fl Gels 3/8/12 CL- 32000 FC SOL 4.5 SD 0.75 OIL MBl pH 9.40 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(umts) DITCH GAS CUTTING GAS M ETHAN E(C-1) ETHANE(C-2) PROPANE.{C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBONSHO~ INTERVAL HIGH LOW AVERAGE 24 @ 4840 2 @ 4882 10.4 0 @ 0 0 @ 0 0 CH ROMA TOGRAPHY(ppm) 6393 @ 4840 609 @ 4882 2054 1 156 @ 5545 13 @ 4882 67.4 78 @ 5545 1 @ 5135 20.2 36 @ 5545 1 @ 5150 8.8 9 @ 5634 1 @ 5614 0.7 TRIP GAS= 623u WIPER GAS= 0 SU RVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 9u LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Claystone 70%, Siltstone 20%, Shale 10% DAIL Y ACTIVITY SUMMARY Drill ahead. Wiper Trip to Shoe - 3.1 hrs. (623U Trip Gas). RIH. Drill ahead Epoch Personal On Board= 4 Report by: Bob Nichol Daily Cost 2465 f1lp.¡fn'\MnrT11noO/n ?()R p.nnrt~\ ?OO?010Q htm 41?fi/700? Dai I y Report PHilLIPS ALASKA North Slope lookout #2 REPORT FOR Ray Skinner DATE Mar 10, 2002 TIM E 06:00:00 Page 1 of 1 DAILY WELLSITE REPORT [~ EPOCH DEPTH 6485 YESTERDAY 5646 PRESENT OPERATION= POOH - MWD FAILURE CASING INFORMATION 16" @ 108' 9-5/88 @ 3105' 24 Hour Footage 839 SURVEY DATA BIT INFORMATION NO. SIZE 2 8.5" TYPE HYCALOG DS70 DRilLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW VIS FC SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL PV SD 13532 1226 679 249 87 DEPTH INCLINATION AZIMUTH 5789.29 0.96 233.60 5886.16 0.92 244.49 5981.05 0.91 247.21 6077.23 1.01 237.65 6173.36 0.99 227.44 INTERVAL SIN JETS IN OUT FOOTAGE HOURS 200975 6x12 3105 3383 53.78 HIGH lOW AVERAGE 96.5 @ 5958 8.5 @ 6473 53.1 3028 @ 6479 577 @ 5731 1953.2 8 @ 6480 0 @ 5828 4.5 183 @ 5732 3 @ 6018 179.1 2912 @ 6470 301 @ 6018 2416.7 DEPTH: UNAVAIL yp Fl Gels OIL MBl pH 76 0 HIGH lOW @ 6352 J @ 6333 @ 0 0 @ 0 CHROMATOGRAPHYwpm) @ 6352 538 @ 6333 @ 6352 45 @ 6333 @ 6352 25 @ 6333 @ 6351 10 @ 6333 @ 6465 1 @ 6384 2220.4 150.1 71.7 31.6 7.6 AVERAGE 12.2 0 SEE LOG LITHOlOGY/REMARKS LITHOLOGY PRESENT LITHOLOGY Claystone 40%, Sand 20%. Siltstone 20%, Tuff 10%. Sandstone 10% DAilY ACTIVITY SUMMARY Drill ahead. Wiper trip. POOH - MWD tool failure Epoch Personel On Board= 4 Report by: Bob Nichol Daily Cost 2465 fi1p'./fT)'\M()m¡noO/~?ORp.n()rt~\?OO?011 0 htm VERTICAL DEPTH 5788.95 5885.81 5980.68 6076.85 6172.97 CONDITION T/B/C REASON PULLED CURRENT AVG 9.6 1004.2 0.9 134 2859 ftlhr amps Klbs RPM psi CL- Ca+ CCI TRIP GAS= 0 WIPER GAS= 47u SU RVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG N/A GAS DESCRIPTION 4I?n/?OO? CASING INFORMATION 16" @ 108' 9-5/88 @ 3105 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T IB/C PULLED 2R1 8.5" HYCAlOG DS70 20198 3813/3-/14 6488 290.89 5.28 DRILLING PARAMETERS HIGH lOW AVERAGE CURRENT AVG RATE OF PENETRATION 1400 @ 6711 6.0 @ 6486 60.8 56.9 ftIhr SURFACE TORQUE 2751 @ 6711 22 @ 6515 1805.3 2160.6 amps WEIGHT ON BIT 8 @ 6648 0 @ 6517 5.3 5.3 Klbs ROTARY RPM 156 @ 6488 28 @ 6514 91 3 104 RPM PUMP PRESSURE 3367 @ 6586 2033 @ 6489 3149.4 3222 psi DRILLING MUD REPORT DEPTH: 6525 57 PV 25 YP 25 Fl Gels 4/10/15 Cl- 30000 10.8 SO 0.50 Oil MBl pH 9.50 Ca+ 120 CCI Dai I y Report PHilLIPS ALASKA North Slope lookout #2 REPORT FOR Ray Skinner DATE Mar 11. 2002 TIM E 04:00:00 MW FC 11.3 VIS SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBONSHO~ INTERVAL Page 1 of 1 DAILY WELLSITE REPORT [~ EPOCH DEPTH 6725 YESTERDAY 6486 PRESENT OPERATION= DRILL AHEAD 24 Hour Footage 239 HIGH AVERAGE 20.2 0 TRIP GAS= 77u WIPER GAS= 0 SURVEY= 0 lOW 90 0 @ 6663 6 @ 6570 @ 0 0 @ 0 13867 @ 1478 @ 778 @ 316 @ 130 @ CH ROMA TOGRAPHY(ppm) 6663 S63 @ 6570 6663 48 @ 6569 6662 21 @ 6570 6662 9 @ 6570 6662 2 @ 6530 SEE LOG UTHOLOGY/R EMARKS DESCRIPTION 2991.6 299.6 154.2 670 24.3 CONNECTION GAS HIGH::: 28u AVG= 28u CURRENT 28u CURRENT BACKGROUND/AVG 42u GAS LITHOLOGY PRESENT LITHOLOGY Claystone 50%, Siltstone 30%, Shale 20% DAILY ACTIVITY SUMMARY Replace MWD tool. RIH. Drill ahead. Epoch Personal On Board= 4 Report by: Bob Nichol Daily Cost 2540 f11p'ltn'\M()rn1no°/"?ORpn()rt~\?OO?O-:; 11 h1m 4I?tí!?OO? Dai I y Report Page I of I PHILLIPS ALASKA North Slope DAILY WELLSITE REPORT [~ EPOCH Lookout #2 REPORT FOR Ray Skinner DATE Mar 12, 2002 TIME 04:00:00 DEPTH 7893 YESTERDAY 6726 PRESENT OPERATION:; Clrc btms up 24 Hour Footage 1167 CASING INFORMATION 16- @ 108' 9-518- @ 3105' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2R1 8.5" HYCALOG DS70 3-1313-/14 3105 7893.1 4788.1 23.43 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 162.0 @ 7289 6.5 @ 7835 72.2 121.0 ftIhr SURFACE TOROUE 3075 @ 6924 37 @ 6998 1833.7 1850.9 amps WEIGHT ON BIT 9 @ 6936 0 @ 7585 4.8 3.0 Klbs ROTARY RPM 105 @ 7476 33 @ 7015 101.0 101 RPM PUMP PRESSURE 3495 @ 7316 2461 @ 7388 3312.4 3189 psi DRILLING MUD REPORT DEPTH: 7759 MW 11.30 VIS 55 PV 30 YP 25 FL Gels 3/9/15 CL- 32000 FC SOL 10.6 SD 0.50 OIL MBL pH 9.40 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 486 @ 7866 7 @ 7091 44.9 CUTTING GAS 0 @ 0 0 @ 0 0 CH ROMATOGRAPHY(ppm) 73212 @ 7869 1095 @ 7853 6952.1 10488 @ 7870 116 @ 7091 817.0 7601 @ 7882 53 @ 7091 495.5 3265 @ 7885 23 @ 7091 205.7 817 @ 7870 7 @ 7892 72.7 SEE LOG - MAX GAS:; 486u LITHOLOGY/REMARKS TRIP GAS= 0 WIPER GAS= 0 SU RVEY= 0 METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAt CONNECTION GAS HIGH:; 28u AVG= 28u CURRENT CURRENT BACKGROUND/AVG N/A GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY SANDSTONE 100% DAILY ACTIVITY SUMMARY DRILL AH EAD, TD@ 7893' Epoch Personel On Board= 4 Daily Cost 2540 Report by: BOB NICHOL fí Ie. /IO-\Morni nQ°1ri20Reoorts\200203 ) 2. hb11 4/26/2002 Oai I y Report PHILLIPS ALASKA North Slope Lookout #2 REPORT FOR D. Heim. DATE Mar 12, 2002 TIME 04:00:00 Page 1 of 1 DAILY WELLSITE REPORT f.' :...8I-ø--- ~~ -, T) ~.-,r-" T T lH I""- Ii :t~ ~ ......... ¿..". ~ ..J; -1.. 9f:\---..." ~""'- _0. J.... ~ DEPTH 7893 YESTERDAY 7893 PRESENT OPERATION= Run Casmg 24 Hour Footage 0 CASING INFORMATION 16" @ 108' 9-5/8" @ 3105' DEPTH 7511.98 7607.72 7705.02 7800.90 7834.21 SURVEY DATA INCLINATION 0.35 0.49 0.54 031 0.51 AZIMUTH 109.72 109.68 116,36 131 .37 111 .45 VERTICAL DEPTH 7511.48 7607.22 7704.52 7800 39 7833.70 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/BIC PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 121 0 @ 7893 121.0 @ 7893 1.$ 121 0 ftlhr SURFACE TORQUE 1850 @ 7893 1650 @ 7893 1$ 1650.9 amps WEIGHT ON BIT 3 @ 7893 3 @ 7893 1 $ 3.0 Klbs ROTARY RPM 101 @ 7893 101 @ 7893 1.$ 101 RPM PUMP PRESSURE 3189 @ 7893 3189 @ 7893 1.$ 3189 psi DRILLING MUD REPORT DEPTH: 7893 MW FC VIS SOL 11 30 MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBONSHO~ INTERVAL LITHOLOGY PRESENT LITHOLOGY Sand 100% 56 10.6 PV SO 30 050 YP Oil 25 FL MBl Gels 3/9/15 9.40 CL- 32000 120 pH Ca+ eCI HIGH LOW AVERAGE 57 @ 7893 57 @ 7893 0 @ 0 @ CHROMATOGRAPHY(ppm) 3864 @ 7893 3864 @ 7893 651 @ 7893 651 @ 7893 553 @ ì893 553 @ 7893 260 @ ì893 260 @ 7893 0 @ 7893 0 @ 7893 TRIP GAS= 0 WIPER GAS= 238U SU RVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG n/a UTHOLOG Y/R EMAR KS GAS DESCRIPTION Epoch Personel On Board= 4 DAilY ACTIVITY SUMMARY POOH. DOWNLOAD MWD TOOLS. RIG UP AND RUN CASING. Daily Cost 2540 Report by: Bob Nichol f11 P' / If). \ l\/Inrni noo/;.. '")()R ,pnnrl<;:\ '")()n?n 111 htm 41?';/"'()()'") Daily Report PHILLIPS ALASKA North Slope DAILY WELLSITE REPORT Lookout #2 REPORT FOR D. Helm. DATE Mar 14, 2002 TIME 04'00'00 DEPTH 7893 YESTERDAY 7893 PRESENT OPERATION= Test BOPs, mix mud 24 Hour Footage 0 CASING INFORMATION 16" @ 108' 9-5/8" @ 3105' DEPTH INCLINATION SURVEY DATA 7834.21 0.51 BIT INFORMATION INTERVAL NO SIZE TYPE SIN JETS IN OUT FOOT AGE DRILLING PARAMETERS HIGH LOW RATE OF PENETRATION 121.0 @ 7893 121.0 @ 7893 SURFACE TORQUE 1850 @ 7893 1850 @ 7893 WEIGHT ON BIT 3 @ 7893 3 @ 7893 ROTARY RPM 101 @ 7893 101 @ 7893 PUMP PRESSURE 3189 @ 7893 3189 @ 7893 DRILLING MUD REPORT DEPTH: 7893 MW FC YP Oil 14 FL MBL 9.90 51 56 PV SO 16 025 VIS SOL MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS CUTTING GAS II-fIIGH 57 @ 7893 0 @ lOW 57 @ 7893 0 @ AVERAGE METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBONSHO~ INTERVAL CH ROMA TOGRAPHY(ppm) 3864 @ 7893 3864 @ 7893 651 @ 7893 651 @ 7893 553 @ 7893 553 @ 7893 260 @ 7893 260 @ 7893 0 @ 7æ3 0 @ 7æ3 LlTHOLOGY/R EMAR KS LITHOLOGY PRESENT LITHOLOGY Sand 100% DAILY ACTIVITY SUMMARY Run 7" casing. Hit bridge @ 7838'. PIU cement head Test BOPs Epoch Personel On Board= 4 Daily Cost 2540 Report by: Bob Nichol tì Ie:! !D:~1omi ng~/o20Reports\200203 14. htm AZIMUTH 111 .45 HOURS Page 1 of 1 [~ EPOCH VERTICAL DEPTH 7833 70 CONDITION TIBIC REASON PULLED AVERAGE CURRENT AVG ftIhr amps Klbs RPM psi Gels 21315 CL- 31000 120 CCI pH 9.40 Ca+ TRIP GAS= 170u WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG n/a GAS DESCRIPTION 4/26/2002 CASING INFORMATION 16" @ 108' 9-5/8" @ 3105' 7" @ 7893 DEPTH INCLINATION AZIMUTH SURVEY DATA 7834.21 0.51 111.45 BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS 3 6-1/8" RBI CD328 3"22 7893 DRILLING PARAMETERS HIGH LOW AVERAGE RATE OF PENETRATION 121.0 @ 7893 121.0 @ 7893 SURFACE TORQUE 1850 @ 7893 1850 @ 7893 WEIGHT ON BIT 3 @ 7893 3 @ 7893 ROTARY RPM 101 @ 7893 101 @ 7893 PUMP PRESSURE 3189 @ 7893 3189 @ 7893 DRILLING MUD REPORT DEPTH: 7893 MW 9.20 VIS 56 PV 20 YP 14 FL Gels 3/4/5 CL- FC SOL 5.7 SO 0 OIL MBL pH 8.0 Ca+ Daily Report PHILLIPS ALASKA North Slope Lookout #2 REPORT FOR D. Heim DATE Mar 15,2002 TIME 04:00:00 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(unlts) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) ,HYDROCARBONSHO~ INTERVAL LITHOLOGY PRESENT LITHOLOGY Sand 100% Pagel of] DAILY WELLSITE REPORT ¡;r-: liE 7 -"'\ -¡""""t. (~ f-' -., -r .... '. ,,~' \G J ' i&- :;:, r $" q, J--, .á.-. '"1! ...::.....-. .-:..... '._~,. -!- -...L .-1- DEPTH 7893 YESTERDAY 7893 PRESENT OPERATION= Weight up 24 Hour Footage 0 VERTICAL DEPTH 7833.70 CONDITION T/B/C REASON PULLED CURRENT AVG ftJhr amps Klbs RPM psi 15000 240 eCI HIGH 57 @ 7893 0 @ LOW 57 @ 7893 0 @ TRIP GAS= 38u WIPER GAS= 0 SURVEY= 0 AVERAGE 3864 @ 65'1 @ 553 @ 260 @ 0 @ CH ROMA TOGRAPHY(ppm) 7893 3864 @ 7893 7893 651 @ 7893 7893 553 @ 7893 7893 260 @ 7893 7893 0 @ 7893 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG n/a LITHOLOGY/REMARKS GAS DESCRIPTION Epoch Personel On Board= 3 DAILY ACTIVITY SUMMARY RIH. Test MWD Well flowing. Shut in (5bbl gain). Weight up to 9.7ppg. Daily Co,st 2540 Report by: Bob Nichol filp.//n'\I\:If"\rninnO'n')()Rpnf"\rtt:\ "'()()')n~' '" him Jl')f)/'7()()""' CASING INFORMATION 16" @ 108' 9-5/8- @ 3105' r @ 7893 DEPTH INCLINATION AZIMUTH SURVEY DATA 7834.21 0.51 111 45 BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS 3 6-1/8" RBI CD328 3"22 7893 DRILLING PARAMETERS HIGH LOW AVERAGE RATE OF PENETRATION 121.0 @ 7893 121.0 @ 7893 SURFACE TORQUE 1850 @ 7893 1850 @ 7893 WEIGHT ON BIT 3 @ 7893 3 @ 7893 ROTARY RPM 101 @ 7893 101 @ 7893 PUMP PRESSURE 3189 @ 7893 3189 @ 7893 DRILLING MUD REPORT DEPTH. 7893 MW 980 VIS 63 PV 22 yp 15 FL Gels 3/4,/6 CL- FC SOL 9.7 SD 0 OIL MBL pH 109 Ca+ Dai I y Repon PHILLIPS ALASKA North Slope Lookout #2 REPORT FOR D Heim DATE Mar 16, 2002 TIM E 04:00:00 MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PE N TAN E(C-5ì HYDROCARBONSHO~ INTERVAL LITHOLOGY PRESENT LITHOLOGY Sand 100% Page 1 of 1 DAILY WELLSITE REPORT -IT-Ji= "'? -.,~, ~~.. :"..-~...~ ~ ~ ~:.-. ~ "'''t, ~ ~ \-: ~ ~ ~-- JL \\-.....' ~~ ~..