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Home My WebLink About204-015 ) ) 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. ~ 0 1+- 0 1 ~ Well History File Identifier Organizing (done) D Two-sided 11111111I" 11111111 D Rescan Needed 1111111111111111111 ,RE~AN þlcolor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: o Logs of various kinds: NOTES: o Other:: BY: ~ Date~_ :3-, '0 b 151 ~ Project Proofing BY: ~ <i IVIClIICI/ 1 Date: (:=3 ~ 0" ; 1111111111111111111 rtfJ 151 Scanning Preparation BY: ~ f x 30 = 3 0 + Date: ~'~ Db I = TOTAL PAGES 3/ (Count does not include cover sheet) v1/1. ...:.~ ¡0 151 I t' ~ Production Scanning 1111111111111111111 Stage 1 Page Count from Scanned File: ;:3:i-- (Count does include cover sheet) Page Count Matches Number in Scanning prr.. ar~t.ion: V YES ~ Date: 3, a-.¡ 0 &, If NO in stage 1, page(s) discrepancies were found: YES 151 NO j ý/1 BY: Stage 1 NO BY: Maria Date: 151 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 111111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page. doc 2 2 — —7 PHILLIPS PHILLIPS Alaska, Inc A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510 -0360 1 . December 6, 2001 t4 0N -GG Daniel J. Seamount, Jr., Commissioner DEC Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 NOWCONFIDENTIAL Anchorage, AK 99501 DEC o 2 2010 Re: NPRA Pore Pressure Prediction Dear Commissioner Seamount, Phillips Alaska, Inc. is submitting under separate cover two copies of the seismic pore prediction analysis for nine different NPRA wells. They are: Lookout #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 forwardedtas 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, 6 JAN 2 8 nn11 Tom Brassfield Senior Drilling Engineer Cc: CONFIDENTIAL -NPRA Well File Paul Mazzolini ATO -1570 1 % 6 CE I I /E EC 0 6 Z oo 0441-0t5 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 Date: October 23, 2001 DEC 0 6 2001 .l M. n A 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 -5 , intercept = 165, Heinlein 2000) was updated based upon 2001 drilling results (slope = - 4.5 -5 , 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 (AT) 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 I L49450 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 IL49471 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. • 4.) Seismic velocities indicate the ossibilit of high pressure 8400 ft - ft p y o a g p ess a zone at 8 00 8800 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 Well: Rendezvous 2 , Pore Pressure and Fracture Gradient System NCTL: 152-4.5e-5 10/13/2001 K. Heinlein Rendezvous 2 UM Plum setto MSL) FEET MSL MSL _cfp_s_2_ ; ,___ ___ : 01 __ -, -- _ - - ,-, , , . ....._ 1 _ --,-,-. EISIL,0-- 1060. 4— -)--"-- -,---, ..........J_-_ ._:_ .__.• - . g 1-- Si _ Ill ------- -------- ----- --r---- ----,----- --I -- 2000 -- 2000 . i • 1 , , i o , _ I . . -( IIIC ..--f -..._..--.0.======titimmaz . : 4--- . - , 1 . :;_j_.;4_ 7: 71. _21:. ,t4_,.. -g _-0.-_- _ ,___ -- L_ -.1- - _ - t - - • - 1 - __::._ 3000 • . - . . -• • • .--w MI 3000 , . • ' ':._ : _j_L_ __L_ . , ..-!- . _, , .. , - "i . . • En , . . . , • 1- REHR _.::.__:--_-- - re . ........ .... . - 1 -4- 4000 MMISMIMMIIIIIIIMR mu mu up _ „__ , - 1- 1 1 H ni , .,. it. ---- E it 1 ,' Iliu .1 2 ------- ---- ---_-------------- i ---- ------- — -.= - -- __ — - AI.. ...1 ,.._ L - -I-. --I- -4/ -- 1 -i-- __I ,.., 1 - I lid n IsmarA -1" • - --r--h EMI A BEHMINIfing - sow ; , il 6000 11111 . 1 I_____ - _ - .1 -- ' - ..1 - _.,... . ...11ni ..---- • -i - - 4 - i -4--i --, ir _,. 1__ i _Ix:41 :ki _ _1_,. simmi f -7 WOO • ' -..-111111 re, CH Minini !- 717— 1 ' 6000 - • - MIMI LifIIMD 11111111111111 ; -4- i - - -1 ---_----_ ,--_----____„_=A--•--- - • - -i - --• • -,-- ••• -- _-_-_--- •-;_2_ _ ,. , • , _i_ i -••,- gi t T. i ..,_--,-- - --• ---; 1 7„,,„ • _,_ 4 - T - Ith !WI 11E11 1 ...... 1 7000 — _ .. B al matiessimairso luau itni i _______ 1 ......, i t ...- , ---Ai Inismnimuifttm nth —...._ -1 ; NInic =MLT rin m 7 nj _ , + i• r Wan T. 7 .