~ i DEPTH 7893 YESTERDAY 7893 PRESENT OPERATION= Coring Ops 24 Hour Footage 0 VERTICAL DEPTH 7833 70 CONDITION T IB/C REASON PULLED CURRENT AVG ftlhr amps Klbs RPM psi 17000 200 CCI HIGH 57 @ 7893 0 @ LOW 57 @ 7893 0 @ AVERAGE TRIP GAS= WIPER GAS= 0 SURVEY= 0 3864 @ 651 @ 553 @ 260 @ 0 @ CH ROMA TOGRAPHY(ppm) 7893 3864 @ 7893 7893 651 @ 7893 7893 553 @ 7893 7893 260 @ 7893 7893 0 @ 7893 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUNDfAVG nla LITHOLOGY/REMARKS GAS DESCRIPTION I DAILY ACTIVITY SUMMARY Monitor Well RIH. Weight up. Well flowing Repair top drive Run core assembly Into hole Daily Cost 2540 Epoch Personel On Board= 4 Report by: Bob Nichol tìlp'/fT).\l\:rnm1noo.;"?ORpnnrt,\?OO"7011fí htrn 4/2ó/10()~ Oai I Y RepoI1 PHILLIPS ALASKA North Slope Lookout #2 REPORT FOR D. HElM. DATE Mar 17. 2002 TIM E 05.00'00 Page 1 of I DAILY WELLSITE REPORT [11~P(JCH DEPTH 7930 YESTERDAY 78940 PRESENT OPERATION= Coring Operations 24 Hour Footage 36 CASING INFORMATION 16R @ 108' 9.5/8R @ 3105 r @7893' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED COle1 6.125 AXC-425 7100433 NfA 7894' 36 7.02 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 940 @ 7911 0 0.8 @ 7930 405 08 ftJhr SURFACE TORQUE 2210 @ 7903.0 501 @ 7894.0 1795.3 997.5 amps WEIGHT ON BIT 11 @ 7930 0 @ 7894.0 4.9 11.1 Klbs ROTARY RPM 88 @ 7925 21 @ 7894.0 61.8 82 RPM PUMP PRESSURE 1365 @ 7930 903 @ 7894.0 1087.3 1365 psi DRILLING MUD REPORT DEPTH: 7928 MW FC VIS SOL 9.95 MWO SUMMARY INTERVAL , TOOLS TO GAS SUMMARY(umts) DITC H GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBONSHO~ INTERVAL 92 10.9 PV SD 28 0 CCI yp OIL 22 Fl Gels 6/8110 11.40 CL- 16000 160 MBL pH Ca+ HIGH LOW AVERAGE 1070 @ 7904.0 2 @ 7930 521.7 0 @ 0 0 @ 0 0 CHROMATOGRAPHY(ppm) 137559 @ 7904.0 64 @ 7930 59621 7 25792 @ 7904.0 14 @ 7930 11501 9 22256 @ 7904.0 15 @ 7930 10292 6 9281 @ 7904.0 12 @ 7930 467 1.9 3046 @ 791 1 0 2 @ 7930 1496.2 LITHOLOGY/REMARKS TRIP GAS= 0 WIPER GAS= 0 SU RVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 2u GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY SN30SS60SH10 Epoch Personel, On Board= 4 DAILY ACTIVITY SUMMARY Trip in. circulate Bims Up. Core 7894-7928' POOH WI core. RIH. Continue core run Daily Cost 2540 Report by: Bob Nichol ti le:lID:\l\'lorni n~O"ó20Reports\20020317. htm 4/26/2002 Daily Report PHILLIPS ALASKA North Slope Lookout #2 REPORT FOR D HElM DATE Mar 18. 2002 TIM E 05:00'00 Page I of 1 DAILY WELLSITE REPORT f- - -- --- -- .~ ""-"'1""'" ....... -- ,~ . ~ ) d' ',', ¡ ~i i =. r..; 5. ~ ~\¡, ~ ~ ~ -.l-.... ~ ,-,",,\ '''''~ "," L . DEPTH 8074 YESTERDAY 7930 PRESENT OPERATION= Drill ahead I CASING INFORMATION 16" @ 108' 9-5/8" @ 3105' T' @ 7893' 24 Hour Footage 144 DEPTH INCLINATION AZIMUTH SURVEY DATA 7961.24' 0.30 150.18 BIT INFORMATION INTERVAL NO SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS 4 6.125" HTC STX 604 0325087 4.12 7893' 210 4 DRILLING PARAMETERS HIGH LOW AVERAGE RATE OF PENETRATION 774 @ 8071 0.4 @ 7931 34.5 SURFACE TORQUE 2526 @ 8072 997 @ 7930 1864.9 WEIGHT ON BIT 12 @ 7931 3 @ 7942 6.1 ROTARY RPM 146 @ 807t 82 @ 7930 923 PUMP PRESSURE 2230 @ 8068 1255 @ 7931 2126.4 DRILLING MUD REPORT DEPTH' 7973 MW FC 980 VIS SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(unlts) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) ,HYDROCARBONSHO~ , INTERVAL 72 10.2 PV SD 25 YP OIL 19 FL MBL Gels 4/8/10 11.30 pH HIGH LOW AVERAGE 19 @ 7993 2 @ 7931 14.5 0 @ 0 @ CHROMA TOGRAPHY(ppm) 2916 @ 7993 64 @ 7930 22 fa. 1 442 @ 8001 14 @ 7930 326.1 336 @ 8072 15 @ 7930 236.1 148 @ 8072 12 @ 7930 95.4 62 @ 8072 2 @ 7932 32.4 UTHOlOGY/REMARKS GAS LITHOLOGY PRESENT LITHOLOGY Siltstone 100% VERTICAL DEPTH 7960.73' CONDITION T/B/C REASON PULLED CURRENT AVG 63.9 2249.2 8.1 146 2228 ftlhr amps Klbs RPM psi CL- 16000 120 CCI Ca+ TRIP GAS= 0 WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 7u AVG= ïu CURRENT 0 CURRENT BACKGROUND/AVG 17u DESCR IPTlON Epoch Personel On Board= 4 DAILY ACTIVITY SUMMARY Tnp In to 7893'. Core f/7928-7931' Pump dry Job. Trip out. RIH WI new BHA. Mad pass. Drill ahead Report by: Bob Nichol Daily Cost 2540 file"/fD:\JVlorninQo'o20ReDorts\20020318.hun 4/26/2002 Dai I y Report PHILLIPS ALASKA North Slope Lookout #2 REPORT FOR D. HElM. DATE Mar 19,2002 TIM E 05:00:00 Page 1 of I DAILY WELLSITE REPORT [~ ~ -0; "1) {' ,(~-...... T -,:- ~I, ~ ,.' ~ t t ~L-! ...f.-..--. -al... .. "- ".r". "'--,..'...J...... ~... DEPTH 8200 YESTERDAY S075 PRESENT OPERATION= Out of Hole 24 Hour Footage 125 CASING INFORMATION 16" @ 10S' 9-5/S" @ 3105' 7" @ 7893' DEPTH INCLINATION SURVEY DATA BIT INFORMATION INTERVAL NO SIZE TYPE SIN JETS IN OUT FOOTAGE DRILLING PARAMETERS HIGH LOW RATE OF PENETRATION 97S @ 8176 2.7 @ 8175 SURFACE TORQUE 2672 @ 8185 949 @ 8188 WEIGHT ON BIT 8 @ 8077 2 @ 8188 ROTARY RPM 146 @ 8075 85 @ 8092 PUMP PRESSURE 2336 @ 813'\ '\860 @ 8092 DRILLING MUD REPORT DEPTH: 8200 MW FC 9.80 VIS SOL MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANEIC-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PE N TAN E(C-S) HYDROCARBON SHOWS INTERVAL AZIMUTH VERTICAL DEPTH HOURS CONDITION T/BIC REASON PULLED AVERAGE 52.1 2092.5 66 133.9 228 '\.2 CURRENT AVG ftlhr amps Klbs RPM psi 73 10.0 PV SO 25 0 YP Oil CCI '18 FL MBL 5/8/10 10.40 Gels CL- 14000 40 pH Ca+ HIGH LOW AVERAGE 18 @ 8151 6 @ 8104 15.4 TRIP GAS= 0 0 @ 8200 0 @ 8200 00 WIPER GAS= 23u CH ROMA TOGRAPHY(ppm) SURVEY= 0 3720 @ 8076 905 @ 8104 2499 4 CONNECTION GAS HIGH= 0 571 @ 8076 135 @ 8104 391.7 AVG= 0 481 @ 8076 110 @ 8104 3077 CURRENT 0 212 @ 8076 48 @ 8104 136.8 CURRENT BACKGROUND/AVG nfa 91 @ 8076 17 @ 8104 48.7 lITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY CI,¡¡ystone 30%. Shale 20%. Siltstone 50%. DAILY ACTIVITY SUMMARY Drill 7974-8200' Short trip to 7870'. TOH to shoe Pump dry job. POOH. Prepare for downhole geophysics Epoch Personsl On Board= 3 Report by. Bob Nichol Da ily Cost 2540 ti Ip' /fn'\Mnrni nu~/... "OR pnnrtç,;\?OO?0'1 i c) htm 4I!A/")OOì Daily RepoJ1 PHILLIPS ALASKA North Slope Lookout #2 REPORT FOR D. Heim DATE Mar 20,2002 TIM E 05:00:00 Page 1 of 1 DAILY WELLSITE REPORT [~ EPOCH DEPTH 8200 YESTERDAY 8200 PRESENT OPERATION= Circulate. clean hole. CASING INFORMATION 16" @ 108' 9-5/8a @ 3105' 7" @ 7893' 24 Hour Footage 0 DEPTH INCLINATION AZIM UTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TlBlC PULLED 3RR 6-1I8a RBI CD328 4x13 8200 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 20.7 @ 8200 20.7 @ 8200 ftIhr SURFACE TORQUE 1911 @ 8200 1911 @ 8200 amps WEIGHT ON BIT 5 @ 8200 5 @ 8200 Klbs ROTARY RPM 105 @ 8200 105 @ 8200 RPM PUMP PRESSURE 2206 @ 8200 2206 @ 8200 psi DRILLING MUD REPORT DEPTH: 8200 MW 9.80 VIS 81 PV 25 YP 17 FL Gels 5/8/10 CL- 14000 FC SOL 9.9 SD 0 OIL MBL pH 10.60 Ca+ 40 CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHAN E(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBONSHO~ INTERVAL HIGH LOW AVERAGE 12 @ 8200 12 @ 8200 0 0 @ 0 0 @ 0 0 CHROMATOGRAPHY(ppm) 2061 @ 8200 2061 @ 8200 0 385 @ 8200 385 @ 8200 0 257 @ 8200 257 @ 8200 0 128 @ 8200 128 @ 8200 0 42 @ 8200 42 @ 8200 0 LlTHOLOGYfRIEMARKS TRIP GAS= 85u WI PER GAS= 0 SU RVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CU RRENT 0 CURRENT BACKGROUND/AVG N/A GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Claystone 30%, Shale 20%. Siltstone 50% DAILY ACTIVITY SUMMARY RIH, CIRCULATE. Note - 85u max gas @ bottoms up. Epoch Pel"3onel On Board= 2 Report by: Bob Nichol Da Ily Cost 2540 fi Ip,' //f)'\M()rningo/n20Ren()rt~\20020120 htm 4/?ó/200'2 CASING INFORMATION 16" @ 108' 9-5/8" @ 3105' 7" @ 7893' DEPTH INCLINATION AZIMUTH SURVEY DATA BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS 6 6-1/8" RBI CD328 4)( 13 8200 8200 DRILLING PARAMETERS HIGH LOW AVERAGE RATE OF PENETRATION 207 @ 8200 207 @ 8200 SURFACE TORQUE 1911 @ 8200 1911 @ 8200 WEIGHT ON BIT 5 @ 8200 5 @ 8200 ROTARY RPM 105 @ 8200 105 @ 8200 PUMP PRESSURE 2206 @ 8200 2206 @ 8200 DRILLING MUD REPORT DEPTH: 8200 MW 9.80 VIS 64 PV 25 YP 15 Fl Gels 4/5/6 Cl- FC SOL 9.9 SO 0 Oil MBl pH 10.30 Ca+ Oai I y Report PHilLIPS ALASKA North Slope lookout #2 REPORT FOR D. Helm DATE Mar 21. 2002 TIME 05'0000 MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL Page I of I DAILY WELLSITE REPORT ~-! -i:-~l)~r-,rT T !r- -MIl'! ~: ~ :~ .~ ~ ~----i .r...... LI& -c-- oJ ~ "\¡-.-. ...' ~ '- ~... ...:... DEPTH 8200 YESTERDAY 8200 PRESENT OPERATION= Downhole Geophysics, 24 Hour Footage 0 VERTICAL DEPTH CONDITION T/B/C REASON PULLED CURRENT AVG ftlhr amps Klbs RPM pSI 13000 40 CCI HIGH LOW AVERAGE 12 @ 8200 12 @ 8200 0 0 @ 0 0 @ 0 0 CH ROMA TOGRAPH V(ppm) 2061 @ 8200 2061 @ 8200 0 385 @ 8200 385 @ 8200 0 257 @ 8200 257 @ 8200 0 128 @ 8200 128 @ 8200 0 42 @ 8200 42 @ 3200 0 LITHOLOGY/REMARKS TRIP GAS: 12u WIPER GAS= 0 SURVEY", 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG NlA GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Claystone 30%, Shale 20%. Siltstone 50% Epoch Personel On Board= 2 DAILY ACTIVITY SUMMARY RIH, CIRCU LATE. Note - 12u max gas @ bottoms up Rig up for geophysIcs runs Run tools downhole. Da Ily Cost 2540 Report by. Bob Nichol tì le:/ID:\IVJorni nt!~/ô20ReDorts\200203 21. htm 4/26/2002 CASING INFORMATION 16" @ 108' 9-5/8" @ 3105' T' @ 7893' DEPTH INCLINATION AZIMUTH SURVEY DATA BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS 6 6-118" RBI CD328 4)(13 8200 8200 DRILLING PARAMETERS HIGH lOW AVERAGE RATE OF PENETRATION 207 @ 8200 207 @ 8200 SURFACE TORQUE 1911 @ 8200 1911 @ 8200 WEIGHT ON BIT 5 @ 8200 5 @ 8200 ROTARY RPM 105 @ 8200 105 @ 8200 PUMP PRESSURE 2206 @ 8200 2206 @ 8200 DRILLING MUD REPORT DEPTH: 8200 MW 9.80 VIS 6ï PV 22 YP 14 Fl Gels 3/4/6 CL- FC SOL 9.9 SD 0 OIL MBL pH 10.40 Ca+ Daily Report PHILLIPS ALASKA North Slope Lookout #2 REPORT FOR D. Helm DATE Mar 22,2002 TIME 05:00:00 MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENT ANE(C-5) HYDROCARBON SHOWS INTERVAL Pa ue I of I ~ DAILY WELLSITE REPORT ~ -JIll ;:; -. '~~ ...~-.." ,.-.. lí -r !.J = b ~_.~ ~{ 3-l ~iI Á.~-=-- ",-_.: '.......-;~ 1. DEPTH 8200 YESTERDAY 8200 PRESENT OPERATlON= Downhole Geophysics. 24 Hour Footage 0 VERTICAL DEPTH CONDITION T/B/C REASON PULLED CURRENT AVG ftlhr amps Klbs RPM psi 13000 40 CCI HIGH LOW AVERAGE 12 @ 8200 12 @ 8200 0 TRIP GAS=: 0 0 @ 0 0 @ 0 0 WIPER GAS=- 0 CH ROMA TOGRAPHY(ppm) SU RVEY= 0 2061 @ 8200 2061 @ 8200 0 CONNECTION GAS HIGH= 0 385 @ 8200 385 @ 8200 0 AVG= 0 257 @ 8200 257 @ 8200 0 CURRENT 0 128 @ 8200 128 @ 8200 0 CURRENT BACKGROUND/AVG N/A 42 @ 8200 42 @ 8200 0 LiTHOLOGYfR EMAR KS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Claystone 30%, Shale 20%, Siltstone 50% Epoch Personel On Board= 2 DAILY ACTIVITY SUMMARY POOH. Run MDT Tools downhole. Take Formation & Pressure samples POOH. Daily Cost 2540 Report by. Bob Nichol fi Ie' I/D: \l\ Jorni 1lQ.