- 61 Istohnar I — -- ___. , IIIN WM IER , 4-4-4-4-4 MCC '`IIIIIIBM I ' 1 ---- 1 --- 8000 . _:_ Mr t 181 gitillAWIlitili0 Mil _ ____ ; [ ! — 8650 - 00 • 40 80 100 120 140 160 100 8 9 10 11 12 13 14 16 16 rim interns at a . isms PPG Legerdhmis Mope s 4580121 -G-153-430ST PPTC (Sonic RCTL:132-45E-S UDEF, Top Trend Model: OFFSHORETEXAS/HORTH SEA) —Mud Weight: DRILLERS REPORT a Casio, Depth X Risk Mew + Repeat Formation Test X Drill Stem Test Figure 1 A Prods:Ilea Pressure di Leok-ell Test M Loot Crab** Zones - Forman Top ... Musk Pipe Logsdon % Sidetrack Location X Freeform PHILL �� ® P S PETROLEU C � . ®® Pro'ect: NPRA If " A ^ Pore Pre an Fracture Gradient System Well: Lookout 2 10/13/2001 K. He NCTL: 155- 4.5e -5 Lookout 2: PPG Predicted fro Seismic (Inline 49540) (depth) 155 - 45 -509 PPC 2 L � I_'C SW p 77 77 7 g ggp { g 7 gg p $ z gg g399;;, NE CDP 8 , 888 . 88 86 8 7 77 777 7700 0 7 0 060 7 8 88 8 0 8 0 8 8 0 5 0 8 9 99. 8 9 9 i 9 5 0 , 1 5 5 4 q! MSL 0.0 ! 1 4 1 4 4 5 8 8 6 1 1 3 7 8 8 8 0 1 1 2 1 5 6 . ^"° x 850 .. ;:�wu r� :r* „� iP wr , . ��+« + 9.00 CDP w+r. ,a u ¢ 9.50 K - 9 i r x.., s 10.00 1.'"'s.'.°44 , ,r z a v F 10 2000.0 °� 7 ? > 11. s .r " � � � � ,1 a za 1150 ` � � ^k . s{ x ;k � �. - �r T',:-.47:', 40 »JF ,1, Y k +e � * AA: .� � , . �� 12.60 1 113 30004 I P,. . �a ax '".: `i'e 3 • , .a. 1340 0 '� * ,k, , . r a` a A . s : ,� 7 f+.,,,^� t.� @ �, „ 13.5 F ' S. ..c `' ' ' x '^1�' ..74.11•-• k ' { „ °' m �. 14.00 { i s ; ^ t i.' S ? r 1't� t 4 `� - - • 14,50 D 40 00.0 '7 7. -t % A ,rc + . - ` h ..� ' "`*ae.. ' � ""' - — �- -� -;- r °`a.:`'� ' "'.. - "3 15 ' 15.50 T ' _ 16.00 (1: 16.50 1) 5000.0 " �-� y� � ,� a 1740 4 r. � G � - a ,✓- • �'; 18.00 600 � 'tom.: ' " �a �. � r• �` , , ^� ' � _; �� . s - 18b0 4 mi Ao 7000. _ 4 >'v 1..."`"•• - J "' A/' •- hard- 8000.0 ?rte. „;;--2,-,.,,,,,i- �$t s .W � .N. �� x �"f 90 00 . 0 s . . * .r ,,; ` � , ' a '= ' 'a l 1 Y --1 h 1, `"'" � ,, a :4--':',7:;:'';--'t v t " 10000.0 y `+.> : _ ..� . . ._.�. ,. s..z CDP Spacing = 110 ft Figu 2 Project: NPRA PHILLIPS PHILLIPS PETROLEUM COMPANY Pore Pressure 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- SDS_PPC T L00T 2 $e,AicMLBYD_ESSYIC NE SW bb 1 7, 1, 1p11,b11 1, 11 bb p'bb bbbbpp 17 p 1 b 1po1p 7OOOOp ,bg7p7p7pbbb 'pbb OOpyyQpO bbypbbbb b'' i 0 0006000 OOOO Og 77 77777 777 7768 08 8818888g0gB8888gg9 919999 999 99 00 0 P 6 8 8 8 8 8 6 B 0 g B a s 8 8 6 7 7 � 9 8 9 0 0000 0 y 1), 2 2 3 3 4 5 5 0 in 8 9 9 0 1 OA 1 2 2 3 3 4 5 5 0 0 7 7 6 8 9 9 0 5 1 1 2 zz 3 4 4 5 5 8 8 7 7 8 3 9 0 0 1 2 2 i 3 4 4 5 i 8 7 7 8 8 1 i $ g 1 0 6 0 6 6 0 6 0 5 0 6 0 5 0 5 0 0 5 0 5 0 0 5 0 5 0 5 0 5 0 0 6 0 6 0 5 5 0 5 0 0 5 0 6 5 0 b 0 5 0 6 0 5 0 5 0 0 5 0 5 0 5 5 !1� 70: � 1i1 1111 it � 5 0 110111 i 11 1 1 1111111 H fill 0111 1 I a $:� CD I,. IIiiI 1 1 1 1 i i l i l 1 11 1 111 � I 11111 1111 1 1 1 1 III _ I 0 � i , � 9.50 366 llliliI111 i I i ro I Ii I I I I II I I I X 10: 400.6 ! II1i011i1 I III 1 li 1 I I II 1 1 111 it I!, . 1,� 6� Il Iillll fill 1 illii if it lIIIil i . III!1II 1111 x .11 II III 11111H1 11 111IHI11I1i11IIN I11Ii ,2A0 600.0 11 I lil Yt 1 1 III 1iiiIl01101I l I IIIIIIII Ih1bl1lI Il IIII1III00IIi�illll ,300 AO 796,6 1 illlillillilll Illillllllill i I 1111 I I l lll li01 i0� 1101i1�IlI llilllilll1IUl J 14 BO i IIv I1111IilliltlilIlilI1 11101I /II l 1110 1111111� �1I1til . lllllillli il _ I OR ] ]�`Y. jj '�(" f`,}j, }Jpj �li) @I Illl ' #i! " 15b0 M 900.0 � � � S �� S :S Si��kl'� � 18A0 �,, ,600.6 ; hill . 0 111 { I # I i 1111 111 1111 1111111 11111 illl 1 1111 i 0(1 111 1 ;z 1 1 >� ,.. . f , h 7 1 i 1lid, t Y t - - -- 17.50 „aa.a llk� es g_j j is {j � _� . 11111 q �� }j $ j i j 1200 1 �1 f1!0 I 0 41-, ill- . h ' 1 _ 111 ! t i 0I 16:50 1300.0 ,� 1 # 1111111111111111111111111111fillill1111111111111111 11 111111Ii1I : :41 1 i 1 1111 . 111 1 111 I lil III - ...... li I ,.- # II #0.1111 i 1.1 1Ilh1I11I0 t 1 11 1400.0 i si� 11 aqligilli,j-,!j'it!:rlltttj_Ajillirtt;tl;,;'gsifiti)ltilstit4.1 11 1' � ; .1!11111 1 1 1 �11! 1500.0 ,�� { {+SR �� # � � -, L S � ' � 0111111# IIIit i I 0 .--r?? ?? ? 43 1 z ii. t t 11 111 0 1 I1 1 01011 11�IlIi : ,7 1�� . ; <��g�,�� t�� r.�s�� 3�� . ._� �:�� .��; 1 1 1 1 1 , � 1 1r 11 i1I1'1 .i l � --- t 1 : 11lim1 0 Il l p ' 1 6 ,s00.o tz - . 'i ,, {■ a zini r. it . �d i5� a 4 4�rt i. - da l 1900.0 ''1 $r Is>i� ®i� f il : Ili . � - z t 1 111 1i .I ,# ..W 5- 111111.- -4,k9 " �.)11IIIII 1 it _ i it " i11I 111 � 1 2000.0 T " $` . , . Figure 3 CDP Spacing = 110 ft PHILLIPS p ®� rve� ��a aa® rs s "...0.‘ El N ®® ,r -.L6P €PETE'OLEU ra epal`, �a 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 (tnline 49567) (depth) 155- 45 -5Da PPe Z � 1 A SW NE 4DP 2 5 6 7 788 9 9 666666334445 5 .66 11 0 1 2 3 7 7 8 6 9 9 0 0 � 1 2 1 3 � .0 0 5 6 6 0 0 78.990 0 2 PN MSL 0,0 2 . 0 5 0 6 ■ i 5 ' . 1 5 6 5 0 5 0 5 5 6 - Q 5: ' S ' 5 88 0 5 5 0 5 0 ' 66 ' p ' y.,. 8.00 G ` .� : ., - 1 8.50 , y ; :... 9.00 1000.0 9.50 � *w .: . 10.00 a t d > } i - . ,,; ,.. ^t t" , ' . r " ' .n ,,,r 2 , � -,, , � - a ... - 10.60 a r 2000.0 + �` T ,. ,K, ,4,.:2-'4,-1'. 4. s .R' 14 11. y"' f r t t o r i +, 11,. r S xc r '' r. 1'". i 1 1.50 e ,°�`� w, � # ' '''..r '......4.4 :-' ,� la� r „ A s x� ' J i x "r ' ° ' ; _ 1 '`' +SF '^ ` " x"' x � s : r _d^8 �, ^ 12 .00 x Ir. � ° r ,:,; > '- ` `� G ' a ,:;,`'t2.--7,'. " . :° I �- #Y"" 12,50 r _, _ _ . _. 7 ,--4,,,,.---,-, -r.. 10.00 6 s ; . �s"�s 4 t T �• .y e` t , ' . . + `^• , $ r ' ,,. 14.00 � - b � — 1620 E �- '"°' ,. � 'wu; T - „A. " ' .� .. * .; _ • 16.00 - N 6000.0 �5€a " •rf - _ 16.60 IPI w . * -, r- " . . , � 17.00 �K �,: � � 7 � w '`17.50 r. `"'a 1 ' 18,00 18,50 8000.0 1900 :..7 4 4 , . ., 7000.0 x«r ,3 x __:,-..._,,4,:,....._-_----4-:-.2-,----, r : r a _ —"-- _ 1....ii „,,,,,, 4, ii4 � " '$r -- .^ -was— -r- � --_---------------- 0000.0 . 9000.0 a n� ' g V , — 10000.0 CDP Spacing =110 ft 'a _ ,� . Figure 4 PHILLIPS PHILLIPS PETROLEUM C PAN 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 (inline 49567) (time) 15S -1 - SOSJPO T Mr 3eis.ic:ALAYO EESIIO II SWS 555 g 5g 0 o p g 7 p 1 77 77 '' pppgpgg88 pp gpp8g NE 1 223 8 9 5 455667? 8l 9O 1 12 21 3 0 0 66667 ? 8 0 69 1 7 2233 6 37 7 � 9 01/22334 6 B�67788 990 1 CDP 5 6 4 pp pp 77 oo 2 5 0 5, 5 0 5 0 5 0 5, 5 5 0 1 5 0 6 0 0 0 5 0 0 0 5 2 0 5 0 5 0 5 0 0 5 9 • 0 6 5 0 5 6'13 5 0 D 0 5* 2 PM Illy i s1 71'1 1.� 11,1111111 i 9 : 1� 11.111 1 a , 1 1 ' .' 1 I - 1: ' l ;1 ' ' i 1 ' 4t 1 I ' e o 1 00.0 � .,... Q � A f � 4,,'(%' � e .5o 2oo.a 1.1 II # #11 II #I #1.... # #I i 1 1 1 illiiliiii' I 1 L: .. ; . r�. � ,1. , i 11 1,1, 1f r �� # �� III I ' # � 11 li 1# i1 ##111111 I I I V II a ®10 00 aaa,a , 1 � � 1111IIIIIIII1111 M IIIIIIIIIIIIIIIIIIIII 111l�111IIIIII 1100 400A Is i ' ' 1. # I IIlrII1 1N IIII 1 IIIIIIIIIIIIillli #Illll 111 111 5aa.a Rim" .l 1 I 1 111 I I IIIIt 1 1 f 11 11. I III , 1111 II 1.1 P! II I 1 111 1 #111 I II III III 111 - v ;z 1 600.0 0 I # I I I1 � l # I 1 1I l I 1 1111 1 111 II # I�Ii ; 3: AIN 14} # # I 111 I I MI LLI II 1 IIW I .. _., ## �. 3III II VIII I I II II IIII "04 # i llll # II 14.50 III I II ! # # # ## # ## ## III # *x Mpg # I ## j( ## I #f ## # # #I# ## II# I 1 BOOR . # k i { {{�{�' 2 j {I #I # 7 A7) . ( {1 #I�� # III M ! ,560 M 900.0 1111111111011/111111/111111111 2 1 !iRI iI II I * �/{ ) r i 11 s 1 j ®10.00 E I. I #1 1 I I III # I I I I in INIll ME J MILL SIII # I{ I I II� .,7 I mom! 4.s, 1000.0 � �' 11111 11I1.1111111Ii 1 MEIN X 11 1 1 1 20 0 1111111 # # I1I 11 I IIII# 110 11111 I I111 1111 � 1 I 1 I1 igi : .. 111#1 #11 1 11 IIMM dill , 11 11 6. " 1300A i 1 I 1 1111 #1 ## 1I11I I I X11 IIIIIIII # II I #11 P # #111 #1111111III 111I IIII 11I 1fI ##li -,9. 1400. 111611111 II111111# 1 1 1 1. 1 11.1.111 11# Ii1111111I 1 1 ! 1111 f I1I #I 15ec.0 � III IMP t ,I � r , I I i /111 1011/111111111M1 IN t III '' � a II �E.P . - > 1 1111 1 1 1 11111 I# ' I# #I # # IM Slim . pppppp j J!` �� III IIIII�'9�y�J1 n 16000 I� ��_ I��,l.'�:t� ; ��!9� , �� 5, ** 1 � � � �,� j ,76 6,6 � �T � 1i 1115 11 I M Fa fili 1 :>;� X 41 1 j- 1 t iiii i I l i 3 1 966.6 j 1 1 ; a 441 7 p ' � 1 111 { 1 I� 1 900.0 f I I I I I III I ,.. I II #I I II IIII P II #III�AI�� III I I IIIIIII II IIIfIt� 2000. ! 111 I ''1 , _1 # l .f CDP Spacing = 110 ft Figure 5 PHILLIPS pi PETROLEUM COMPANY Project: NPRA Pore Pressure and Fracture Gradien System Well: Nova 1 10/13/2001 K. Heinlein NCTL: 155 4.5e -5 Nova 1: PP Predicted from Se (Inline 49546) (depth) 155- 45- 30S_PPC_= N0 1 SW 0 0 0 { 4 p ' 7 o 00 0 o 77 a 77 '' NE tDP 3 44 4444441 4 4 55 5. 5 5 55 5 55 . . 5 .. 5 66 6 5 6 6 6656 0 6 6 0 6 660 6 67 7 7 777 777777 g g g 0 i gg 4 55 4 44 0 2 0 g 44 77 g 0 7 7p 0 MSL 0.0 .0 5 6 0 6 6 5 0 5 0 0 5 5 5 0 5 6 : 5 0 ' 5 0 5 0 5 i 5 ' 6 0 5 6 5 0 5 0 5 0 0 5 2 P I ! 8 .00 1 1 :, ; ; , . , 8.50 9.00 1000.0 _ • � ,� ,�.� �.,... _ �. _. ...PA 9.50 " 10.00 1 � 10,50 2000.0 ' `" c e 11.50 11.50 " 1 ,.;� '12.00 kr� c 12,50 4 d3.+ -•- :. ..''. , : 18.00 18.50 14.00 . D '^ .. 