%20Reoorts\200203 22. htm 4/26/~OO2 CASING INFORMATION lõ @ 108' 9-5/8- @ 3105' r @ 7893' DEPTH INCLINATION SURVEY DATA BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE DRILLING PARAMETERS HIGH LOW RATE OF PENETRATION 20.7 @ 8200 20.7 @ 8200 SURFACE TORQUE 1911 @ 8200 1911 @ 8200 WEIGHT ON BIT 5 @ 8200 5 @ 8200 ROTARY RPM 105 @ 8200 105 @ 8200 PUMP PRESSURE 2206 @ 8200 2206 @ 8200 DRILLING MUD REPORT DEPTH: 8200 MW 9.80 VIS 67 PV 22 YP 14 FL FC SOL 9.9 SD 0 OIL MBL Dai I y Report PHILLIPS ALASKA North Slope Lookout #2 REPORT FOR D. Heim DATE Mar 23.2002 TIME 05'00.00 MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units DITCH GAS CUTTING GAS METHANE(C-1 i ETHANE(C-2) PROPANE(C-3) BUTANE(C.4) PENT AN E(C-5) HYDROCARBONSHO~ INTERVAL Page I of I DAILY WELLSITE REPORT J:I ~: lJ(~~ (~; T-T lib..... - ~....... ",,--," '-,J ~ _or...... DEPTH 8200 YESTERDAY 8200 PRESENT OPERATION= Lmer/Cement 24 Hour Footage 0 AZIMUTH VERTICAL DEPTH HOURS CONDITION T/B/C REASON PULLED AVERAGE CURRENT AVG ft/hr amps Klbs RPM psi Gels 31416 10.40 CL- 13000 40 pH Ca+ CCI HIGH LOW AVERAGE J2 @ 8200 12 @ 8200 0 TRIP GAS= 2ì03u 0 @ 0 0 @ 0 0 WIPER GAS= 0 CHROMATOGRAPHY~pm) SURVEY= 0 2061 @ 8200 2061 @ 8200 0 CONNECTION GAS HIGH= 0 385 @ 8200 385 @ 8200 0 AVG= 0 257 @ 8200 257 @ 8200 0 CURRENT 0 128 @ 8200 128 @ 8200 0 CURRENT BACKGROUND/AVG NIA 42 @ 8200 42 @ 8200 0 LlTHOLOGY/R EMAR KS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Claystone 30%, Shale 20%, Smsto.ne 5.0% DAILY ACTIVITY SUMMARY POOH. Run Sidewall Cores. POOH. Run 4.5" Liner. Circ IBtms Up (889u @ 5200'. 2703u @ Shoe) Epoch Personel On Board= 2 Report by. Bob Nichol Daily Cost 2540 tìle://D:\Morn¡ng~/o20Reports\20020323. htm 4/:26/1002 ALASKA OIL AlWD GAS CONSERVATION COMMISSION Paul ~1azzolini Drilling Team Leader Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510-0360 :,} !Æ~!Æ~~~!Æ ¡ / / TONY KNOWLES, GOVERNOR ~~!Æ~E 333 W. T" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501 -3539 PHONE (907) 279- 1 433 FAX (907) 276-7542 Re: NPRA Lookout #2 Phillips Alaska, Inc. Permit No: 202-027 Sur. Loc. 1387' FNL. 1399' FEL, Sec. 25, TlIN-R02E, UM Btmhole Loc.1312' FNL, 1399' FEL, Sec 25, TI1N-R02E, UM Dear Mr. Mazzolini: Enclosed is the approved application for pennit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies. and does not authorize conducting drilling operations until all other required pennitting determinations are made. A weekly status repon 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. An 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. In accordance with 20 MC 25.005(f). all records, data and logs acquired for the pilot hole must be clearly differentiated in both name Lookout 2PH and API number 50-103-20410-70 from records, data and logs acquired for well Lookout 2 (50-103-20410-00), Annular disposal has not been requested as pan of the Pennit to Drill application for NPRA Lookout #2. Blowout prevention equipment (BOPE) must be tested in accordance \vith 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ('- ~, . ~I l£'¡.I!A'h- ¡J; i..,~ L~-l.. ":' - - /) ~ Cammyhechsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 22nd day of February, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a Type of work' 1b Type of well Exploratory D Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone D 5 Datum elevation (DF or KB) GL 40 & 35' RKB feet 6 Property Designation AA0818191 AK5164 Dnll D Rednll 0 Re.entry DDeepen 0 2. Name of Operator Phillips Alaska, Inc. 3, Address P.O. Box 100360 Anchorage. AK 99510-0360 4. Location of well at surface / 1387' FNL. 1399' FEL Sec. 25. T11 N-R02E. UM At top of prod~tlve Interval 1312' FNL. 1399' FEL. Sec. 25. T11N-R02E. UM At total depth 1312' FNL. 1399' FEL. Sec 25. T11 N-R02E. UM 12. Distance to nearest property line 13. Distance to nearest well 1399 @ TD feet Lookout #1. 1.1 miles 16. To be completed for deviated wells Kickoff depth: 6000 MD 18. Casing program size 7. UM or property Name Exploration NPRA 8. Well number Lookout #2 9. Approximate spud date ./ February 25. 2002 14. Number of acres in property 5756 ~(~~ ~ -zfu{D ,JM/1 -¿.( ¿lIt Zr Development 011 0 Multiple Zone 0 10. Field and Pool Exploration 11. Type Bond I:,ee 20 AAC 25 0251 Statewide Number #59-52-180 Amount $200.000 15. Proposed depth ¡MD ana TVDi 8279 ' MD I 8275 ' TVD Maximum hole angle 10.1 ù 17. Anticipated pressure Isa€' 20 AAC 25035 ,e1l211 Maximum surface 2154 pSlg At total depth (TVD) 3850 psig Setting Depth Top Bottom TVD 115' 3265' 7835 8275 Hole 24" 12.25" 8.5" 6.125" Casing 16" 9.625" 7" 4-1/2" SpeCificationS Grade Coupling B PEB L-80 BTC L -80 BTC L-80 BTC Length 80' 3230 7804 590 MD Surface Surf. Surf. 7689 TVD Surf. Surf. Surf. 7685 MD 115' 3265' 7839 8279 We'ght 63# 40# 26# 12.6# 19. To be completed for Redrill. Re-entry, and Deepen Opera lions. Present well condition summary Total Depth: teet teet Plugs (measured) measured true vertical Effective Depth: measured true vertical teet feet Junk (measured) Casing Conductor Surface Production Length Size Cemented Measured depth Perforation depth: measured true vertical Quantity of Cement (,Include stage data) 200 sx AS I 470 sx AS III Lite & 170 sx Class G 170 sx Class G+ additives 120 sx Class G+ additives True Vertical depth RECEIVED JAN 1 1 2002 Alaska Oil & Gas Cons, Commission Anchorage 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Dlverter Sketch 0 Drilling program D Drilling flUid program DTlme vs depth plot Œ):¡efraction analysIs DSeabed report 020 AAC 25.050 requirements 0 21. I hereby certify that the loregoing IS true d correct to the best ot my knowledge Questions? CallI om Brassfield 265-6377 J'JlA- I r[~(),;wÁ./A1.Q.t~dl,.",,' . J "ltil'()¿ S'gne ,- r- 'P' Title: 0,,//1(10} Team L¿.ader Date I Commission Use Only Permit Number I API number . s / D 00 Approval date I) ~ 0. 6 f) ;2...02- -Dz7 50- /D3-- 2D...,Z - .]\ V~'1' (/\ Conditions of approval Samples required [8j Yes 0 No Mud log reqUired Hydrogen sulfide measures n Yes 00 No Dlreclional survey reqwred Required working pressure tor BOPE D2M; 0 3M; 0 5M; 0 10M; 0 Other: Tes t ßO V E 1-0 2)';00 p~'. ~0- I~,\-\u\ \;5C),Y'~S~ ~SDC()V~\~~'1 Origin~1 ~io.nert R.v CommiSSioner Cammy Oechsli ~Yes 0 Approved by by order of the commiSSion T.IR see cover letter for other requirements ~Yes U No 0 No Date ~ fÀ~ 0 ~ OJr(~~~'A , J I /I :., I "4 - ,. II J 'W' Submit in triplicate Form 10-401 Rev. 12/1/85. Phillips Alaska, Inc. ( Drill and Case Plan for Lookout #2 General Procedure: v' \ \ \U¿ \'f \4\ 1. MIRU Nabors 18E over pre-installed 16" conductor casing. Weld landing ring on conductor. ./" 2. Install diverter & function test same. Notify regulatory agencies 48 hours prior to test. ./ 3. Spud well and drill 12 1/4" hole to the surface casing point at 3265' MD/3265' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. ./ 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. . Employ lightweight permafrost cement lead slurry and Dowell LiteCrete high compressive, lightweight tail slurry to assure cement returns to the surface in a one-stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. ./ 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test 7. Make up 8 '/2" bit and BHA and RIH)o top of float equipment . Pressure test casing to 3000 psi for 30 minutes . Record results and fax to town 8. Drill float equipment and approximately 20' of new hole . Perform LOT (or FIT if gradient reaches 16 pp( equivalent) Record results and fax to town .;/ 9. Drill 81/2" pilot hole wellbore to j:8275' MD/j:8275' WD. Run MWD I LWD logging tools in drill string as required for directional monitoring and formation data gathering. 10. TOOH and LD BHA. RIH and set abandonment plug(s) as required by applicable regulations. If additional geologic evaluation is required (cores), RIH wi OE drill pipe and set sidetrack plug to 6000' MD 16000' TVD. 11. After setting sidetrack plug, WOe. RIH with 8'/2" drilling assembly and twin well to top of J4/UCU. Run MWD I LWD logging tools in drill string as required for directional monitoring and to properly identify objective top. 12. Run 7" intermediate string to/ isolate potentially sensitive shales log¡ted just above the objective (est.@ 7839' MD / 7835' TVD). Cement casing to bring cement j:800' above 7" shoe. 13. Make up 6 1/8" mill tooth bit}md BHA and RIH to top of float equipment . Pressure test casing to 3000 psi for 30 minutes . Record results and fax to town 14. Drill float equipment, CCM, displace to coring fluid and TOOH. (LOT is not planned for this casing string - see attached explanation). 15. PU core barrel, RIH and core at least one 60' core. TOOH, LD core barrel and PU 6-1/8" bit and drilling assembly and TIH. 16. Drill twinned wellbore to j:8279' MD / .:!:8275' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. . Condition hole and mud for e-line logs. 17. Log 6-1/8" wellbore as ~cessary. 18. Run and cement 4 1/2" 12.6# L80 EUE Liner 19. Make a cleanout run with bit and scrapers . Displace to filtered seawater ./ . Pressure test well to 3000 psi for 30 minutes . Record results and fax to town 0 ;, ; fi A- Phillips Alaska, Inc. ~ 20. Run and land 3-1/2" or 4 1/2" tubing with gas lift completion 21. Nipple down BOP's. Install production tree and pressure test same to 5000 psi. 22. Secure well, release rig. 23. MI well testing equipment and surface test tanks. Perform production tests as required. Produced fluids will be either reinjected into the formation or trucked to Kuparuk or Alpine production facilities. 24. Upon completion of testing or if the well is not completed, plug and abandon the well per applicable regulations. Thoroughly clean location and block off further ice road access to location. 01/G,NÞ- Phillips Alaska, Inc. ~ DRilliNG FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRilliNG AREA RISKS lookout #2 Drillina Fluid Properties: Spud to surface casing point Density PV YP Funnel Vis Initial Gel 10 Minute Gel API Filtrate pH % Solids 9.5 - 10.2 ppg / 16 - 26 25 - 35 50 - 100 10 - 20 15 - 40 7 - 15 9.5 - 10 :I: 10% Drill out to TD (pilot & Intermediate hole) 9.5 - 11.0 ppg ,/ 6 - 20 5 - 20 35 - 50 2-6 14 - 20 < 6 below 7000' 9.0 - 10 < 11 % Twinned Hole (Intermediate shoe to TD) 9.1 - 9.4 ppg ,- 8 -12 12 - 20 40 - 50 8 - 12 12 - 16 <10 9.0 - 10.0 < 8% Drilline: Fluid System: Equipment list for Nabors ISE should be on file wirh AOGCC. Drilling fluid practices will be in accordance with the regulations stated in 20 MC 25.033. Maximum Anticipated Sulface Pressure and Casina Desian: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Casing Size 16" 9-5/8" 7" 4-1/2'''' Casing Setting Depth 115' MD / 115' TVD 3265' MD / 3265' TVD 7839' MD / 7835' TVD 8279' MD / 8275' lVD Fracture Gradient 11.0 ppg 14.8 ppg 17.6 ppg 17.6 ppg Expected'Maximum Mud Weights: Pore Pressure Gradient 8.33 8.33 9.0 ppg 9.0 ppg 12-1/4" surface hole to 3265' MD / 3265' TVD: 10.2 ppg Pore Pressure 35 1380 3650 3850 MASP Drilling NA 53 psi 2154 psi 2940 psi ./" 8-1/2" pilot hole to 8275' MD / 8275' lVD: 11.0 ppg (for shale stabilization) 8-1/2" Intermediate Twinned hole to 7839' MD / 7835' lVD: 11.0 ppg (for shale stabilization) 6-1/8" Production Hole to 8279' MD / 8275' TVD: 9.4 ppg O='G ,Vl- ;i '( Phillips Alaska, Inc. ( 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) formation 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 FG = 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' TVD) D = True vertical depth to casing seat in ft from RKB OR 2) MASP = FPP - (0.11 x D) Where: FPP = Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 16" Conductor Casing MASP = [(FG x 0.052) - 0.11] x D = [(11.0 x 0.052) - 0.11] x 115' = 53 psi OR MASP = FPP - (0.11 x D) = 1380 - (0.11 x 3265') = 1021 psi 2. Drilling below 9-5/8" Surface Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(14.8 x 0.052) - 0.11] x 3265' MASP = 2154 psi OR MASP = FPP - (0.11 x D) = 3850 - (0.11 x 8275') = 2940 psi 3. Drilling below 8-1/2" Intermediate Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(17.6 x 0.052) - 0.11] x 7835' MASP = 6309 psi OR MASP = FPP - (0.11 x D) = 3850 - (0)1 x 8275') = 2940 psi f , , 1. , ' ,'j :' V' .: ~' .. ~ ¡ ¡ \J A /... Phillips Alaska, Inc. Casing Design Performance Properties Size Internal Tensile Strength Weight Grade Connection Yield Collapse 16" 63 ppf B PEB Conductor Casing Joint Body 9-5/8" 40 ppf L-80 BTC 5750 psi 3090 979 M 916 M 7" 26 ppf L-80 BTC -M 7240 psi 5410 667 M 519 M 4-1/2" 12.6 ppf L-80 BTC 8430 psi 7500 psi 304 M 267 M 9-5/8" @ 3265' MD RKB Casing Setting Depth Rational: 16" @ 115' MD RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling pilot hole and twinned well bore into reservoir. Intermediate casing is set strictly to provide isolation of potentially troublesome shales. Because the objective interval will be pre-drilled in the pilot hole at a higher mud weight than what is targeted below the 7", a leak off test will not be done below this shoe. The shoe of this casing will be set immediately into the top of the objective with a planned core to be taken immediately below the 7" shoe. A LOT would require 20' of additional hole to be drilled and would jeopardize targeted core recovery. 