14.50 15.00 F 4000.0 __ _: _...- _�...__- ._ . ._._..._.. -__ ,_ _ _.. _ _ - -• - `- --_. _. _< . _ .-___._ 15,50 T 16.00 B 1650 6000.0 . -_. - -_ _._ .._._� - _..._ .. 17. s _ 17 . 50 18 .00 1 8.60 6000.0 - - - ' -- - - - - - - - - - - - - -- ® 19.00 -_ 4 8000.0 90010 9500.0 CDP Spacing = 110 ft Figure 6 PHILLIPS � ° PHILLIPS PETROLEUM COMPANY Project: NPRA ' 1 Pore Pressure and Fracture Gradient System Well Nova 1 10/13/2001 K. Heinlein NCTL: 155- 4.5e -5 Nova 1: PPG Predicted from Seismic (Inline 49546) (time) 155 -45-503 PPS T NOVA 1 Seismic:AtAWO_EESYIC SW 4 NE 1 CD 3 3 7 3 9 3 3 33 4 7 4 4 2 4 p 4 4 4 { 4 4 4 5 4 4 4 4 4 4 4 4 4 5 5 5 5 6 5 5 5 5 5 5 5 5 5 ? 5 5 5 5 5 6 6 0 6 p 6 p 6 6 6 6 { 6 5 6 5 6 6 9 6 5 6 6 6 6 7 7 7 7 7 7 7 7 7 7 5 7 77 .0 05 I 9590 505050506050506858885050588Si ;052 056505650505050505650685 $885950$88 PPI {� 1a '* 11 4 �1�1 ai' M 7 { ,'i1 a ai ' :, i j ill'' �� { .0 ' I� ti1.�4 a .1 11 "i 1111;I1. �.a 1 111 ? nI,I �1 1 m 88: 100 iii11 ` ii1 i y iiil i iiiii ii it Oath ry i i ii iiiii'i111`iiiiil�� gig' . 9 . ili 1 i i 111 p iiii l ® O . • 1111 111 #1 !111111 11 i! 11111 ! 11!111 !1111 1 11 1 liliiiiiiiiilliinp 3 00.0 , � ,. . 11111 1 i i 111 1111 111 1 1 1 11111 11011 ! 111. 111 I 1 10 ,,� 00.9 �� i 11 ! 11111 Iii Iii 1 1 1 11 12:. ! 1! 111111111 li 1 I 11111 1 i111i�1 !! 1 . �.i11 1 1 11 i Soo.o r ji 1 3 "� � j �3��'.�` {� Q f 12.50 600.0 1111 11 11111111111 111 1111 11111011011111111111 111y �ixli ],11101011 0 01 _ 13A0 Nu EMI P, 111 1 i .'. R 1111111111011111111011010011111111111 #011111 p 111111111`1 1 MI 14AO 111 'tMIMINA } {' I ■2 1 111 1 i 1$i ■ii #! ■� 1 1 i ■ 1 ■■ J 17 1110 1 . 9 8 00A 7J��S�SS�� `��f ] *1 1 ] � { .Li1 � #� �� .il 1! 11� P 1� 1ji1� YlD�� 11i1�11 i1�1� 1 f j] gjf e 15A0 900,0 N I 4 MM { I J 1 B 1 1 1 n i R l 71 1 1 € 7 : ., i1 s iii 1 i 'MINIM 1 0 ,,, ,00 , i .. � .... ,.. . _ _.. �. ..-.� � �'i 1 : 7 ,0 1i iii #1 ii# ii i1 ffifi i 111 ii iii # 1 i1 11111101111 11111 1100. - 1 #! 111 1 1111 1111111 1 1i 11 111 - ;9 1200 )g�jj�gj } / j 1 1 1 19,00 1:: 111< 8I ? 1 1111 Minn! 1 1 011111111111 1400,0 aligli!'41i 1rJA S .[ 4E ! /JE .d a S# � I i . I 'j iiit d .r'S 1tK1t . � 1 5 . 0 V01811 11111lt 1 1 ` 3 51 $ 11111,10 1 1111 i {E {[ gay /! i, i lIMII jX� VIO , 11 i E S 1111 11 . .•1,1* • 1 iI III yJJPW !t t iII ^; I 111111 111 111 l r R 11 1 1 E I 11 r�''.rcac. 1� Ii 1 i 1 i1 1 1 11 # 1 a ` 11 1 `//�� ..ii . 1 o s ,706.6 2 1 900 . 011111 yF aw�i .rt.�< , ,.. ' 'f:c*; '<.r+-:cs�sa '4 s-.✓r '�k' 1111 11 11 #111 I h 11 ��.M , csxs> dli�iitiii #111 i ffilla 29 o0 1i111i 1 111111# 11111111 111111111.11101.01i11i11iii 1111 i1i111i111 1 . 1 �J , CDP Spacing = 110 ft Figure 7 il PHILLIPS P 5 IrIS a EUM COMPANY Pro ect: NPRA ' P' Pore Pressure and Fracture Gradient System Well: Nova 2 10/13/2001 K. Heinlein NCTL: 155 -&5e -5 Nova 2: PPG Predicted from Seismic (Inline 49495) (depth) 155 -45 -505 PPG i NOVA 2 A SW NE 4 CDP 4 4 4 pp 4 4 44 4 4 4 4 4 4 77 4 4 4 4 4 5 5 5 5 p 5 p 55 5 g 5 5 5 5 5 5 5 5 5 7 57 5 57 5 6 6 g 5 6 6 6 6 p 6 6 6 6 6 5 6 6 6 0 0 7 6 6 6 6 6 7 7 7 7 7 2 7 77 7 7 7 7 7 5 7 7 7 7 7 7 7 7 7 8 8 8 MSL0,0 0 .,, 5 ? 505060 5 0 6 05050505 .50505060505050595060005 05 05�5 05050 m - - , 8.00 .... 8.50 Ai • 1000,0 i am , 9.50 10,00 . . "" 10.50 W104'4. :OX 2000.0' i *J - r 11.50 ' # ' ' "� I.n' — iii fI t: 4 �5.. ' t'''.' , ,' ' . d� z t � ' a 4 'a ., 1 12.00 ' 7S 12.00 „R„ ` � ' Ys ,13.00 3000.0 k t f �r rt �, tr ;t ; r i � ' �. Y K �a 13.50 r Y ., y 1 ; s • 4- 14.00 ' H 4000.0 Y ,M ,. ,c_ 15.00 15.50 P i ` Ins ,,., ® 16.00 T inn 16.50 (ro 5000A IIM 17.00 ` IS 17.50 N e,:14`-'-'''';!" ,, Ts - tit � . d¢ ,� ,.. w �, � ;: 18.00 ' . - 't ® 18.60 6000.0 -. 1, + - 19,00 -. C.," - .. - , - . � � .. � T+^.V*^ -� L -- ::z-,... C fF ' S t d � P �� ' 4 ` zk F}' 3 " Y w .. °.,, 4 kto 10 � ." RIR K'�t v ..*� r , r� '}, `yam i ' r- *--- : e z--,- mm. t ` n - - r� - *`- m''s,+_ v .rro'.rak�*^xwi > ��, x ., �- � ,.� � u ri. . , 7000.0 " !."''sc&.a'.. �' ' z -i: 'T:,# 'z ' ` .. { • q, _ - 8000.6 . „� ,. 10000.0 ‘ ... .. �t , .__.j_ ' ,;, _�,_. 