7" @ 7839' MD RKB Well Proximity Risks: None Drillina Area Risks: Shallow Hazards: See attached explanation Drilling Risks: Drilling risks in the lookout #2 area are surface interval clays, intermediate interval sloughing shales, and lost circulation/breathing potential through the reservoir. Surface clay problems will be counteracted with fluid chemistry and rheology. Shale stability will be controlled while drilling with fluid chemistry, rheology, hydraulics and fluid density. Lost circulation will be addressed with lost circulation material (LCM) and managed flowrates. See attached mud weight versus depth graph for the offset wells Lookout #1, ARCO Spark #lA, Rendezvous "A", and Rendezvous #2. Annular Pumpina Operations: 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 Lookout #2 surface/intermediate casing annulus will be filled with diesel after setting intermediate casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. ./' PAl may request approval to inject or dispose of fluids in the Lookout #2 9-5/8" x 7" annulus at a later date. This request would be made after sufficient data is available to meet the requirements of AOGCC's 20 MC 25.080. C r:'G';)- Geoloay: Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows: FORMATION DEPTH (55) UNCERTAINTY POSSIBLE FLUID EST. PORE TYPE PRESSURE. psi 338 1435 1690 1770 1890 2790 2940 2970 3340 3650 Permafrost K3 Sequence 97 Sequence 96 Sequence 95 Sequence 93t Base Turbidites Disturbed/Pebble Shale LCU Top Jurassic Base J4 Silt Distal Nuiqsut Marker TD Phillips Alaska, Inc. 780' 3335' 3910' 4080' 4360' 6205' 6530' 6600' 7270' 7760' 150' 100' 100' 100' 100' 100' 150' 150' 100' 100' Possible Oil or Gas Possible Oil or Gas Probable Oil and/or Gas 7880' 7920' 8200' 100' 100' 3700 3725 3850 ~, Formation Evaluation: Anticipated logging, coring and testing for this well is as follows: I. Logging Surface Interval (0 - Surface Casing setting depth) LWD: GR/Res/Dipole Sonic 8-1/2" Pilot Hole (Surface Casing setting depth to TD) LWD: GR/Res/Density/Neutron/Dipole Sonic 8-1/2" Twinned Well (Top HRZ - Top J4/UJU) LWD: GR/Resistivity 6-1/8" Twinned Well (7" Shoe to TD) LWD: GR/Res Wireline: GR/Res/PEX/Dipole Sonic/CMR (Contingency: MDT/RSWC) Cori ng Full Diameter 2.5" Core in Upper Jurassic (1 - 2, 60' cores) Potential Rotary Sidewall Cores (wireline conveyed) in the event full core operations are u nsuccessfu I II. Mudlogging Mudlogging service should be in operation from the base of the surface conductor casing to TO. Service most likely will include ROP on 5' intervals, lithology, total gas, sample collection, gas analysis of cuttings, gas chromatography, and H2S detection Sixty-foot (60') wet and dry samples will be collected from surface to 4500' subsea III. 0= G I A- Phillips Alaska, Inc. Thirty-foot (30') wet and dry samples will be collected from 4500' subsea to well TD (pilot and twin) and ten-foot (10') wet and dry samples, or continuous, collected across the Kuparuk and Jurassic intervals. IV. Flow Testing Flow testing and pressure build-up tests will be used to determine formation properties and estimate the commerciality of this exploratory well. Flow testing for any particular interval will consist of an initial unstimulated flow period followed by an appropriate pressure build-up. The flow period will be determined on-site in response to analysis of initial flow period, PBU and fluid properties. The well will be flowed to temporary surface production facilities consisting of gas separation and fluid storage tanks. Produced fluids will either be trucked to an existing production facility or reinjected into the formation following completion of the flow testing operations. Based upon pressure and flow characteristics during the unstimulated flow period, a reservoir stimulation may be performed in the form of an acid or frac treatment followed by a second flow test and pressure build-up. Additional prospective intervals may be tested as described above or may be commingled with the previously tested intervals. If commingling is chosen, production logging will be performed during the flow test to determine the productivity of the individual zones. c~rGIP¿~L Phillips Alaska, Inc. loolkout #2 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 1,2-1/4" Hole I 9-5/8" Casina Interval Event Gas Hydrates Risk Level Low Clay Balling Medium Abnormal Pressure in Surface Formations Lost Circulation Low Medium 8-1/211 & 6-118" Hole Event Lost circulation Risk Level High) / Hole swabbing on trips Low Directional Control Medium Sloughing Shale, Tight Hole Medium Abnormal Reservoir Pressure Hydrogen Sulfide gas Low Low M itiqation Strateqy Monitor well at base of permafrost, increased mud weight, managed fluid rheologies, decreased circulating times, controlled drilling rates, low mud tem peratu res Maintain planned mud parameters, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP. Diverter drills, increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries, port collar, controlled runninq speeds. Mitiqation Strateqy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Pre- planned LCM pills, lost circulation material. Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, weiqhted sweeps. BHA design, on-sight geologic review and advisement of potential slump blocks. Increased mud density and fluid composition according to plan, controlled trip speeds, sweeps, ECD monitorinq. Well control drills, increased mud weight, continqencies for top set casinq strinq. H2S drills, detection systems, alarms, standard well control practices, mud scavenqers C ., ~ r,,\ f . J 8J I h': ~; ! : ~.'~II- --. ...- Q) Q) ...... ......... ...c ...- Cl. Q) 0 0 () ...- I..... Q) > Q) .18(.,) - ~ I..... I- .;.00 - .;.Coü - 3úCo - 12D0 - 1 f,ûÙ - ¿Jor) - ::'4Ü'; - ;:80,) - .!.2Ü') - 9 'S., b ~.601:' - .¡::¡oc. - .¡..¡['Ù - ~ ::CI~I- t.6C.) - 6~C":' - f.,4CIj - t,8C(' - - 20,j - 760,:' - Co - tst R~'B tle'¡QI;c,r,' -S' -phühps I structure: Lookou t # 2 Field: [xploration Permair"s. " CS9Ft JJ IS==luera.:c:: 97 r. :.o::-qLJerl~~ 96 5~':¡U~I~I'=e Çt: ... I~ I 1:1':1' \," 'J t 1 I...~r.." For: T Brassfil-Id I)Qlð ¡:...'jl re'J , ;' - úør. . ;O,j ~ I"; ur "QI....n,:(. ,PI LoOI,C .~r.~2 ~ I' ¡"fl. "1. ::J:,.Q,":llI,. (¡re. Ir, II!lt ,.lor8"':-8 &'e.1 I'. T'...o ~'l.:o:.l ÚC..:,II'",' '1'0 ,'o,....,.¡¡.e (l"ac~rs'1jt~J 11AI(IR HUGHI&S __LNTLQ ---- EstirnatÐd :;1.lI~F,~C: LOC.4n:'f.l: 1,:E,;' nJL, 1 ~,99' FEL SlC. 25. ilJ.!i.:_E2E., lIf" .~ 3 .' 1 :C' it t :..J ':'n~le I)r(,p L':U ~ Co L':IJ - TGí - -: -ur:¡~~,c JoL -CI-T, Jur(]:",~,c-~ (:-::'~Pt n""IOI r~LI"__;u.i:' ~41.1..~ ~ B,' ..I"¡ ~. I: 1:\')0,:'- L. . > .' D,~tJ' r'JJ ~'5Lo', h,'kr 8.1(0 - ó~cc' 800 ìC :~ -:=?,C' 4('0 I) ~ :': Vertical Section (feet) -) .:1ÜI: A~irn..th 0.00 ..;Ih reference 0 ÙO N Ù.OC E fro." SlOT //1 .... I I ~~: asca, ,-- Irice Well: Lookout Location: Nodh Slope, Alaska sea,] - 6(00 - 6120 - 6240 - 6.?EO - i:,~eo - 6~CÜ - i:,"'2') - .......... ëij Q) 6t'4!j - - -..- ...c c.. t.~6')- Q) 0 0 7( eo) - ü .... Q) 72CcJ - > Q) :J "';' ~21:' - .... ~ - 44'J - -::to - 7Eeo - 7ëC,.j - 7920 - e.C40 - 51ëO Ò 2 ~oj rn ,/ - , ~ PHilliPS "".~ (lIB'';', :~l' I ~ ~, J " ,~ ~ , ~~" KOP - S;aetrack Pt 3.00 DLS; .3.00 deg per 100 it , 6.00 0\ 900 Sequer,ce 93t End Anqle BUIld 10.00 Beg;n Angle Drop 8.00 Sequen.::e 93t BI Turb;a,tes P",CDle/SnCJle Leu" ;'3T - T/ Juross;, B'" J4 SoIt 0 D,stal Nu;Q=.ut Ml(r iCJ 8':CO .3¿O 2010 12ü Verlical Section (feet) -> (0 120 .360 4~( 6.00 DLS: 2.00 .::leg ¡:,er II)I) It "OF' - ::d-:lrO:k Ft ~c.-'.~~ S~"~:':I~~~09~~C; pe;r ~eQ..Jt:n(¿ ~3[ \ lJ(J . - . E~'d ~'lqle 8'J~.j E. O'J :'':9 r ,.r'g'¿ - rc~, e. Ü(i e, ïurc'a;t",:. Þ~a~'~:,~f~~~~ ~ ~ 4- ':'(; P,~I:bIE Shale 2.('(1 8/ Turbidites 4.00 PeCDle/Snale 2.00 Ena Angle Drop LCU .JJ TGT - T/ Jurassic - 7 CsqPt B/ J4 Sdt O;stal Nu;Qsut Mkr "=3 ïD 240 AzImuth 0.00 wl1h refarence 0.00 N. 0.00 E from slot 111 0 ~ . .<IIi, ! "'J 1 1 rj' ¡ u i I~' t~ I.. I-c.~'ül'd-~, I""'" - - - - --P';r' -T - [lrRElElfiplri: l":J't ~>:1l1t,' ' 'l-L't, -2(>.1' I fl't(.1 n~lc'C''''.;e I! l:"':'~':"~"2 ':.1" ...~~ '1 : I (WI.,] r'ul6. (j'1iI' ,.-, 1"1 IEI'.,.''':8 0'c,1 , I ¡"U' "."or,' úe.,'" c.'. '.'.;ait_li'" (""",....W'BE) 1- fÑT~1 I I ~--- Plliliips Alaska, Irl(~. __I Structure: Lookout #2 Well: Lookout i _Field: Exploration Location: North Slope. Alaskal ./ "' ~- PHlllIPS)Þ -=----¡ - ~11, c:::::-::=.=....::...=.o::::::=..=.= = P R ()~ [ LE ;,F\,. {-=-\ t~ /¡1~ r~ ¡, ;-- h, r T (,,=l' t--=} ~\lJ J"'\/!- ~ ] '\..1, '_I r~- \' i~ =! f~, L)) l~.. ¡.l i" --" L~ ' M. 0::::::== = c:::::== ----- Poi r1 L ----- MD inc Di( TVD North EosL \./'. Sect Deij,/ 'J -' f<OP - ::~ i d p t r (1 c k Pt 6000.00 0.00 0.00 6000.00 0.00 0.00 0.00 0.00 ~',cqucncc 9.3t. 6281.01 '::.).4j 0.00 6280.00 20.64 0.00 20.64 j.UÜ I End l-\nqle Build 6335.4 7 :0.06 0,00 6.3j.3.75 29.jS¡ 0.00 2SL39 ,3.00 Begi( Angle Drop 6344.23 10.06 0.00 6342.33 JO.J2 0.00 30.92 CJ.OO 8/' I Turbidites 6609.17 4.77 0.00 6605.00 65.10 0.00 65.10 2.00 Pebble/Shale 6679.34 3..36 0,00 6675.00 70.07 0,00 70.07 2,00 End A,ngle Drop 6847.44 0.00 0.00 6843.00 75.00 0.00 75.00 7:ûO LCU 7349.44 0,00 0.00 7.345.00 75.00 0.00 75.00 0.00 S?¡ TGT - T/ Jurassic- 7 Cs 7839.44 0.00 0.00 7835.00 75.00 0.00 75.00 0.00 -.J¡. ~ .: ~ ~~"'1' 1 G'~ :B/ 7959.44 0.00 0.00 7955.00 75.00 0.00 75,00 I J4 Silt O,OO¡ -==.- ~.¿"'- g.:,.- 'Distal [\J u i q ':' I) t. fvikr 7999.44 0,00 0,00 7S~9,~J.OO 75.00 0,00 75.00 O.C)O ..... '-:..-. " a---- II~I ë'L7(~).44 0.00 D.DO 8275.00 75.00 (), 00 7:L 00 0.00: -- ---- - - - - - ----- ------- -------- -- --- ---------- - ------ --- --- ----- nn --- -- --------- ---- 'C'eo1rJ r" ¡\Y'U For' T BraBBfleld' ---- -- - --- -- ------ n- \:,:,..;.. ~ ".utEr..; "jrð .r. fee" rc,'tl'flr..:e "'...1 'I I I,,"" \'., U.' r.... It.. ,,'. "'.,'R"i. FI<n ('''r.-..., I BE) I BAKER IIUOI8I INn:'Q Phiilips Alasl-<a, Inco , I Well: Lookout I Location: North Slope, Alaska¡ (""t o"'".~ '2 - Dt., - 2(~1' P.c.1 pr.'tltr..:.e .~ L()(II":,,,,. ~l '''trs..,]n II Structure: Lookout # 2 Field: Exploration = 0::::== -- =-==- [C) QI (=')1 I~ I. 11 11- r r:,~ '.