5— , ,,--"� � �r`.. CDP Spacing = 110 ft Figure 8 PHILLIPS PHILLIPS PETROLEUM COMPANY Project: NPR '�' Pore Pressure a Well: Nova 2 nd Fracture Gradient System 10/13/2001 K. Heinlein ' 7 NCTL: 155- 4.5e-5 Nova 2: PPG Predicted from Seismic (Inline 49495) (time) 155 -1 -S0S PPC i NOVA? Seis\ic:ALANO EE$IIC UpK�3 S W �p a p p b � �p� � NE 5 0 D 0 , 0 { 0 0 0 5 1 Q 1 QQQ i 0 ` 0 0 0 0 8 5 0 0 0 0 0 0 0 0 5 5 5 5 0 0 5 0 5 0 5 5 ' g 6 6 5' 0 1 a 6 4 6 4 6 6 6 0 1 5 5 g 5 B 5 6 0 4 7 7 T . 7 t 7 0 7 7 0 7 7 0 0 0$ 5$ CDP 1 12 p2 3344$5 55 6 0 6 0505 5 503644 5 577.89 �. 5050 i8.0506 01 2 9 5 778 0. 50505 1 0605150 i 05 050 0 5 50 {0 60 50 5050 0 5 5 0 PP t t �� °, 5 i w f . 1 j Hi i' 'I j* a ! 1 7 i g l1 ' 9.00 100. g ti I' i I�,j. a i is � g {{ss ytty #� 4 a� jj s } 8.60 i µ �4 N � � Now � � �0� r IIII �. &', "a p � - 9.00 2 00 . 9 I iO � I �� o �� - 50 • 3 00.0 � �� 400.0 �. # t } ' 1� l � �'� i`i` ji I S !. ; 10 p{ � �j j iy j(j4 { ! 500.9 ;5� if D �� e� 1��CS .��. � .) 1 �{$� 600.0 �xj � jj ;� 3( '5151�i��t�i1�111111:11:1:1111111141111� {6 � f!i# jg { j�$[{{ '' /�j�s�{��jj�'f��lH�n( ��I�� {!� {f iiii.:'.500,1 700.0 1 -/11 l 1 * iri YS S 1 1 141 11 11 111 ifs ii /115111511[1 1111 1 1,111!1 11�� 1L4111e �A �� ;� # x�� zp�� ,Y . s�� *. �� $ :� � j jj � �� } ��1 � �� # #�� } �� )�' �� l }��P� � � sis(fj 11 ,6.� T gg�� tr qq{{ f � , yyE }} tt ?9 A! ,5, 50 ��E y s i +j 'S$) S # t 9 ! ! is { t M 900.0 � �3'S9�Stt �ttFJ FJ+!°t �i� ��f ��>t �� #�{ � �� ! �. 2� *d�2�f � ��P � �� ®, 6,� , : I , �0 ,0 rre 51r�r�i°Ss .� >t }<�t #.. ?S5 y ?C . a iintro .� a+sv �x�ra q� r��t 44 111 .4 1111 1 # } , # - t 4 ; 5 zz 1 � 18, ill n oo.o � ��t i �s��) � �� # ; jj t�t jj{{ t2!!#"fA � "�t" ii jjjj � � �� '� � � l! rr� s �j[ �!{ ��1� {j { 3flanin �� i �� t7.59 4. 1 200.0 t+i{. iI �i II # �!.�IR }y 1 8 . : 1 300. "ff 13 3 l � ;'siss. / ,� i � .. twt t g {IS 1 19.00 I 1100. l l to �_.. � y . . .�. 1, H y I 3Kat w l a ,. ilk, d _ , - .a .. 1 1500.0 , "S , ..€ � S" t iliY7S i+ �F. V i M t'1f )S ti�S+ . > r 600 .E �1Vi'�I[�1t�P .di l L }�5�1i'iil - �� , „ • ,�, 6 "1 * 1 3 / i a : I . F - att�i =� �+i'+��i r �';` " „ .ate . � �. ( � " ?:z i l i i f (, , i >,k .r 9 1) , 1700.0 a.rPt °1 s. vk 1 ,� #.,a ``wj,'k?ra�. ;. ffi ”. "•r'S°t T.�r.'g , � '+� sift i 1t' 31 $16 ,,, imS'4.'�.'� KtKd' a,:m-"�]*'.�*t ua'4 1800.0 R a s .. � .�. _. � � r�a,a'J" D � e'. `Y� . � 1 s ' d 2 � � tl � 1, a ,. ' 5 2000.° , ail rr 1 -tai_ t CDP Spacing -- 110 ft Figure 9 PHILLIPS P �IL i �� CO MPANY Projec NPR Pore Pressure and Fracture Gradient Sys WeII: Oxbow 1 10/13/2 K. Heinl NCTL: 150- 4.5e -5 Oxbow 1: PPG Pre dicted from Seismic (Inline 4947 (depth) 15l- 4S -S0S PPC 2 i SW NE CDP 0 000 g p 003� 8 0000 7 0 0 0000 0000400 000 0 5 100105 0 51 1 00 5 560 0 gp 3 0 6 0.50 000 00 0 0000 000 0 0706 6 gg 6 MSLOA 0 5 0 6 5 0 6 0 5 5 0 7 0. 0 5 0 0 0 6 0 5 0 5 0 5 0 1 0 5 0 5 0 0 0 0 5 5 0 6 1 5 0 0 0 0 0 5 3 0 5 0 0 0. 9 !!! i*" ".. �, _ 8.00 tg, aa�a 1000.0 - - - - - - - - - - .. _ ,� _. _.____. .:: 9.50 t � 10 10 .00 .: .50 4 11.00 2000.0 � ,:_' ..t _ a- - y. t - •- _.__- _....._. .. 11,50 ^. 3Y*ti„ .d .... 12.50 T _ � . 12,50 , ._ 13 .00 13, 14.00 _ � 14.50 4 D 4000.0 k :>` �{.' - 15.00 . ,,-., .. ,,,..,,,,,,..,,,... • p . 1 6 . 50 i w 2' y n - - 16.00 0 600 0.0 '"r'- d '` 76:'''''77:!"'- 1 - _ -- - - - 16.50 s ... .- - 17.00 ..�. . � . � , - � � " � , . ��., 17.50 �, A 3 y � L C . � ��e �, *� hs .� 18 .50 Mk ` : a ,s. `3 i ¢ a ' "u... :rs ,'. 18,50 6000.0 _ _ �„ - F r ® 19 .50 il 7000.0 i ` ",` 8000.0 '1rs£'` $ a s . : d , , X L .,. a " g, pp 8000.0 ( � r N 10000.0 CDP Spacing = 110 ft Figure 10 PHILLIPS PHILLIPS PET a EUM COMPANY Pro ect: NPRA : ' Pore Pressure and Fracture Gradient System Well: Oxbow 1 10/13/2001 K. Heinlein NCTL: 150- 4.5e -5 Oxbow 1: PPG Predicted from Seismic (Inline 49471) (time) 150- 45 -SOf PPO i OXBOW - Seismic:ALAMO 18$IIO i��CpS SW NE 7p CDP 2 2 3 3 3 3 5 3 3 3 3 q 3 5 3 3 ggg 0 3 33 3 3 0 3 3 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 5 5 5 5 5 p 5 . 5 5 5 5 6 5 6 6 5 5 5 5 5 5 5 7 6 6 6 p 6 p 6 6 6 4 4 6 6 6 6 7 6 6 6 6 8 5 6 5 0 5. 0 5 0 5 0.. 5 0 5 0 9 5 4 . 5? 2 0 5 0 1 5 5 0 5 1 0 5 0 5 0 0 5 0 0 5 1 6 0 5 0 6 5 0 0 5 0 0 5 0 0 5 9 ON 0.0 ;. ' I ' _zi r ! + 1 ! i } ! ' 8.00 y •� Li, i i l 3� 1�" + • �y� { gg+�y� ��'i i � � � � f� yp$ 1 ',. 2000 Iii ii i i pg,� fiiii i � lli ii ii hi iiiiOIiii ii iiidhii iiilIfiit �d dIIlIIIf lili li li# 1 fffilini u 11111111111111 II 8b0 308 0 IIII1III1111h111l11I 11I1I1 O1 1N 11111111 1111111 111 111111III11111 1 1001 1!111 1 11 1 h 0 • 300 _ �; 10.50 l 1 on 111 1 1 1. 1 :..,. 1100 400,0 i:� � � ��11 �� jj(( . '� '�` 1150 '��, ,. s1 6 # l 1200 11111 0 111 11 111 11� 1111MBEM1111 1 111111111111 11111 1111 s 11111111 1 111111 (111111 111111 1111111 13 700 0 t �I 3II111111111111 11111 111111111111111 1111 1111 111111{ 11 111 14.00 ,, r ., r S�CSS 1 155,1 � - � i ; "" 4 # { i { 14� e oo . o } fillif l�i lif !1611 iiiiiiiii �i -5i} 1 i rst 1 111111 1 1 111 1 1. 11 11 ! . �C ��u;�] } j g\ �(j3Iy� . {(� tji�! jt I . I H I Ii Er-'<2 '[[ g ii#fil 15 15.00 ,!��56i]ilfL6�2 + 50 ": 800 j i K 4i'R' � ' Ff t ♦ ]i IMBi igiii f tiM, IM 1550 psi 1000.0 �� #�� #�� ;�� 3 � �� I I i i i x > 1 11 lEM III i3u i 11111111111111illili i tillitiiiiii - 1 '7:7 12000 t 111 0IUI 1�1� 1 jj �j f!'. 1111111 1111111 011111111111111111111111111 1 111111 I 18: 1 3000 ll f 111111SS77721s $ { lii ] ¢ ii 1� � �� ll ' i ii . 1 1 111111 )11 111111V j{ 1111111111 11 11 1116 1111 1ftj {jA Llilil ji1I1111 11111II1IIIi11 1 � { i l 6!!1 1 i iiiin i 11tg a •C _ 36 : imam f Al 1 '7 1 .R MIIMM if 1 4 . 000 � � i i 3�b�a��'E ggg � I�€� �„' ** jj [[$$ { p/ � 7 }� �� f� j J j }� {�y�� M ��( �j{�[j ( j f ) { �y / i�� '�{S 0 15 iI lir ij VAMIIIIMINIMIIIM , i OVEMI S I g71 g! f 'B E IMMIl a 1500 a q -+ Zh • r �- •" 3 A 1700.0 :�4 f !! ' ..A #k `fr t ie �z ' d R -�.: s is s t.: ' "' , �., . Hea 1 it z tf 111 18000 ,:. . . ...ai9 .,,,�« <•....- ..,..r^k..,5.lyd ° :. rr8 1 9000 II ;Aril � a 111 1 , 4 '� ' ` 'l11r g 4' . : ; , • '" it '* '1 " 1 5 �l iy lk kr, it 2000.0 ,4'. ,<�"sr''��+r�'. ?� t �- ��rdl YfY�3�`ainl��°.::��"tiZh.'n .� di 'B vtia.�. s,�o� ". .9rr�` A.a �z� ` ... .� , "{` •s ...... CDP Spacing = 110 ft Figure 11 PHILLIPS �� - PETROLEUM COMPANY Project: NPRA Pore Pres and Fracture Grad System Well Rendezvous 3 10/13/2001 K. Heinlein NCTL: 152- 4.5e -5 Rendezvou 3: PPG Predicted from Seismic (Inline 49607) (dep 152 -4S -SOS PPC} RENDEZVOUS 9 S W pp pp pp p p pp pp 44 pp p p0{ 4Y 44 5 pp 77 p Q¢g pp 1 p� yy NE Pii CDP 9 0 6 1 1 2 2 3 3 4 4 6 5 3 7 7 8 9 0 6 1 2 6 2 1 3 4 5 5 5 6 7 7 8 8 9 8 0 0 6 5 3 6 0 6 0 b6 0 8 0 5 0 8 9 7 0 0 1 6 6 6 3 3 4 6 6 0 6 7 0 0 3 p! MSL D.O A � . �q 9. s 9.00 1000.0 w w � x E3 ,w , 0 f °+ r ®10.00 a 6aa� '* . . s r te- ; �°'" ' ' : "S,` 18.50 2000.0 F ; s� t rr ,, 11,00 .. t xi 11.50 ° . x 1 , t 9 , +t r 4 r n +-1 v"- + l € 12 � • t ... .;ct Y♦ .+d.►r � - - i.. 'n` -s; 19,00 0000.0 „"......,..7,,z,.,!: '' q a r &? .. g x '* 3 ,,,;34,..,—,,,,,,,4773,-,..t. 14,00 EV 13.50 �, + ..” „....-r- �. � �, °'-`t � � �, , ' r - r 'k J ;ttw 1 4 . y " 14.50 4000. 4" � a 15.60 0 E Nye ; x 15 • T .. ' ` **, .."" , . r � ® 16,0 0 N � * s _ 16.60 5 000.0 ,, _ s ,. '� , �; -irk r ». `- 5 *7 � `�" 1T� f,., _ s - - ' 17.50 . M g FFk ' 16.66 6666.9 f .r » n1rY..t , ..,.. ..ir& 19 59 Y.. .. < <.' - t - y 'T 9 r tt' T �,,µµ f 8 L 7999,0 "�"' `Y.VM.^ �. t:tni �' 3.}.+J' �s Ti: a'4. 'x .�'�:x - ,_--',, , v, Q a F - ..-*. ---;::::-:' . .',,,' ,,,:,-,.-',.„;,,.. 9090.0 f } 9600.0 �# . ,�� w 10000.0 ' , , . . .r CDP Spacing = 110 ft Figure 12 PHILLIPS PHILLIPS PETROLEUM COMPANY Well: Project: NPRA Rendezvous 3 . ; A Pore Pressure and Fracture Gradient System 10/13/2001 K. Heinle NCTL: Rendezvous 3: PPG Predicted from Seismic Online 49607) (time) 1S2- 4S -502 PPC T RENDEZVOUS 8 Seie ■ic:ALAWO ESONIC NE SW :110'3. 0 p o p aa o p 0 p 0 Q o 0 p 0 p �p ' pp pppppp pp CDP q 3 3 3 3 3 3 3 3 3 3 3 g 0 3 3 3 3 3 1 4 1 1 p4 4 3 Y Q 4 i 4 4 1 4 4 4 1 p 4 ' 5 5 5 5 5 6 5 5 5 5 5 6 5 6¢ 2 B g 5 9 6 6 6 6 6 6 6 6 4 6 6 ¢ . 7 7 9 0 0 1 3 3 4 4 5 5 6 7 8 5 : g 0 0 1 1 2 8g 3 4 4 5 5 6 7 8 8 0 9 9 0 0 1 1 3 3 4 4 5 5 5 r r UUUUUU 333993 55 nn o 0 0.0 0 5 6 0 i 0 . 5 0 0. 0 t i 0 0 1. 0 5 1 0 0 1 1. 0 1•" 5 PP! s ,� ; . & ��>Y�Iaii 000 ,100 � �I� ��r{ �� I <�� 5 iit 200.° 1 1 I I I I 1 I III { I II1 { 1 {I 1 Pill I IIIt I I 1 { { {{ { { J 9 300.° I I 1 11 I I li .1rw 1{ III 11 I ! I � i 4 I I 111II 1 11{ I1 MIII I1I 1 11I I I II IrtM �1ll.. >, 11I1III11 I II 1 1I1 #I11 { 1 III 11h 1 1111111 1 1 { 11 I II {111II 11;111IIflllllll {I { 11II11I1IIIIIf1lIil 11.500 5�.5 j( I {{ 1 i#IIIII II{1i1111111{11I ii iliilliil{ 11111111{ 1iil11iIIIIIIll111 7��b��{ � ,2.50 00.0 � ,3,00 ��. ° ## 111 a 111111 11I111I11I1 I111111l11 II111I11I {1111 I11I111 1 II I1III1{ #1i # # I 140 1 11 i 1 11111111 #11 { 1� _..1111111 1 I VIII 1 1 � #Ill }111111 800,0 } -� 16.00 T h S Q { {{ j{ 15.50 M 900.01 #111i1111i1ii1 iFf i'Sif7`1tAER�LT[0Ii �7 A ;1 15.00 Birj n� ,�°.