=P J ~= IL (='~ (~ìl ~\ A ~\. ¡:~ ~ [\,:, ~ T ';....=,ù ',\,~"';' ~ '~: ~ ~.V 1 ll~ !¡ '\1J ~ ----- f--'oint ----- fv1D Inc Dir- TVD 1-) e r rn a fro s t d:,j.OO Û.OO C~.O() 0355.00 9 ~,/8 CsqPt 32135.00 0.00 0.00 ~,265.00 1'-' 3 3410.00 0.00 0.00 '::5410.00 Sequence 97 3985.00 0.00 0.00 J98~,.DO Sequence 96 41~)5.CJO 0.00 0.00 4 1 5~),00 Sequence 95 4435.00 O.OÙ 0.00 4435.00 Sequence 9.3t 6280.00 0,00 0,00 6280.00 B/ Turbidites 6605.00 CLOD 0,00 6605.00 Pebble/Shale 6675.00 0.00 0.00 6675.00 LCU 7345.00 0.00 0,00 7345.00 C' - _. TGT - T/ Jurassic 7835.00 0.00 0.00 7835.00 ~~ 8/ J4 Silt 7955.00 0.00 0.00 7955.00 -. 8::--::- 'Distol r\J u i q s u t 7995.00 0.00 0.00 7995.00 ..... Mkr Do : ~'T[) 827~j.O() 0.00 0.00 327~,.OO - ----- ---- -- - - ----- r '\, ,(,::~" ~ ¡,~\\ I II ~/~. ~l ~, lh,,/ t~=\ I //==\" r\ 0 r t h EIJst. CJ.OO 0.00 0.00 0.00 Cì.OO 0,00 0.00 0.00 0,00 0,00 0.00 Q,CJO 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 ....... ......... ..... .I (' PHilliPS ~ r~J' '~ ~ I == == I v. Sect Deg/1 or '- 0.00 0 I-In .v'-' 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 CL ° (J 0,00 0,00 0,00 0.00 o.O( 0.00 0.00 0.00 0.001 i 0.00 0.001 0.00 0.00: ; 0.00 0.00 0.00 0.00 0.00 ______n____-_------------ ---- --- - --- O.CJO, F'hi1.1ir.',:: .;1"=1-:,,. In.:. L,:,e,ke'Llt ~¿ L':":'¡,':JU t ::, 1 ':' t ~ 1 E:.:p 1,:, r ,::. t i,:,n [J,:,t:l:h ~,1,:'¡:"=, ,;1.:.=:1':" P F ':' p ,:.. ~ .; L L I :: T I J J ,:; t'i' b.:. J.:oõ:r i-iu;rh€:Z IJlT E..:,' ':':'ur roõ:f : L':":'K.':"..II:~:: :t~l '.'€:rz. n '~"J r r €: f : p rq:.,5 ('1;' Li,:""n::€: : [o"I:€: prinl:""d : 12 -[o€:,;:-::':'('l [',,1:0::, cr"".:.co::,d : l.~'-['€:c-::(,,)1. 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[I Ü (II) E t) 1.,j(, ÜÜ 3 ('1) (I ' " -' €.(, ~ ~ ~5 ~ ¿.~ [ (I ')1) E tj 2 (1(1 O'~' 6 (1) I) (II ' ';,1 ~'" 6~ 11) .1 t) !i .:1 I)tj E r:.: ?l ,) 1 0 .1 J I) (It '='0&: ~Ü 1)':' :' , ';'.1 [ Ü II) E t5 j (1(1 ' " I .~ II) (, (II 6:' 9 '? 7 - :~ :,1 [j ':1 II) E ¿. J j c .' 1(, "'6 ':' II) .; 333 -, ¡:;; ."-1 39 [ I:' I) (I E tj j.1' 23 1 (, I~, (I ,)(1 ¿ ::'.1:: ~ ~ (I ~ - II I) I) (, E ¿. ?. .1.1 1') '" I~ ':'(1 .:?,.1 5 5~ 31 .j [J I) (I,) E ¿'..j.1 '.1 ? ' '' ' (I 1:11) .;,...j.1 ~. Ü .J 12 I) (I (II) E ':,5.1 ' .1 ' 6 ' " (I II) 6::,.1 3 55 s.~ 1 Ii (I (II) E ¿, ¿ I) " I' . -" (I I:'LI ¿:6.:15 1:lj r:.5 1(1 [ Ü (II) E t5. ¿,~" ..1 .1 r)l) (I (II ' ¿,¿,. ~ 16 1"', ,- :I~' [i (I (1) E ¿ .; :"~ ~ . ., j¿' ÜI) ~, 6 -, ~ 1)(1 " -' ,-, Ii ' (II) E .;. '''¡ .''¡ .: r) (I ':1 (II ' o:'~'. 3 ,) - - :. <'.' [ ':' (,(I E t, :,"¡ ."¡ ':' II) (II ¿, oj.1 ~ (1(1 'c: " ' )1 ':' I~I (I E "'" 1:11)(1 '" II) (II ~,99~, ~.r, 'c ('1: [j .:1 0') E , ?..¡~ ...¡ I~I II) I) I~' -, 3.J5 (8(1 -, 5 (II:' [I .:' IÜ E .., :,':1 (I (II) Ü I:") ,(, ~ ~ '~5 5t: -;'5 (It , Ii .:' .:' (, E -: :~.~ ...¡ ' '' ' I I) I~I ~ ?:: 5 (1(1 ~.: (, I II I:' 11:, E ~ '~59 .. '" (I .)(1 ~55 (, (I -, ¡:;; (1(1 [] I:' 1:'(1 E ~ '~'j'~ .. r) " I) 1(1 ~'?5 (I (I ~c: (II [ (I 1:'(1 E ~ 1)1 '1:1 ÜÜ I) 1.:1 (. I~IÜ : j ~5 ::¿ -, ~ Üe. [I 'j I:' (I E 8~"~ ..j (. ' " I) I') ~:: : c (I.:, ,.~ (1(1 Ij I) (. (, E [',:,;¡l~g ['eo;¡ 1(1(, fc (I . ':' (, j . ':11) j . I~I') ? . I:' .:' ~ . 1:'1:1 ? . t)Ü Ü . (II) '::.ÜÜ 2.(1(1 ,¿ . (8(1 2. .).) :. . (, I) 2.1:'1) 2.1:1.) .2 .Ijl) Ü.I)I:, (1.1)(1 (I. (II) (I. tJl) Ü . 1)1) 0.(8(1 Ü. (1(1 .) . (II) N'~'P'~'.:.~.L LIST II)'; l?a9-=- 1 lour ref: L00koucn: 5c#1 ~.~rs. #1 L:;,sl: re":ised : 1:-D~c-::(lOl ".',= rt :e,,;t 0.(1(1 ~0P - Sl.j¿,cr:;,c~ Pt ~ . ¿,i:' 1 (, . ..¡.;. 20.6.1 ~~q~en~e 93c 23.51 29.?9 End hngle Bul.ld 30.~2 B¿,gin Angle Drop j 1. "¡.3 ..¡ -;' . 1';:' ':,? . ~ 1 ¿ ':' . 1 (I E f.? . (I~' Tu.rt,Ldl.te.s -'(1.(,-' -, 3. j S pa,t,le .:h:de -5. (II) En oj .~ 1191-= C' r .:'[:' -;, 5. (II) - 5. (I') LCU '5. (II) - '~ . (II; -y '3. (1(' TGT-T Jur:;,ææic-"CsgPe E J"¡ .:i.lc -'S.üt) Dlst,:;,l !¡'Úqsul: [lkr 75.0':1 -:' ~I . r) I~I T D All dae:;, IS In feee unless 0cher~ise seaced fr,:,m slot nl .:lnd T'lD fr.:,¡n Ese p¡.~E'. dJat,(.rsnl?EI 1~5.("j Fe ab.:,".'~ ['I~:;,n Sea E0ccom hole dlscance is 75.0(1 0n a:lmuth O.GO degre¿,s fr0m wellh¿,:;,d TOl:al D0g1eg for we1.1pach is 20.13 d¿,grees. ~erel.c31 secl:ion 13 from we1.1he3d 0n 3:imuch 0.00 de9rees. Calculaeion ~ses ehe mlnlm~m cur~:;,c~r¿, m~ehod. I?resent~d b:,' Baf:er Hu,;¡h~s IfJTE':' Cc..:, rd 1 na C~.5 Le":el) . U ; í ¡ ï.,'¡ ; i . j J' ~ L pr,llll.p= þ,l::'¿,k::', Inc. L00k0~e ~2,Lo~~~uc E:.:ple,r.:.l:l,:,n, [J.:,rch .: 1 :'f-'e, ';1 ::'.n:.:. rID Rect.:.ngul~r Coords. ----------------------------------------------------------------------------------------------------------- T" .' [0 6(11')1:1 (1(1 ¿.Ü(,(, II) " -' j .;.'::~l (11 ;:. ~I ' ( (1(1 ::1 ¿,..¡ II ¿. ", j5 ..¡ -, 63 j ~~ ~. 9 ? Ij ¿.?"¡'¡ - 2 63"¡'-: j ? ~. I:' ';' - II ¿.~,.):.., 1-' ¿.~,Ü5 1(1 I""J ':,. 1 (, [] ¿.67~ .?"¡ ¿.r5"'S I:' I 1 '(1 0'" II ¿, ,?..¡ -, .¡.¡ r;: ~..¡ 1 ell ~r: (1(1 II -, j'¡~ '¡"¡ -, :'..¡ ~ (II:' ~s 1(1 [j - j '? ,¡..¡ 7,! j.:: (II 7S II) Ii ~'~5~ "¡'¡ -";'55 Ot) r:IO II 7~9~ '¡'¡ -: ~ ~:' (It:' -, .:: I (I [j ~.: - St .¡.¡ ~ '~ (II) -, r: II) Ii T,:,p I!D T ,:,p T'".'C' Pecl:~ng~lar Coordæ. 1:1. (10 E I:' . 1:1 r) E (. ':11) E (1.1)[' E (1.1:.,:1 E ü. (It:' E (1.0(1 E (I. (II) E (1.1)(1 E (¡. (1) E I). (1(1 E r:I.I)(1 £ PF':+:'::.;L LI~TTli'':; E'::.,:!.:- '¡":"Jr rei' : L,:,..':,k':"JCIl2 ::I:~l ','¿rs. ~1 La.: t r.:"i¿.:d : 12 -D¿,;:-.'>:":'l '::'ffiITL¿-nCZ in '....¿ll¡:,::.cr, -------------------- -------------------- (",,:,mmen c r:':'P - O:idetrac¡.: PI: So? ::¡uence 9 j r. End ,;r";ll¿ E.uild Eeg i n .~,n';¡ 1 ¿ ['r,:,p E Turbidi C.:-.:, Po:- t,t;, 1 e S" r,~ 1.:- End A.n,;¡l¿ C'r,:,p L':U IGT-r Jurassic-".CsgPt E J"¡ Silt ['isl::..1 Ilui,:¡.::~t: lH:r TD C~ælng posicions in sering '~' ------------------------------ ------------------------------ J?':'I: I1D E,:,c T',"D pect::.ngul::.r C~ord¡. ':~.::in.;:i n ::. rJ ,:¡ t) I)() I:' . 00 ~I)ÜI:. r)(I I) . ':1 1:1 [ J I:I.I:'Ü[¡ ----------------------------------------------------------------------------------------------------------- 5t 5 ~. ':,:a¿:ln,;. ~, C~¡ln';1 (I 00£ (I. r)ÜE n '::. -\?2.:;..'¡'¡ ¿'ÜOlj.I)I:' j' ~ ? :' . I) I:' I).O(IE (, . (l1~1 E (I. (1I)¡j -:' . (1(11 j Ii,:' T::.r9¿-t= a.::.:;,:..;:i::.tëd '..'ll:h t:ius ',,','ell¡:'Hh C ".~ " ", ~ {~ 1 cr I , '~ . ~i ¡ ~~ i ~ t,,' ;'. ~ ~ ~ ~~ ~ ) PH~LLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Lookout #2 Proposed Completion Schematic I ~ r ~ ~ l 4-112" FMC Gen V Tubing Hanger, 4-1/2" L-80 EUE8RD pin down ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 4-112" 12.6# L-80 EUE8RD Spaceout Pups as Required ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 4-1/2" 12.6# L-80 EUE8RD Tubing to Surface ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ EÐI ~ ~ ~ 4-1/2" Cameo 'X' nipple wI 3.813" profile set at +1- 500' MD. 4-112" x 6' L-80 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ EUE8RD pup installed above and below ~ ~ ~ ~ ~ ~ 16" 65# H-40 @ ...¿~ ~ ~ ~ ~ '- ~ ~ ~ +1- 115' MD ~ ~ ~ ~ ~ ~ ~ ~ 4-1/2" 12.6# L-80 EUE8RD tubing to landing nipple ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 4-112" x 1" Cameo 'KBG-2' mandrels wI DV's and RK latch, 6' L-80 handling pups ~ ~ ~ ~ ~ ~ ~ ~ installed above and below. Spaced out w/4-1I2", 12.6#/ft L-80 EUE8rd tubing as ~ ~ ~ ~ ~ ~ ~ ~ needed. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Depths are ~ ~ ~ ~ based on est ~ ~ ~ ~ ~ ~ ;;. ~ ~ rig RKB ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Surface csg, ~ ~ ~ ~ ~ ~ ~ ~ 9-5/8" 40.0# L-80 BTCM ~ ~ (+1- 3265' MD 13265' TVD) ~ ~ 4-1/2" X 1" Cameo 'KBG-2' mandrel wI shear valve and latch pinned for 3000 psi ~ ~ ~ ~ shear (casing to tubing differential), 6' L-80 handling pups installed above and ~ ~ ~ ~ below. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ lill) ~ ~ ~ ~ ~ ~ ~ ~ ~ 1 joint 4-112" 12.6# L-80 EUE8RD tubing ~ ~ ~ ~ ~ ~ 4-1/2" Cameo 'X' nipple wI 3.725" No-Go profile. 4-112" x 6' L-80 EUE8RD ~ - ~ ~ ~ handling pups installed above and below ~ ~ ~ ~ ~ ~ ~ ~ 1 jt 4-112" 12.6# L-80 EUE8RD tubing ~ ~ ~ ~ ~ ~ ~ ~ 5.125" X 4" Baker locator sub ~ j ~ .... 4-1/2" Baker GBH-22 casing seal assembly wI 12' stroke, 4-112" L-80 EUE8RD box up Intermediate csg. 7" 26.0# L-80 BTCM (+1- 7839' MD 17835' TVD) Production Lmer 4-112" 126# L-80 EUE8rd (+1- 8279' MD/8275' TVD) Liner Assembly (run on drillpice). Baker 7" x 5" 'ZXP' Liner Top Isolation Packer with HR profile Baker 7" x 5" 'Flex lock' Liner Hanger Baker 20' Seal Bore Extension XO Sub, 5" Stub Acme box x 4-112" EUE8rd pin 1 Jt 4-112" 12.6# L-80 EUE8rd liner as needed 4-112" Baker Landing Collar 1 jt 4-112" 12.6# L-80 EUE8rd tubing 4-1/2" Baker Float Collar 1 jt 4-112" 12.6# L-80 EUE8rd tubing 4-1/2" Baker Float Shoe ... .. 3-%" 9.3 ppf L-80 EUE rd may be substituted for the 4-%" 0 H it}¡°r.~~'1{ 16" Conductor Casing at 115' MD I RKB Base 01 permafrost 855' MD 9-5/8 ' Surface Casing at 3,265' MD Topol Cement at 7,000' MD 7" Intermediate Casing at 7.839' MD 4-1/2" Production Liner @ 7.689' MD to 8.279' MD Lookout #2 WELLBORE SCHEMATIC and CEMENT DESIGN J.~; ,I~ ,i .', ',' ":\ I ," ~ .~ ~. ~ '.... r ,\ ., ~: ~ '.; , " ~. . . '~.' II ~..... ~, '.'" ? ,. 11.1/01" HI " ., ", .'. L. " ~~ '~ 8-1/2" Hole " ~,: .:1 '. f~ ~ '. z2 ~ " . a, r - ,.. 'J~- -...-- '. ,'" .'1. ~~ ~...; ~ ~~ ~: .Ir" " ~1 " .t.,~ .' . . . J 6-1/8" Hole ... ~ Conductor Casing Size 1 Hole Size D",pln' Tc,p 01 C",rn",nr E~c.;.ss C"ICul"t.;.( VOlum.,. Calcul"t,onS: IT 1 5 II/ 1181 çtl 10785.1 cl'lll 10.93 cf ~x Slurry Volume: 181 cf Slurry We,gnt 15 7 PPg Slurry ",;;I( 0 93 cl 5X Surface Casing Stage 1: V,~lum", ,€<55 III 11.610111 Lead 12.070 cll Tall 1800 II) shoe Joint vol 34 ct + 1363 cl, ,03132 cl ii, ,03' 32 ct'll, '14.14 C1 S~I 103132 cf If/ 12 40 cl Sx) ) 16 ,n 20 nOle '15 MO RtŒ Su"ac", 100".. 12001" 181 çt 200sx or Arctic Set 1 200 sx rounded ""~e<,,ss 9-58 ,n 12-1 .1 hC,I", I::' 001"; 1,339 cr 11 4:'1 = 731 cr 466 sx 11451 = 363 ct 166 sx Sy~,.,.m Lead IArct'c SA.t 3 lit'" c",menl .. 9"" DJJ I~"CII + 3("'" D5319YPI ... 50'" D12J Ispn",rEoS'" 1.5"0 S1ICaCi;,I'" 1 5', 0;'9Ie'<1 1 + Ü .1'.0.16 \'J.;.lo"m.1 TaIlIL'leCr;;leo'l} 120 PPgl Lead Slurry Volume: 2.070 ct Slurry We.,gnt '07 Ppg Slurry y,eold 4.1.1 Cl sx Tnlc~E'nlng T,m;; 60.. nours Tall Slurry Volume: 363 cf Slurry We.,gnt '2.0 PPg Slurry y,el( 2.10 cl 5X Tn,eK.;,n,ng Tim;; 3 ::. . .1 5 nOurs Intermediate Casing Size 1 Hole Size D",ptn' Top 01 C;;ment E xces 5 C"lculal",d. BHT I SIalIC!. Vvlum~ arC'und 7 183911) 1186 cl, 10.T268 cl III 1 17 d s~1 shoe )Olnt vol 17 cf + Sy~l.,.m. ICI,,~s G c¡;.m",nt... 1'" 0800... 0 ¿', ~oh; .. 0 3": 065 Slurry Volume: 203 cl Slurry We.,gnl 15.8 PPg Slurry VlelO 1 17 CI 5X Tn'e~;;nlng T,meo :'I 5 - 4 5 nc,urs Production Casing Size 1 Hole Size OePln Top 01 C",meonl Excess C"ICUI,,¡,;d BHT ISI31IC/ or 470 sx Arcrle Ser :3 LIt", or 170 sx CI3.;> G 7" In 8.1/2" hole 7,839 7.00lo 7:.':' ~ 160" F 130" F 8HT IC,rCI: excess (1 751 = leE. CI 1 74 ~x or ("':'0 Js¡t sx CI.335 G 4-1/2" In 6-1/8" hole 8.279 7.650 50".. 160" F 130" F 8HT IC,rer eXCtiSS 11 501 "; ~,¿ cf 162 CII IT 20 ct ~~I VOlum", arOun( 4-1 2 Vol. Between liner 8. Int. shoe Joint vol 7 ct + Volume ot 200' above liner SY51;;m {Class G cem",nl w GaslJlok + 01 gps 047 Ideoloam 1+ 3'.053 IGYPI + 0.75°. 0E.510'sP .. 1 gps 0135 + 2 gps 0600.. 0 1., 0800 11,;1 ¡ 20 '£x 5ì sx .10 ~x (.140 III 100942 ct III Slurry Volume: 121 cl Slurf)' Weo,gnt , 58 PPg Slulry V,e.ld , 20 ct'sx ThlCKe-nlng T,me 3 5 . 4 5 nours or 120 sx Class G Cement volumes and blends are estimates only and subJect to change before 1/8/2002 0 t":I,J ,; M ~.. ; ,II ,f l,'~ ¡ ''VJÎ';5i1d- - 4000 = - J: .... c. Q) C 5000 ~ --- _I -- {'"r eo::: :r r------ 0 1000 2000 3000 6000 7000 8000 9000 0 2 3 i 1 - 4 5 6 7 Lookout #2 Producer Expected Drill and Complete Time ¡ _I - ------- _I - - -'- Estimated Time to Drill & Complete I I , I --- -----I-~-- I 1 1 : -I - - ~ - - -! - - - - -;- -1- - -,- I - - !- I I I , ' ------------------ -- - - ---; ---- -- - -- ----------- I ----- t--¡-. I i ' -~---~. : i ;___(_n__; I I 1 I - - i-- I ~---- I - - ,- - - - - - 1- - I .... '..... 'y , I ! -j- I - - ..'- , , -- -¡------- I - i -------- I I i - - 1- - 1 - ,- - . ------- ----------- - - I - - n__~__L - 1- - - ,- - - ¡- I ¡ -----'---- -r-------- I -1- --- I - -! - - - . - - - - ------ - T -----.---- "I i _1_____- I 8 i -~--~--_._- I .____i__:- i - L - - I - - ~ - - -, - - -: - - -I , I I 1 - _:- ------'-----"":-- - -- ;---------i- ---; ! I I - .. - - - - i - - 1- - - I I ¡ I , i I -, n - - - - -, - - -,- -I , I I ' ' - ---- -----¡------,------ ; -------- I I _I i I I : 0 1 +C' L - - ,- I ..... ; - - , ~A ... .... 1\.: ..... y ------ . 9 10 11 12 1 3 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 Time (Days) - -- -------1------;----- ""'---""- y ... ... , ---------- - - - - - - - -I - - - - - - - C) ::0 -- !:;") ---- : ::::"::JI ---- ~ .... 116" set @ 10s'I DRilliNG TIME AND MUD WEIGHT CURVE Lookout #1 ..-.- Depth -Mud Weight 0 ~J__tj_i_~_l_._j_j_~_t_l.:tj___'_t_"'J_--j-'-~~--~- I ~' '" 1 "" "" I I " "I' "I' I' " "" 1 I 1 1 ., I' ". 1 '~-I-L.--_'_...I_l_L___'__'_.J_l___L._I__'_.J___L_L._'_.J___l_L-L_I___.J_l_L_L- --,--,-,-,- --r-,--.-,---r-r-I-'---T-r-r-'---'-T-r ---'-'-T-~---:-~-~_~___I__I- 1_'___1 _1__'- 1___1 1 " 1 1 1 1 1 1 1 1- 11 9 --'-i - .. - -. . ~ L' ..I J. L' I , , 1 r 1 I' r-r-'--I---T-r-r-I---'-l-r-r- . _-:-~MIRU. 120 rig loads from 100% pad ~=, =,=== «, =, =~=~=~=~===:=~=~=~==-~-:-~-~---~-~~-~---~-~-:~Slougingshales Incr MW ~ 1 000 1 1 I I "', I I I' I':: ~ ~ ~:, -: ~ T r " 1 r - ,- -. - , - 1 - - - r - ,- -, - , - - - T - r -.- "- - -:- -: - ~ - { - - - ~ -:- -: - ~ - - - ~ -:- -:- -: - - - ~ - ~ -:- -:- - - ~ - ~ - ~ -:- - -: - ~ - [D~1I12-1/4" Hole 1- _:- _: - J _1- - - :- _:- _: - J - - - ~ _:- _:- from 11.3 ppg to 11.5 ppg to =- 11.7 --'--'--I-.&---....-'--I--I---~-....-'--I---''-~-....-I----I-''-~-.... -I -I ~ .... - - -. 1 I I' 1,1, ",control - = ~:~ =: = j = i = ~ = ~ =:= j = j = = = t = t =:= j = ~ = i = t = ~ =:= = = j = i = t = t =~ -: = j = t = t = = =1= j = i = I = : =:- =: = ~ = ¡ = = = ~ = ¡= ~ = ~ = = = ~ = :- =¡~ -: - - - + - ~ -:- -:- - - l - + - ~ -:- ~ 2000 1 1 " 'I' 1 'I I I 'I' I '" 1 I' 1 I I- 1--1--1---1--1--1--1--- '-~-.--.-' -,,-~-""-'----I-+-I--....-- 11.5 , 1 " '" 1 "I I 'I' 1 I" 1 . I' ," 1 I 1 " 'I I 1 I 1 'I 'I 1 1 1 1 1 1 --'--'--I-+---I--'----i---I--I--,-----+-I--I--'----i-+-I--I----I -1-+-1--- III II:' ~' I ,1'1 I', 1 I'" __'__I_...!_.!- --'__'__I_..!___!.._'__I__I___.!._!.._I__'__- I , " 1 1 I' 9-5/S"set@3143' --1---1- ---i-~rl--I--I----.-+-"'-I--'----i-+-I--I-- 1 1 'I "I' I' 1 1 1 I I I ,-ï-'-,----I '-1-'--- ,I_.!___I -'- 1_-'_- _!.._I__I__I_...._.!_!..._I__'___..!_.!._!.._'-- --'--'--1-+- --I--I----i---I--I--I------t-t--I--I------t-I--I----I -1-1--1--- 145ppgFIT 1 , , " I' I' "I' - 11 J-- - -:- -: - ~ - 1 - - - :- -:- -: - ~ - - - ~ - :- -: - -: - - - + - ~ -:- -:- - - ~ - f - ~ -:- - - -; - '- t - ~ - - -; - -' - 'J. - !. - - -'- -' - =} = ~ = ~ =:= ~ = ~ = = = ~ = ~ =:= ~ = =:- } = ~ = ~ -:= - - ~ - ~ - ~ - ~ - . , , 1 1 I" I I 1 'I 'I' I I I 1 1 1 I I 1 I I' , '" 1 1 1 1 , ~ 1 , ,- -I - - , - ~ - , - ,- - - - 1- -' - -' - 1 - - - '- - '- -' - J - - - L - '- -'- -' - - 1 , I' 1 I I. I'" t "I 1 I' 1 I' I 1 I I I' 1 I I' 1 I , I : :!: :!: t j : : : ~ :!: ~: j : : : t : ~ :!: t : ~ ¡ ~ ¡ Ii ~ ~ ~ E ¡ ~ ¡ ~ ~ ~ I j ~ ! ~ ~ ~ = :!: ~ ~ ~ ¡ ~ ~ f!: ~ ~ ¡ ~ : ~ ¡ ~!~ ~ ~ ; ~ ~ ~ ¡ ~ ¡ :!: ~ = :; ¡ : t :; : i: = = ; : ¡ : ¡ : ¡ ~ 11. 1 4000 'I 1 1 ,I I 1 I' 1 1 I 1 'I 'I I' I 1 I' I" ~ r r-, ,1"T r-, I' r r- -,- "1 - - ~ ~ - r - r- -,- - - , - T - r - r-:.... 1 0 9 , , " 'I' I 'I I' 1 1 1 1 I'" "I' 1 I 1 1 'I . 1 1 I 1 I' 'I 1 , - I I , 1 I 'I I I . = ~:~ ~: = ~ = ~ ~ ~ = ~ =:= : = ~ = ~ ~ ~ = ~ =:= ~ = ~ = ~ = ~ = ~ =:= = = ~ = : = ~ = ~ = = ~ = ~ = ~ = ~ = = =: = j ~ i = ~ - - -.~ -: -' ~ - ~ - - - ~ -:- -: - ~ - - - ~ - ~ -:- ~ - - . ~ - ~ - ~ -:- - - ~ - ~ - ~ - ~ - !i: , I 'I ,', I "" I' 1 1 '" 1 'II' ", -jDrlIIS-1/2"Holet-I--I_.J___L_L._'_.J__~l_L_L_'___J_l_L_L- CJ = =:= ~: = ~ = ~ = : = ~ =:= ~ = ~ = = = ~ ~ ~ =:~ ~ = ~ ~ ~ = ~ = ~ =:= = = ~ = ~ = ~ = ~ = = ~ = ~ = ~ = ~ = = =: = ~ = ~ = ~ . -- ;--; ~ - ~ - - - ~ =:= ~ = ~ = = = t = t =:= ~ - -, ~ - t - t -:- - - ~ - : - t - t:- 10.7 g! 5000 "" I'" I' " ,." ., 1 1 '" I I' I I 1 1 'I .", 1 1 1 , - - II , - 1 - 1 - - - - ,- , -, -, - ;:> , , 'I I'" I" I "I' I" 1 "I' 'I I I I 1 " I" I I' 1 , r" I 1 "" - - 1- -,- ..I - J. - - - L. _1- .J - .J - - - L - L. _1- .J - - - J. - L - I- - '- - - ..I - J. - L - L - - ...I - ..I - 1 - L - - -,- ...I - l - L - - - ,- _I' .J - l - - - L. _1- .J - .J - - - L - L. _1- .J - - . J. - L - L - '- - - J - J. - L - L - e - - '- -'- 1 - ' - - -' -'- _I - I - - - 1 - I _1- -' - - - I - I - 1- _1- I I I' I 1 'I "I 1 I' 1 I I 1 I 1 'I 1 I 'I ' " "" - 1 0 5 - - -:- _:- ~ - ~ - - - ~ _:- ~- ~ - - - ~ - ~ _:- ~ - - - ¡ - ~ - ~ _:- = = ~ = ~ = ~ = ~ = = ~ = ~ = ~ = ~ = = =:= ~ = ~ = ~ ~ =~ =~ ~ = ~ = : = ~ =~ ~= ~ = = = ~ = ~ =:= ~= ~ : 1 = TD/Make attempt ':ã: __'__I_'_I___I__I__I_'___'_'__'__'___I_I_'__'___I_~ II _1'1' '" 1 1,..1' I' 1 1 1 1 " ,@DPClogsrun2 1 , , T I 1 I 1 r 1 I' T r ., 1 I - r - ,- - -I - 1 - r - r - - -1- -I - 1 - T - - - ,- - - -I - 1 - - - r -1- -,- -I - - - r - r -1- -, - - " 1 - , I I " 'I 1 I I 1 I' I' 1 1 I' I' "'. 1 1 1 I , I 1 1 1 1 I I 1 I I 1 Pre-casing wiper ~ 10.3 . 1 I I 1 1 I I '" I 'I " 1 I I 1 '" --¡ ",' , I' ., " . t 'I ' . - -1- -.- 1 - T - - - ,- -.- -.- 1 - - - r -,- -,- -, - - - T - r -,- -,- - - 1 - T - r - ,- - - -I - 1 - r - - -,- -, - 1 - T - - . ,- -,,-- ""i Weekly BOP Test -,- -,- - - 7 - trips to clean hole - -1- -1- -I - -I - . - I- -,- -1- -I - - - I- - .... -1- -1- - - J - ~ -I- -,- - - ~ - .. - I- - .... - - -1- -I - .. - -,- -I - ~ - .. - - -I- - - -I -1- -1- - - ~ - ' __'_-:_...!_.!._--'--'--'_J___!..._I__'__'-- _.!._!.._'__'___..!_.!._!.._'___-'_..!_.!..! __I__I_..!_.!.. -- - " 'I 1 1 "I' ,run7"/CementlRun , 1 I ",. III' I' I' ,,', "," I I '1- I -I-T---I-'--I--¡---r-I-'--'---'-GOI IUS 1M - -1- -1- -I - ~ - - - I- -,- ..... - -I - - - .. - I- -1- -1- - - J - I- -I- -,- - - -I - + - I- -I- - - -1- - - .¡..-~. - -,- --t - - - + - - -I- 1 -I - + - - - I- -I- -1- -I - - - .. - I- -1- -1- - _. + - rvJB IT DT, 7000 I' 1 I "" I I I' I' I' "I, " , I I 1 1 1 I 1 I "I I 1 1 I 1 1 , , I' '" I 1 I I' I' I' ," " I I 1 I 1 I 1 1 I' I' 1 I run 2000' of tbg = =:= =: = ~ = 1 = = = ~ =:= ~ = ~ = = = ~ = ~ =:= ~ = = = 1 = ~ = ~ =:= = = ~ = 1 = ~ ~ = = = j = ~ = ~ = ~ = =:= j = ~ = ~ = ~ = ~ ~:= _I 1 = = = ~ = ~ ~ = ~ = = = ~ = ~ =:= ~ = = = ~ = and RDMO - 9 9 - -:- -: - ~ - ~ - - - ~ -:- -: - ~ - - - ~ - ~ -: - ~ -- - ~ - ~ - ~ -: - - - ~ - ~ - ~ - - - - ~ - ~ - ~ - ~ - -:- ~ - ~ - ~ - - - ~ -: - ~ - I - . - ~ -:- -: - ~ - - - ~ - ~ -:- -: - - - ~ - ComDle-ion/ODerati - . - _1- -'- J - 1 - - - L _1- -'- J - - - L - L _1- _1- - - ! - L - L -'- - - J - ! - L - - - - -'- 1 - ! - L - -'- J - 1 - 1. - - _IJf -'- J - - - - L _1- _1- J - - - L - '- _1- _1- - - . - L _1- _1- - - J - 1 - L _1- - , , I' "I' "" 1 I ,I I I I I' I' 1 I 1 1 I I I I' I I I' I 1 I I 1 ." I 8000 --:- _: - ~ _l- - - ~ _:- _: - ~ - - - L _:- _:- _: - - _1- ~ _:- _:- - - ~ _1- ~ - - - - _: - ~ - ~ - ~, - _:- _: _l_1- - - --:- ~ _l- - :- _:- _:- ~ - - - ~ - :- _:- _: - - - - ~ - :- _:- - - J _l- ~ _:_:- 9.7 --:--:-~-~- --~-:-~-~---~-~-:-~-- -~-~-~-:---~-~-~----~-~-~-~---:-~-~-~ r -:-~-~--- t- -.-t ."-,11 . . .. ~-t-.-~-t- - -'- -'- J - 1 - - - L _1- _I - J - - - L - L _1- -' - - - 1 - L - L -'- - - J - 1 - L - - - .J - J - 1 - L - - -'- .J - J - - -'- _1- J - 1 - - - L -'- -'- J - - - L - L -'- -'- - - .1 - L - L _1- - - J - 1 - L - L - --:--:-~-~- --~-:-~-~---~-~-:-~-- -~-~-~-:---~-~-~----~-~-~-~ I 1 -~---~-:-~-~---~-:-~-~---~-~-:-~---~-~-~-:---~-~-~-~- 9.5 I I " I' 1 I "I I I'" '" I' I' " I I "I' I'" I I " 'I I I "" , I " ,I " I 1 I' 1 I " I I' I 1 'I 'I" I'" "., "I, "I, ,'I' - -r -1- ., - "T - - - r -,- ï - , - - - r - r -1- ï - - - T - r - r -,- - - , - T - r - - - - , - , - T - r - -,-, - , - r - - - r -,- , - T - - - r -r -,- , - - - r - r -,- , - - - T - r - r -1- - - , - T - r - r - - -,- -,- .J - l - - - L. - 1- .J - .J - - - L - L _1- .J - - - J. - L - L _,- - - .J - .L - L - - - - ...I - J - 1. - L - -:- ~ - ~ - ~ - - - L -~- ~ - l - - - L _1- ~ - .J - - - ~ - L -,- .J - - - .L - L - L _1- - - J - .L - L - ~ -=--- 9.3 60 - 3000 t- W W I.L - J: t- o.. W C C w a: :J en ~ 6000 :E 10.1 9000 0 5 10 15 20 25 30 35 TIME TO DRILL (DAYS) 40 45 50 55 Spud Well @ 0900 hrs 3/31/01 Release Rig @ 0600 hrs 4/30/01 prepared by WBL 5/0701 '!~ P-: ~:J L -"- ;' ~- . ) i . - J 11- FIr 12.01 ..J ~ - t- W W U. - DRilliNG TIME AND MUD WEIGHT CURVE -+- Depth 0 .. PAl Spark #1 Mud Weight I I I I I I I I I I I I I I I I I I --~--:--I -~----~--:--~--I____L_..J__I-_'¡----I---I__I-_J.---_I-_'¡_-I_-I-_---~-~--.:--~---_:_-~_-.:- 1 1 I I I I I I I -------- --- I 1 1 1 1 1 1 1 1 1 1 I 1 I -1-----1--1---1--1-----1--1---1--1-- 1 1 I 1 M .. / ,-------------------- 1 I 1 I' I 1 I' I ---1--1--1- -1-- Qve In ng 321/2000 -~_~____I - I I I i""-'--I--j"----I--¡--,--¡-----,--r--I--'-----I--¡--l--:----_'__1__1.__'-- - - ~ - -:- - ~ - - - - - .L - -' - - L - -' - - - - L - -J - _1- - 1 -- -- ~ - ~ - -~ - ; - - - - : - ~ - -:- - ~ - - - - ~ - + - -t - - ~ - - - -1- - ~ - -1- - ~ - - - -1- - to - -I - - t- - - - ~ - - ~ - ~ - -:- -- 11.8 1000 I I I ::::::: 1 1 I--I--I----I-I--I--I----I--f--:--~----:--}-~--:-----:-_~_~__I_____I__L_l__I_- : + f ¡ = j=: = I r¡ = i = = =I j: I J =: = = ~: ~==~= ~::~ =~ = :j== ¡ =: ==~ = ¡ = ~= = ~ =: = =!= = ~ = ~= =~ =: = =!== ¡ = ~ = =~ = = = ~= =U = =1= =- 11.6 - - { --: - - ~ - ~ - -& - t j Ru n 7 -5/8" Surf. Csg. H - = = = ø - - '- - 1 - - - - L - 1 - -;- - =: = = ~ = 1 : ~ = = ~ = : = =:= = ~ = ~ = = ~ = - - -: -- ~ - ~ - - ~ -- - ~ - - ~ - ~ - -: - - 11.4 , , , , \, ~ . " ..., Z ~ J :: ::: ""'" ,- -- -, --, - ,-- ,m + -:- + -:- - J = =;= = t = r = ~ = r T ~ = = = = HJ = i :':'= I rH: = = =~ = ~ ==:=:~=: = ti: i= t: = :;= = ~ =~= =~ =: = =;= = ~ = ~ = =~ = = = ~= =~ = ~ = =!= =- 11.~ 3000 - - ~ - -1- - } - ~ - - - - { - -:- - ~ - I - - - - ~ - -: - -:- -{ - - - } - ~ - -:- - f i Plug back r - ~ - _1- - ! - _1- - L - - - _1- - L - _1- _1- - - - _1- - L - ~ - -; -~- - ~ - ~ - -:- -- 11.0 I I I I I I I 1 I I I' I I 1 I I I ~ 1 1 1 1 1 1 1 1 I 1 1 1- - - -, - - 1- - ï - -I - - -_.J_-'__I-_.l---IFIT159l.J----.L._..J__I-- ----1--...1--1--.1...----1..-..1 :.1.' I I I I I I I I I I I I I I I I __I__I__~_..!_-- . 1 1 1 1 I 1 1 1 I 1 1---- -.-_1.._.1..._-'-_1..- __I--.L.-.l--I..----I_-I-_...I--I-.----'-_I.._..I__I__- 108 ) ==i== ¡ =~==== t= =!