° : c, t11 . l f e !} / it { } 5 [ /y�{e�' )) ;rte 1100.0 11111111I111I1Ilili F [jiiyj MIMIMI j] f` /jjr ■ 18,00 1200. 0l 111'1i�".J31'S #)3 +iEM[3�iR 3i� - .10. ��1 � �� 1��1 #1�11� � . I 111 111 I1I III_ 1 #11 � � ,9.� 1300 i 1 { tiyc�, SS {5 c�q � j {� !�{ sij) '.�f" � ,��¢j ss 4 ,400 1 { t l i i? j � S Ct i�tlejz i+ {$fi i t R � l ! • xj. {j {�}; D fkP j / 1500. f : 1 ^ 1 .4 1 1 11711 I a ® R LL 1 R 11 11 E 111,11 _R, Y { i{ ( i i_il j Q� L ij(i .{: , .vl'il r'.2•"". �Buvi :y7 t 1000.0 L. ` • � �� 1 � 4w � � j ' � � +0 7RS 2 7 1 �'7 5 T if ft� P 1�_ . a 11# ' J l l W R O 1 1 f 1� ' t ` 1~ 1700.0 x : . x ° kali lam ,, #jets 41.`. 1 # ” i ill% 1800.0 3i N "a � 1 6,0 -c m�. ! # ,900.0 .M .. b. i ,. 0 4,1,m14: .fa �� ing 2000.0 ��_ .r :, _ - i�1419� Figure 13 CDP Spacing = 110 ft PHILLIPS e ® PETROLEUM °�4 ea F ET °`: ` Pore Pressure and Fracture Gradient System Well: Spark 6 10/13/2001 K. Heinlein NCTL: PCO ect: 152- 4.5e -5 NPRA Spark 6: PPG Predicted from Seismic (Inline 49800) (depth) 152- 45- 503_PPC_t SP� -6 SW p p o NE • 1 0 g 0 g 0 7 0 7 0 0 0 0 9 0 0 0 0 0 0 0 0 1 1 0 0 0 0 0 0 0 0 0 4 5 5 6 5 5 p p 5 5a 5 0 5 5{ 0 5 5 5 5 g 6 g 5 7 5 7 5 8 5 6 g 5 g 6 6 0 1 1 0 0 p 0 0 0 0 0 0 g 0 5 0 1 0 0 1 0 0 0 0 0 0 0 11 p 0 0 0 0 0 0 CDP 6060 0 3 44 4 4 6g b g i 88 8 � �6 0 6 0 6 061606 0 60 b 05S6060606 06060 0 6 66g ig00 06 , 3 4 6 7 !N 6A0 �iv.u. . ,.,.. . , .,,, 4 „ +. ,.. 850 4 . 9.00 1 1000.0 , °' h r , F a: fillo t s A , „xa' � + 6; „ ,, 4 ,� .Lns 'r'< ` .n 10, .qc e% � �, � °�` �ar � � r., - 10,50 .,a, fib`` 'tS - .� i '' e� 4 `"-t< a `ice. ° ^� w,;.„'�' y 1100 2000,0 t. 5 a'S � k`= J ^x�+. � , ''4" t2 ^+. '� -- '' 3 s .,, a s.. t , „z a, * '1 ,.� 11.50 . 41 Al % .� "w, 12.00 «` n s�} . «.� ' < g .- 4 a s ; 4 .: Y 1 .K. f 4 ^ ;5 4 �... . 12.50 0000.0 � z S . ��'� � +,st,� ,& � � � � � 13,00 t ..e � 3 .. �` ' '''''7' � ' � 5�1� p� � � ,t� : � ak `�- - 1350 t ,7..r. a'} °`�" 14.00 nd. „ D 4000.0 r ' ' T" — s '"" n 1 450 E fi +..; i - { t i p ®1550 T " i s1 ° _ e �... a p " ® 16.00 5000.0 ` 1 -�i' 4°s=M1. :e, t u : r ;:,,2- - r .:,- --- x — wti r +�s..r x 16.50 ID +� A - -. ' r 1700 —,:t ..... , —:.- �� ' i l e ' - 17.50 � +t°# ::18.00 6 000 . 0 !- c V . .. a r - -k.. .@ 16.50 a a �` 4 .�. -t»- .i, ® 19.00 - 9. ' 71 "�"''o�. k r`` fi r " r � 4 '. F . - p=ro : 7000.0 I - "' .n.f `.. ,w eixle ^` ° ; 1 ° ,..-u u.° acid • � - � v : .+' ..,".-,5-1g'-:,::...41-- 6000.0 `' .;:-. , p ' .9660.6 n S , -- , .4 Y# e i " +• M k d db '"'Y kq ' d CDP Spacing = 110 ft Figure 14 10000.0 PHILLIPS PHIL PS PETROLEUM COMPANY Project: NPRA Pore Pressure and Fracture Gradient System Well: Spark 6 10/13/2001 K. Heinlein NCTL: 152- 4.5e -5 Spark 6: PPG Predicted from Seismic (Inline 49800) (time) 1 152- 45 -60E PP0_1 SPARK 6 Seia.ic:ALAMO JUIN SW NE bb 'bb bbbb'b�b bb' bbbbp b b' bb b , p 7 pp t1 bd'ob 1 p�b'ob�p'bbbb p ' o bbb p'3bbo CDP 0 8g 3 3 3 $ 4{y 4 4 5g 4 4 4 4 5 !i 6 5 6 g 6 g 3 53 g{{ 55 Q$ gg ' ¢ 5 6 7 7 6 6¢ 77 7 7 2 7 j 7 4 7 7 0.0 5 005051 i . 0.is�gb.,l05i5•.�.0606 .i i i i � 5i.�5i6� i i i5 Pp S.00 100.0 .:_ .: .- 9 860 200.0 .Is .04 ..:.i Mg : 111114. N 0 4 . irgal -APS 166 ' sze 300.0 I IIIIII 111 I III I . .. _ `l �a 1III {i � l - _:: ....� � ` tto iiii i I .; i n i i l VIII II 1 ;a� IN 11111I 1 11 II 11I111I111II11 1Iinhied111 I Ill I 111111111101111111111111111111111 „.60 • 600 111111111111111I11111I1 I1 I II11I1 I1111 1 IIM II II III11I11 1111 li 0011111111I1111111111I111I11 121: 900.0 III I 1ll 1 11 (j 111 11111 1 1111111111111111111 111111111111111111 13.00 i 1 1 i *i 11 III Ili I NI 11111 #1111111111111 1l 11 111 1 - 13,50 700.0 . EO UNIMUUMMO 1 I 800,0 }P 3 }"14191 A I{MORMIR (j _S rommannommommon ' mpum ii! t i 15 ,50 9 00.0 1"t4t . °4P-5 {t ' ktgtttlif � lii' { , js c '' FS yj tom" {� 11 i iiiii 161tilIR 'I)C 1i a ill", # 3 i 1 p. 011 IMO? t IM +tT3 ' 18 60 ,.,I 1900.0 1 III 111 lllllf11I 11111I11 N 11# 1 1111111 l 1 111 I 111 0 III .. ,77:55 1,00 - �. 4,1..111 1 � 1111111l 1200.0 .j�ffil �j1 1i $$ ii 1 11 #1 I I I III i I 11 JI I : 1300,0 371) H11 Y 1GZr i j 1 I i 1400 lLl �f}M*�s�t��{ � g *gLfI 3$$ajjrr°G$$gga � ��N NNW ��) 1��i.; j��1��5��Y 3�t 1500 `f if I 1'#111 t1 Y i I y LS lei i Ill 11I 11 ltitft4!9. � � S + i' X91 hl!t. ! 