= =~=~====~=f~~r==~ =~==~: ~:=: =~=~ ==U: = - tI=t~=: =tU=t=:t~=~: =~=: =~= =~:j ==i: =- 10:6 4000 I I t I I I I I " ,IWtUpf/sloughmgshalel' 1- I I 1 I. 1 1 I 1 I I--'--I-------I--ï--,-- ~ ~ ~ ~ r ~ I~~ I ~~I ~ ~ ~ ~ ~I t ~~~ ~I fEI = = =~ =~ = =!: ~~: - - :: H::~ ~::t i = t~ =:: t u= t = = t~ =J = t- 10.4 ~ 5000 "" """' - " "" ---,-,--,-- ------ _--'--L---_'--L-J__L____'--L_L_'_---_'uL-'--'--- 10.2 £! I I I I I I I I I I I I I " I I ": 1 I, :: :::: :: I 1 I I I I W __.J__I__.L._.l_-r-J.-_I__I.._.J_--_.L.- j--I.._.J--__L-...I__L_.L----I.._J__I- L' I-. 1 I I I I I I 3: I I I -r 1 1 I 1 I 1 1 1 I I 1 - ~-- - _-'__L____I__.L._.l__L--__I__I-_...I__I____-'_-I..-..I--I-- 100 : : FE : ~ : ; : : : : 1 = =': : '- =;:: = : ; : E t = 1 : : = = ~ = LE = E = = t t t ~ =~ = = ~ = ! - -:-- ~ =: = =;= = t = ~ = = ~ = : = =i= : ~ = ~ = : ~ : = = ~ = = ~ = j : =i= = - 9 8. i 6000 :::: :: 1 1 ~ 1 1 1 1 1 I 1 1 1 1 1 f -I - 1 - ~ - - - -1- -.- -1- -1- - - - -1- -¡-- I - -1- - - - -1- -1- - I - -1- - . - - ..I - _1- - L - .J - - - - .L - _I - - I.. - - - -. - ~ - - ~ - ~ - - - - ~ - ~ - _:- - ~ - - - - ~ - ~ - _: - - ~ - ' - ~ - - - _: - - ~ - ~ - - :... - - - _: - - ~ - ~ - _: - - - - ...: - - ~ - ~ - _: - - - - ~ - -:- - ~ - ~ - - - - { - -: - - ~ - 1 - - - - ~ - -: - -:- - {- - - - ~ - ~ - -:- - } - - - - ~ - ~ - -:- - ~ -, - I -:- ~ - - - -:- -} - ~ - - ~ - - - -:- - ~ - ~ - -:- - - - -: - - ~ - ~ - -:- - - 9.6 - - .. - -,- - t- - ... - - - - + - -1- - .... - -t - - - - t- .... - - ... - + - - - - I- - -t - -I- - + - - - - .... - .. - -I~ - t- - - -I- - - -1- .... - - - -1- - t- - -I - - ... - - - -1- - I- - -t - -1- - - - -1- - .... - .. - -1- - 7000 - - ~ - -:- - ~ - ~ - - - - f - -: - - ~ - ~ - - - - t - -: - -:- -1- - - - ~ - ~ - -:- - t - - - - ~ -1- -:- - ¡. - - - -:- - t - -: - - L - - - -:- - t - ~ - -:- - - - -:- - ¡. - ~ - -:- - - - -: - -:- - ~ - -:- -- 9.4 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I - - ..I - _1- - L - ..J - - - - 1 - _1- - I.. - ..I - - - - .I. - -- - L - 1 - - - - L - .J - _L - .I... - - - - I.. - ..I - _1- - L - - - -I- - 1 - ..J- - I.. - - _1- - J. - ..J - - I.. - - - _1- - L - ...I - _1- - - - ..J - - I.. - ..I - _1- - - - { - -:- - ~ - ~ - - - - ~ - -: - - ~ - ~ - - - - ~ - ï - 1- - { - - - - ~ - ~ - -:- - ~ - - - - ~ - ~ - -:. - ~ - - - - ~ - ~ - -:- - ~ - - - :- - ~ - ~ - - ~ - - - -:- - ~ - ~ - -:- - - - -: - - ~ - ~ - -:- -- 9.2 - - .. - -1- - I- - ... - - - - .. - -1- - .... - -t - - - - t- - -1- - - + - - - - .... - -t - -I- - ... - - - - .... - .. - -1- - I- - - - - ... - + - -1- - .... - - - - - t- - -I - - I- - - - -1- - I- - -t - -I- - - - -1- -.... - .. - -1- - I 1 1 I 'I I' 1 I 1 I I 1 I 1 1 1 1 1 1 1 1 1 I' 1 1 1 1 1 1 1 1 1 - - I - -,- - I - -. - - - - "'i - -1- - ¡- - ï - - - - I - -,- -. -"'j - - - - ¡- - 1- -.- - ï - - - - 1- - ï - -I - - I - - - -1- - ï - -1- - I - - - -I -. - -, - - 1- - ""j - -,- - - - -, - - 1- - ï - -,- - - 9 0 8000 . 1 I I I I I 1 1 1 1 1 'I 1 I I 1 I 1 I I I 1 1 1 I Logged I, 1 I I I 1 . - - ..I - _1- - L - ..J - - - - 1 - ..J- - L - .J - - - - L - ..J - - L ..I - - - - L - .J - _L - .L - - - - L - ..I - -L.... - L - - - - L - .L - _1- - L - - - _1- L - ..J - - L - - - -' - - - - .J - _1- - - - ..J - - L - ..I - _L - 1 1 I 1 I 1 " 1 1 1 I 1 1 1 1 1 1 1 1 1 I 1 I I I 1 1 1 1 I 1 1 1 1 = = ~ = =:= = ~ = ~ = = = = ~ = =:= = ~ = ~ = = = = ~ = ~ = = ~ - ' = = = = ~ =: = =: =: = = = =: = ~ = =~ = ~ = = = =: = ~ = 2= = ~ = ~ = =:= = t- ~ j= ]~ = . = =[ = i = }= ]= = i = J= =: = ~ = =:= =~ 8.8 9000 --: - -¡- -:- -: - - - -: u¡- -: -: - m:- -:- -:- - , -- - -~ - ~- -t -! -- -~ !- " -:- - m¡- -: u:--:- - m:r R~n 5-112" - -i--:I Rig Relear:ed'4I29/00=- 8.6 - - J - _1- - L - ..J - - - - J f h I ~ - - L - 1 - - - - L - .J - _L - .L - - - - L - J - -'- - L - - - - L - .L - ..J- - L - - - _1- - .L - -' - - L. - - - _1- - L - ... - -'- - - - -J - - L. - -' - -'- - - - ~ - -:- - ~ - ~ - - - - {~ 0 e opener run ~ - - ~ - ~ - - - - ~ - ~ - -~ - ~ - - - - ~ - ~ - -:- - ~ - - - -~ - ~ - -:- - ~ - - - -:- - ~ - ~ - - ~ - - - -:- - ~ - ~ - -:- - - - ~- - ~ - ~ - -:- - - 8 4 - - .. - -1- - I- - ... - - - - ... - -1- - I- - -I - -¡- - ~ - ~ - - ... - .. - - - - I- - -t - -I- - ~ - - - - .... - -I - -1- - I- - - - - ... - ... - -1- - I- - - - -,- - ~ - ~ - - I- - - - -1- - I- - -t - -I- - - - -1- - I- - .. - -1- - . 1 I 1 1 I 1 1 1 I' 1 1 I 1 1 I 1 1 I I 1 I 1 1 I' I I 1 I I 1 1 I I . 10000 - - "j - -~- - ~ - ~ - - - - ~ - -~ - - ~ - ~ - - - - ~ - -~ - - ~- - ~ - - - - ~ - ~ - - ~- - ~ - - - - ~ - ~ - -~- - ~ - - - - ~- - ~ - -~ - - ~ - - - -,- - ~ - -~ - - ~- - - - -~- - ~ - ~ - - ~- - - - -~ - - ~- - I - -.- - 8.2 -- - ..- ..,.oJ 12.0 2000 J: t- o. W C 0 5 10 15 20 25 TIME TO DRILL (DAYS) 30 ::55 40 jt 9/99 C) ::J::] -- ~ --- ~ ~ r-- - I- W W LL - DRilliNG TIME AND MUD WEIGHT CURVE -+- Depth 0 Rendezvous 'A' -Mud Weight ~ I , , I I I " 1 I I I I -___1 I 1 J L 1 I' I 1 1 I - - - - ~ Move in rig 4/11/00 f/ Nanuk = = ~ = = = ~ = = = =~ = = = = = = = j = = = =:- = = = ~ = = = ~ = = = - - - - - ~ - - - ~ - - - -:- - - - ~ - - - - - - - -:- - - - ~ - - - ~ - - - -:- - - - 1000 :::: 1: :~::::~::: 1::::::::~::: 1:::~:: ::~::::::: t::~:):::~::: ====I= }== f= I= =: = = = f =I = = E= f = =- 11.8 - - - - ~ - - - -: - - - - ~ - - - ~ - I I . 1 I' I I :: I' I I I 1 - 11.6 2000 = = = = 1 = = = :;- = = =~ = = =; = ~~~ ~ ~ ~ ~~ ~~ ~ ~ ~ ~ ~ r ~ ~ ~~ ~~~ ~ ~~~ ~~ ~ ~ ~~~ ~~ ~~~~ ~~ ~ ~ ~~ ~ ~ ~ ~ ~ ~~ ~~~ ~~~ ~ ~ ~ ~ ~~ ~: ~ ~ ~ ~i~~~ ~ ~ ~ ~ ~ ~ ~~ ~ {~~ ~ ~- 11.4 - - - - ~ - - - ~ - - - ~ -I Ran 7-5/8" Casing I~ - - - ~ - - - - ~ - - - - - - - ~ - - - - ~ - - -l- - - J - - - - - - - -l- -- J - - - _:- - - - : - - : : : : - 11.2 = = = = E = ~= = =: ~ = J =:: :,::::~:::!::: ~- ~ - -:-:: - _: -- ~--- ~ - - - i _: - ~ - _: --- - -: --- j - - - -~: f :~~ = = r = = f = = I = = r = =- 11.0 3000 : : : 1159 Fï-r-I\--:----:---':----:---------:----:----:---ï--------}---i----:--~--"---:----~----1----:----- 10.8 - - - - I - - - -' - - - - ,. . I I I I I ,: I I I , ... I ' I , - - - - ~ - - - ~ - - - - ~ - ~ - - - ~ - - - : - - - ì - - - - r - - - - - - - ì - - - -r - - - T - - - ì - - - - - - - - ~ - - - ~ - - - -:- - - - ~ - - - - . - - -:- - - - ~ - - - ~ - - - -:- - - - - - - - . - - - '- - - -' - - - . - - - - - - -. - - - I - - ~ j Wt. Up for shale t - - - ~ - - - ~ - - - ~ - - - - - - - - L - - - .J - - - _1- - - - L - - - - - - - _1- - - - L - - - .J - - - _1- - - - - 10.6 - - - - { - - - ~ - - - - ~ - = = t = = = = = = = -~ = = = ~ = = - -: - - - -:- - - - - - - - -: - = = =:- = = = t = = = ~ = = = = = = = = t = = = j = = = =:= = = = t = = = = = I~ = =:= = = = t = = = i = = = =:= = = =-- 10 4 4000 : : :: 1 t- I 1 I I I' ,::: :::: . ~ 10.2 ~ 3: 10.0 c ::::» - - - - ~ - - - -:- - - - ~ - - - ~ - - - - - - - ~ - - . ~ - - ~- - - -~ - - - - - - - ~ - - - -~ - - - ~ - - - ~ - - - - - - - - ~ - - - ~ - - - -:- - - - ~ - - - - - - - -:- - - - ~ - - - ~ - - - -:- - - - 9.8 :E = = = = i = = = j = = = = t = = = i = = - = = = = = t = = = 4:' ~ = = j = = = = t = = = = = = = j = = = = ~ = = = t = = = ~ = = = = = = = = t = = = j = = = = ~= = = = t = = = = = = = '~~ = = = t = = = j = = = = ¡ = = = = - 9.6 6000 . 1 I' . .. I I I' I 1 I 1 . I I - - - - ~ - - - ~ - - - - ~ - - - ~ - - - - - - - - ~ - - - ~ - - ~ - - - - ~ - - - - - - - ~ - - - - ~ - - - ~ - - - ~ - - - - - - - - ~ - - - ~ - - - -:- - - - ~ - - - - - - - -:- - - - ~ - - - ~ - - - -:- - - -- 9.4 . . " .., I I' I' .. I I I I I - - - - ì - - - -1- - - - r - - - ì - - - - - - - -.- - - - ï - - -,- - - - 1- - - - - - - - -,- - - -,- - - - T - - - 1 - - - - - - - - T - - - 1 - - - -.- - - - r - - - - - - - -,- - - - r - - - 1 - - - -1- - - - - - - - ~ - - - -: - - - - ~ - - - ~ - - - - - - - - ~ - - - ~ - - ~ - - - - ~ - - - - - - - ~ - - - -~ - - - ~ - - - ~ - - - - - - - - ~ - - - ~ - - - -:- - - - ~ - - - - - - - -:- - - - ~ - - - ~ - - - -:- - - -- 9.2 --' - - - - T - - - -.- - - - r - - - T - - - - - - - - r - - - T - - - - - - - r - - - - - - - ï - - - - r - - - T - - - , - - - - - - - - T - - - , - - - -.- - - - T - - - - - - - -.- - - - r - - - , - - - -,- - - - . . " . I 1 I I I' I'" I 1 , I I I I I .. . 1 1 I 1 I 1 1 I 1 I I I - 9.0 - - - - "t - - - - - - - - r- - - - T - - - - - - - - r- - - - 1" - - - -1 - - - r- - - - - - - - -1 - - - - r- - - - 1" - - - "'1 - - - - - - - - 1" - - - "'1 - - - -1- - - - r - - - - - - - -1- - - - r - - - "1 - - - -1- - - - I I " I I 1 1 1 I ., .. I' I I I I = = = = l = = = ~ = = = = ~ = = = J = = = = = = = = C = = = I = = = J = - - = C = = = = = = = J = = = = C = = = I = = = J = = = = = = = = ~ = = = J = = = =: = ~ = ~ ~ = = = = = = = ~:= = = = ~ = = ~ J = = = =: = = = =- 8.8 I , 'I 1 I 1 1 I' I' .. ~ I I . r.- 1 , - - - - "i - - - -,- - - -.- - - - ï - - - - - - - -,- - - - T - - - -.- - - 1- - - - - - - - -,- - - -.- - - - T - - - 1- - - - - - - - T - - - ï I run 5-1/2" - - run kill strg. r. - - - 1 - - - -,- - - - 8000 I I 'I . I' I' I I I 1 . . ," - 8 6 = = = = i = = = j = = = = t = = = i = = = ~ = = = = t = = = i = = = j = = = = ~ = = = ~ = = = 1= = = =~ j- I -. - j = = = =.= = = = i = = = j= = = =.= = = = i = = = ~ = = = i = = = ~ , rel~ase ri'g t = = 8..4 - - - - ~ - - - -: - - - - ~ - - - ~ - - - - - - - - ~ - - - ~ - - - ~ - - - - ~ - - - - - - - ~ - - - - ~ . oggIng ~ - - - -1 rftlsf- - - ~ - - - -:- - - - ~ - - - - - - - -:- - - - ~ - - - ~ - - - -:- - - -- - - - - 1 - - - _1- - - - L - - - 1 - - - - - - - - L - - - 1 - - - J - - - - L - - - - - - - J - - - _1- - - - L - - - ..J - - - - - - - - - - - .J - - - _1- - - - L - - - - - - - _1- - - - L - - - J - - - _1- - - - I 1 I 1 I I I I I I . 1 I I I' I 1 1 I 12.0 J: I- 0. W C 5000 7000 9000 8.2 25 0 5 10 15 20 TIME TO DRILL (DAYS) jt 9/99 <:::) :::::0 --~ ç~ ~ - -~:;. ~ :~ ,-- 2000 - 3000 f- W W U. - J: f- a. W C C w a: :J CJ) « w :æ 4000 116" set @ 115'\ DRILLING TIME AND MUD WEIGHT CURVE Rendezvous #2 ~ Depth ~v." '-,- Mud Weight 5000 6000 7000 8000 9000 0 I I I I I I I I I I I I I - - - - ..J - - - - - L - - - - - - - - - - '- - - - - J - - - - - 1- - - - - .J - - - - - - - - - - J - - - - - '- - - - - .J - - - - - '- - - - - - - - - - _1- - - - - 1 - - - - _1- - - - - ~ - - - - - - - - - - r - - - - 1 - - - - - :- - - - - - - - - - -:- - - - - ~ - - - - - 1- - - - - ~ - - - - - - - - - - ~ - - - - -:- - - - - ~ - - - - -;- - - - - - - - - - -:- - - - - ~ - - - - -:- - - - - ~ - - - - =- 11.4 - ~IDriI112-1/4" Hole I~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ = =~ ~ ~ ~ ~ ~ ~ = ~ ~ ~ = ~ ~ = ~ ~ ~ ~ ~ ~ ~;~ ~ ~ ~ ~ ~ ~ ~ ~ = ~:~ ~ = ~ ~ ~ ~ ~ ~ ~ ~:~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~:~ ~ ~ ~ = ¡ ~ ~ ~ ~ ~ I I I I I I I I : : : : : ~ : : : : : ~ : : ~9~j/~'~ ~~I: l ~~~~.: ~ ' ~ : ~ ~ ~ ~ : '1 : : : i~ :~: : i :~' ~._~ ,~=~ ~ ~~ ¡: ~. ~. ~ ;~ : : ~ ~ 1 ~ : : : ::~ ~ ~ : : : ~ : ~ ~ ~:: ~ : ~ ~ j : ~ ~ ~ ~: ~ : : : ~ ¡ ~ ~ ~ : ~ ::.2 14.5 ppg FIT 1 ,''' 1 I ; ~ " ,::: - - - - - ..... - - - - - - - - .., - - - - - .- - - - - - - - - - - I-- - - - - -t - - i:~ - - 1- - - - - ~ - - - - - - - - - - -I - - - - - ~:~- - - - - -+ - - - - - 1- - - - - - - - - - -1- - - - - + - - - - -1- - - - - + - - - - - ::: ~: N:::¡: ~ ~ I ~:::N>::::~:: :);1:: :~~ ~ ~:j::: ::= ~~:: I:::: :It:: i:: ~ :::::::::: ~:: :'::::: ¡:::: :I~ ~ ~::!:::: ~ :::: r~' I I I I~.. I I I I 1":- I I I I I I - - - - - ~ - - Ill. - - ~ - - - - ~ - - - - - ~ - - - - - - - - - ~ - - - ~f ~ - - - - - ~ - - - - ~ - - - - - - - - - - ~ - - - - -: - - :.~ - - ~ - - - - -: - - - - - - - - - - -: - - - - - ~ - - - - -: - - - - - ~ - - - - ~ 1 0.4 : : : : T : \ ~ : : : : i : I õriu- ~-1 ;2~' 'HoÎ~ t : - ~ ): i : : : : r : : : ; : : : : : = : : : : ; : : : : :!: : '~.' : ; : : : : :!: : : : : : : : : : :!: : : : : ¡ : : : : ::: : : : : ¡ : : : : ~ - - - - - !,J - - - -,~ ~ - - - - ~ - - - - - ~ - - - - - - - - - - ~ ..f - - ~ - - - - - ~ - - - - ~ - - - - - - - - - - ~ - - - - _:- - - ~~ - ~ - - - - _:- - - - - - - - - - _: - - - - - ~ - - - - _: - - - - - ; - - - - - ~I '!1.. I I I I"j I I I I I ~ I I I I I I - - - - - ~1 - - - - 1!,- - - - - 1 - - - - - ,- - - - - - - - - - -1- -:- - - 1 - - - - -1- - - - - 1 - - - - - - - - - - ï - - - - -,- - - _0: - ï - - - - -,- - - - - - - - - - -,- - - - - ï - - - - -1- - - - - T - - - - - - - - - - ~ - - - - ~f - - - - ~ - - - - - ~ - - - - - - - - - - ~ ::~- ~ - - - - - ~ - - - - ~ - - - - - - - - - - ~ - - - - -:- - - - ~ - ~ - - - - -:- - - - - - - - - - -: - - - - - ~ - - - - -: - - - - - ~ - - - - -=-- 1 0 ~ ~ ~ ~ ~ ,~< ~ ~ ~ ~ :~~~\~ ~ ~ ~: ~ ~ ~ ~ ~ :~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ :j~ ~ - - ~ ~ ~ ~~~ ~~i~u-r~ - - - - - - ~ ~ ~ ~ ~ ~ ~ ~ ~ ~:~ ~ ~ ~ ~,- ~ ~ ~ ~ ~ ~:~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~:~ ~ ~ ~ ~ l ~ ~ ~ ~ ~:~ ~ ~ ~ ~ : ~ ~ ~ ~ ~ : : : : : ~ : : : : : ~ : :>~,i. ~~~. ~ ,: ~ ,~: : : : : : :,,:,;f : : : : ~ : : : : : ," : : : : j : : : : : ~ : : : : ; : : : : : ¡: : : : y : : : ::: : : : : : : : : : : ¡: : : : : j : : : : ::: : : : : ! : : : ::- 9.8 -- '- - - - - ~ - - - - -, - - - - - + - - - - =- 9 . 6 - : : : : L : : : : ~ : : : : ; : : : : :; : : : : : : : : : : ~ : : : : ; : : : : :; : : : : ; : : : TD~~u,n T'~~~~~~~~u,n, ~~~J_B:US:IT:'SP/IR_u_n- CO~PI~üon:opera~:~~~I_~~ - - : :~ 9 20 1000 I- J: CJ W 3: 10.2 c ::J :æ: 0 5 10 TIME TO DRILL (DAYS) 15 Spud Well @ 1600 hrs 4/8/01 Release Rig @ 2400 hrs 4/23/01 prepared by WBL 51701 Text for inclusion in pemlit approval cover letter: In accordance with 20 AAC 25.005 (f)~ all records~ data and logs acquired for the pilot hole must be clearly differentiated in both name (Lookout 2PH) and API number (SO- l 03-2041 0-70) from records. data and logs acquired for \vell Lookout 2 (50-103-20410- 00). WC¡r\ if Îsl~ 1.- ~ PHilLIPS Alaska, Inc. ~ A Subsidiary of PHilLIPS PETROLEUM COMPANY Box 100360 Alaska 99510-0360 January 91 2002 ~I2C~/¡I2D J4N 1 A/ask., 1 200') aOi/&G. ( A iSCons a flChoraue' Ofl/f»iSSion Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil and Gas Conservation Commission 333 West th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: Lookout #2 (Exploratory Test) 1387' FNL, 1399' FEL, See 25, TllN-R2E X=314048, Y=5955055 ASP4 NAD27 1312' FNL, 1399' FEL, See 25, TllN-R2E 1312' FNL, 1399' FEL, See 25, TllN-R2E Dear Commissioner: PHILLIPS Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory test well from the referenced location in the National Petroleum Reserve - Alaska. The well is designed to penetrate, evaluate and test the production potential of the objective sands. As indicated in the attachments, the drilling program will entail drilling an 8-1/2" wellbore through the objective with a full LWD logging suite for evaluation. Based upon favorable log data, the well will be plugged back and twinned to the top of the objective and a 7" intermediate casing will be run in order to case off potentially sensitive shales. At least one 60' core will be cut through the objective zone beginning immediately below the 7" shoe. The well will be drilled to TD and a 4-1/2" liner will be run and the well will be tested, post-rig. The proposed casing program will utilize a 9 5/8" surface casing string, a 7" intermediate casing, a 4-1/2" production liner and either 4-1/2" or 3-1/2" 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 (Nabors 18E) as required by 20 AAC 25.035 (a) (1) and (b) have been submitted previously. OR\G\NAL 5) A complete proposed casing and cementing program is attached as per 20 MC 25.030. A well bore schematic is also attached visually depicting the proposed well. The drilling fluid program, in addition to the requirements set forth in 20 MC 25.033 are attached in this APD package. Seismic refraction or reflection analysis as required by 20 MC 25.061(a) has been mailed under separate letter. 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 rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 6) 7) 8) Complete mudlogging operations such as type log generation and sample catching are planned. The following are PHILLIP's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 MC 25.070) Sharon Allsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs (20 MC 25.071) Dave Bannan, Geologist 263-4733 The anticipated spud date for this well is February 25, 2002. If you have any questions or require further information, please contact Tom Brassfield at (907) 265- 6377 or Paul Mazzolini at (907) 263-4603 Tom Brassfield Senior Drilling Engine r cc: CONFIDENTIAL - Lookout #2 Well File Paul Mazzolini ATO-1570 Andy Bond ATO-1310 RECE\VEO JAN 1 1 2002 Qi\ & Gas Cons. commission A\aska Anchorage OR\G\~~AL . i\T't1 ì,LI) I¡ i~ (11ft ;~, ;l:l~;j¡ji.: I =I.lllei-j .'. I =I ~. tL~ :,.t.\r~d.~ ~J:I~ ,~~f.'fa?;l ~~,\; ).f ~'0 ~ I~ ,;;/ \f-1v.(.fJ:'~"r.\. [1;. "V'll ir~~I' :I:\\;f;';~ ~'~~~:llr~\J;~ =t':k1:'~ïM~t~H~~L ,,¡¡ )PHIIUPS '~::;,~~r~~~~~~~~~¡n;':~":.~¡~;(\;';:',;5't:~~:.;::,::>~? ¡"::V'>. :.7~-:;O^ ,'1:eÇ~~~,~~~c. Ba~k ~~"ç~:;~~:~'~;'~ ::...':::- ','. :.". . W Phillips Alaska. Inc. ...;~,....,),::. '::>':", ';.;: .',': ' "', ,: :".: ',:,,' Chkca¡;o.II~ino!s.ACCOUI1('09-,90000, ". . A....' : : : Payablt:: Th.riJu@.h PO ßox I O,¿,. 776 ReplIblic B¡;.nl:. St,eU>y\'II!e. 1<1J¡Qi1~_p98 p Anchor3ge. AK 99510-:"776 ~I . -' '-' -;;:I"" ,..... ""'....,.., I V Pé(,' ONE HUl/DRED DOLLA.RS ].J!D IJû CENTS 0101398 To Ihe o¡J¡;r 01: (I 1 - 1 (I - I): .~~~****~*~**~lOO.OI:'* STATE OF h..I...ASLA ':"OG'::-C Dal~ \m'"unl. \ ,'lId ;;¡! Il:'r <;JI.I d,(,s 333 \.1. 7TH ,c.,'.'EHUE, SUITE 100 1,NCHOP;:'.GE Al-: 9StS013539 "ï' (un rl( J l.../lu1.I.k^-_) I j /-~; .:~ ~11~',r~ ~IL~~ 1 ~~~ ;,t' 'r~;I~'~I~;' fill L-c-;..)~ -tF- d--. "'I'" P ;, ;¡.,~ .".',;0.,,: 1(:', .,.. L .1'."1 . 1110000 .. 0 . j 98111 I: 0 8 j £1 0 ~ 2 b 21: 0 £1 £10000118 CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDRlLL EXPLORA7/ INJECTION \VELL INJECTION WELL REDRILL TRANSl\lIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER "'ELL NAME I£xXou -f 2-- CHECK \\1lAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PIL07{PH) ANNULA~ D~~SAL ¥NO ANNULAR DISPOSAL l--> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a Dew wellbore segment of existing well --' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot bole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data an.~ logs acqujrld fo~wel\'fyame on permit). ~ Arr(.i-~~ Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS l--> YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved. subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. CXr (C:n"(.~h~ ~(: ¡'1~¿,(d/~,5. /~y"tVn~~ ~'?~--~~~~ ~/7'11 '/d' 17 /~ ~ ~¿~M0 ./~r(r~ ~ 0<.0/)6 ~-'f'! la' ~', u,~ l' ¿jl../i//.. Zl..Ct_;,k-v If 4<Ú<-,v-)] '(J7 ~a.J(j~;-'" (:11..~~ ~ ~vd' k4-.- ) /!(o¡ I....dz :J7/! ~ dr://.:./ / .5¿~1<ß 1o/:-I¡ =loYJ r"r "-<....J( '1'~;'UÝ"}'---"~..5 <ê,!Á ~ WELL PERMIT CHECKLIST. COMPANY Æ, / ¡, ~5 WELL NAME LÞvl:.o u I q 2.. PROGRAM: Exp / Dev - Redrll - Serv - Wellbore seg - Ann. disposal para req - FIELD & POOL /\/,4 IMT CLASS EX?£:. (~'-DcAí). GEOL AREA 8'JC> UNIT# d A' ON/OFF SHORE (:;~ ADMINISTRATION 1. Permit fee attached. ... . . . . . . . . . . . . . . . . . . .. ft' N. 2. Lease number appropnate. . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. .. . . . . . . . . . . . . . . . y.., N 4. Well located in a defi~ed pool.. . . :.' . . : . . . . . . . . . ~.0) 2)(f>(0A..~ ~I 5. Well located proper distance from dnlllng Unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . ,N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . IV"A. ~ N - 'v'¿.,.-h,-~ ~I 9. Operator only affected party.. . . . . . . . . . . . . . . . . . á..'N 10. Operator has appropriate bond in force. . . . . . . . . . . . . iN 11. Permit can be issued without conservation order. . . . . . . . ) N AP~~_ItR DATE "l J2. Permit can be issued without administrative approval.. . . . . N Þ.l) "').- 12... C> ~13. Can permit be approved before 15-day wait.. . . . . . . . . . N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . @ N ÇÆ, t ~) ¡ I'S .' TV. J). 'I i . .b .// / . 15. Surface casing protects. all known USOWs. . . . . . . . . . . 00' N A/~. ~L14~. '" . ..¡...t~J-/ :~' r/], ~ .Þ<.- ,> /¿:~~fr'7..~ / 16. CMT vol adequate to circulate on conductor & surf csg. . . . f'i/ N Ac/€q UN' þ' é'tLt'ç.s Ct"u. I) j. ~'I):J r,.('- J . /;)- . I!-?L ~~ ~~~ 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y ro ~ ¿Z,' ß.ð- 18. CMT will cover all known productive horizons. . . . . . . . . . ~N' 19. Casing designs adequate for C: T, B & permafrost. . . . . . . N. -. . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . ' N tJP..b~, r -.. I r £ 21. If a re-drill, has a 10-403 for abandonment been approved. . . -¥--N- ¡.J fA 22. Adequate wellbore separation proposed.. . . . . . . . . . . . -¥-N- Ii 23. If diverter required. does it meet regulations. . . . . . . . . . ¡ N ¡.j i iE.. 24. Drilling fluid program schematic & equip list adequate. . . . . N .,¡. ""~\~ \ ~\' \ '-~+ \~ .!:CCG\)"!.\ 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N 26. BOPE press rating appropriate: test to "3500 psig. Y N MA-sP :: 'zq~C fv;. f/ltt.'I- c. $.7 fes.t = 5CCC f.s--~' . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . fl2 N 28. Work will occur without operation shutdown. . . . . . . . . . . (]) N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ 30. Permit can be issued w/o hydrogen sulfide measures. . . . . (Î:)N /'I'V7U- ~ ~ ~Ç.,uI ~ /1 ?,'&;oL-;v..¡:-tf/ ¡{;. ~ ç-.Äd ~ (' ~ (~ ,~¡.(.,~. 31. Data presented on potential overpressure zones. . . . . . . c:!!Þ N ,\~''-'l. ,¿.x,~, ttiAYI~--kcI . ;?~~ ~Q¿~ ~ <J 32. Seismicanal~~isofshallo~gaszones. . . . . . . . . . . . . (j) N -A-O,t/~p~~/:,cr. /J"Iu:q' ~~J-fA..'/ pc~~ ~ q(;¡~ ûJtj ~tf'_. APPR OA TE 33. Seabed condition survey (If off-shore). . , . . . , . . . . .. NA. ~ M>d.e.ov t" ""1. (/ U r tt../ £0 2. tl..' Dv 34. Contact name/phone for weekly progres~~~~~t:f~~ O~/Y~NØkf'7-, ~~d u...~ ,p-r-~ d/44~ þ~ 1/ b-k -~.f~ -rx..i~:. Vi! ~/.,Lr ¿.' . ANNULAR DISPOSAL 35, With proper cementing records, this plan - ~ ,,'" - .~ 17 ÞW ~ ,vJ. c~,--r .,o/vV¡I.'rW /~4-1...ú rJ ~/~~ ~'1?1~e.6-.~ (A) will contain waste in a suitable receiving zone; . . . . . . . Y N i l I "" ( . . l-- d L Ii, .... ., APPR DATE (B) will not contaminate freshwater; or cause drilling waste. .. Y N I\.,.!) q,~\..Vll,.'t 'tv (Y(,~ yfJSI.C" ý""t'C) WSi-< ({. ( 'ttA..{ ç. '-/-( ~¡;.L-{ . to surface; P (C) will not impair mechanical integrity of the well used for disposal; Y N (0) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: Commentsllnstructions: RPC TE~-%,-{):;:L COT E'Xl~/t;rJ4.&. ,0 t~/L/(.' ;#-vd4./) J, Þ'~~ '~V<J;;d;:. SF~:::::::i:L.-- WGA vJc,,}--- DTS (Je'-{0<. ¡;¡. ¡ I~~ <-u->/(,&. dr./V, ~ ~ -h£Hiud. .~ JMH d1\:\lt ll2.~()~/~t ,tv-dl ~".~I b- &--r-e..d ¿... I~£~ ~-IL t,U ¡"~It~~. .,,~ J./f!/~ ~-(t.~-;" o--ed ro$-7',;e¡ /~ ~/u/~ð~.'~?~~6~ t.(~j;)£<.J ~f¡'?",,> "'~Þ- V ¿' i/ APPR OAT~ it.IG/~ Z//S{V"L ~ ;)-{~~ <5) GEOLOGY G: \geology\permits\checklist.doc