9kati �1�!!ltti l� I I � .: ? , r ?; . 3131 N Ei 1600.0 .Itr - 1Z,.... i „[e.n . °1 : i4il JWii.s •_ ;4 I'',h -. ., � . _ .. < 5,s s,a ... .. - : _ 4. •- 1 11 y ` * ( {� `q q.'qq ' q 3j1.1 ; . lid. , _ l { k 4 1 - j y e y 9� i 17 001 t ..@ —i 4 7.. A k �� 1 if` ;* •14 P. + 18 44.1444f K•f d. E 1 .. 4 # N 4M @. AMA, A @ 'z 00.0. p49._ ti 0�•. .� I11I I Il I i I VIII i ill 41 II I I _. ICI +il 141 1 1 11 1 1M I11 I. I I I l li l i 1900.0 . n "�:% 'a� s nt sr . v t 11 O RIAI I . ,;: 11,1, t A$ 411'4,,' jf ”' APAIM it i l li r' 2000,0 .- - ��.... -..s4 " # -4.s.t°Lffi84:CG.....:oa-4c �{ ism SSi.' k.' S9dSZS 'C151:.0:��.i1)"�. -x n., % ... ,n k.� �? wa61 r. CDP Spacing = 110 ft Figure 15 Project: a c PETROLEUM ® rs ��qn�� n a e ®® ect: NPRA Pore Pressure and Fracture Gradient Sy stem Well Spark 7 10/13/2001 K. Heinle NCTL: 152- 4.5e -5 Sp 7: PPG Pred from Seismic (Inline 49912) (depth) 111 111 151-4S-605_996_2 SP SW NE 1 11 1111 11111111111 115p1 1 j 111111111111 1111111111 8.00 AR 11111111111111 111111111111 1 11 1 11 eDP 9 595050505050 5 05050 5 0585050 5050 5050505 2 05 5 0 60 50505050 5 0 5 0505050 505 050 505 52 086 MSL 0,0 r z ...:,. 1 ,8•50 o s. rc 3 3 3 9 0 .a. . . . 9 .50 0.5 1000 4 . ,, tit-- , w-, > *',.7,,,,:"."';,4 Re a„ i �° 10.00 s a ` - : 10.50 1, .. s ,2 > '' .. .a••y*{, Ifi� .: ,,,�+ a +:. i .+-' �r Ewa r y� # , .a a z � ..; .. ' . '� r ` .. " a � k ' 11.00 2000.0 � x i ' .0‘ . ... � 11.50 „if •� 12,00 , �, ... i 13.00 3000.0 „n., r .:. _ .. < f° 13.50 74.0 D 4000. `.,°K --.i E ,'uYr*: ', a P �. roar, .,---.I-',1-417:. t T t5 ;p. '„'” r , . f . '^ � m 'x . 15.60 18.0 H f� a ;�.; .a + m =.. +ta a 01 5000. ik t 17.00 ,., ` "" r , - - ' s „= mot. „.. « a x - > ,�` 18 .> +��s 1 fl. � .-4=7'47...r.;4- I, 1 . c` ' f'''',,,I, ' 40 6000.0 " V. � .._ 4 'E. 3u . ,. +x: " .r b »G 18 50 . ti � � ® 19.00 .- .-1111....1-...'.:',;..4' -. '''''' ''''' ' ,':,:Ze:1...0 ' -0 II F �! - -A t -:-- - , ra ama.en * ,tv 5 8000.0 '17:. - o;» r ar s•"- x”' _ Eat. man. 1411 14.11 c7 i 740, t f p w ' . . ,t, 9000.8 • �: 10000,0 CDP Spacing = 110 ft Figure 16 PHILLIPS PHILLIPS PETROLEUM C MPAN Y Project: NPRA e 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 Online 49912) (time) 152 -45 -505 PPC 1 SPAR 7 Seis.ic:ALAIO EESW0 SW NE 0 1 1 8 0 0 8 1 0 0 0 i 1 0 1 1 0 0 0 0 1 1 1 1 1 0 0 0 0 0 0 1 0 0 0 0 0 0 0 0 1 0 0 0 0 0 0 1 1 0 0 1 0 0 0 0 0 0 1 0 1 0 0 0 1 0 0 0 0 8 0 0 0 0 0 0 1 0 0 cDu/ 00 8 33 88081:848140. 4 8818 888 .886. . 011-5 8 ? 888 7 10 . 4 Ph 1 8.00 3rII 100.0 _�Mn� f ., ■n ^� 4 �: 8.50 ~ !1. r �� tic)1 i 11116 iiiii ` i idliii itg : .M 6111 RE 88: 200.D 1 JifflJJffJJ fl ffl fflh1 iff IO ff 1 ..,a � 11 1. 11 0 11111111111111 MIII111I111 I 1 I li i � . 11 lI 1 ®0. 0 • 300,° 11 II 111111111111111111111111111111 1 11 1 . 1 II l 11111 �� . ;10: 400,0 !! 11� {�y� �f ill liBRifll�f 11�IIll4 +,,.:1200 5000 ; .1!�l11 I Illullll1Il 1 lllll 'R 12.50 D�.O 1111111111II 111111 #1!11 ]sus) 11 ■■)1`lI 1111111 1 1 ■ 1111111 11111 1111¢ / 11111111,tM■ .. 13: 7 00 .0 � W RO I I MMIMM IIMIMMl I 11M11l 11 1111 11/1111 1111111111111 l 1111[ il itli I 11 ® 14bD }] I1 11111, X0.0 ;'� � }} II * I $ ��I �� F c{ i , 1 { 1 ij i� y 1 � 1441 1 jt �11�O jf� 2�24 9iF7 � IMEIMIMPPIMMMORMINNEERIMPRIBI E j$ t 111 al ,5.00 00 9 T 3 3 RP 11.1. 4 11 { d111i 1 51 151 i 00.0 5:. e «Z? ✓? } ry a E « «3 11111111111111111111111IIII I IIIIIII1 11 i s 111 - � 11111111]e1 ' a i i " $f .18. ,.s 1� D. ,. - 4 - , ... , - ; ill#s 1 1 1 11 lllll lllll lull llINIMU llllll l 17 0 }}ff#jj {j � 7 �Z11�_Ifllllllll ll 1111111111111 1 1 1100.0 11A111 111{1`.1 1 X11 1111111 S[i �,jj +j� fir! { {f+{ 111111101111111111 1200. }}jj 1`i *$$* 111 *j ) p3 lI ill l i j $ 1 ,1 1 1 111 1 1Mi I a l:::: 0. IAII � 1511�.R 111 1 111 11 m 111 1 1 111 ! 1 I. 5 1 11 j 1 1 1 t IIIII IBBI t l 11� { { 1i X11111111 � la 1 111 �1 �� l II 1400.0,, H 1 e M ]f a' .-� 11111111111 ]111111i11i1_1111 � 'I�9E 130 `a�•� 1 600.011111111 111111 11111111111 » ® :„ ' 1 14101t#i � P Ii", r1RAtilty3tlitbia ; �' ftiii` igt 4 '� - 1� 13133 r IMI IS w ... ? 3.,4 a i *'. 1600.E {y� 1 ..... �.[ga. -at �Z{ nic'!t 1 P°dt 41 .k 0111 $ '® " , aa; 0a.r s, b 1700.0 � 1111 I n �" '�4a0 "; �''y} 11�t,' Fl ,r�r fi i7� a e�s #s a 1, "� o r s a s :p - �"� {) �x .4.' , h�.., <s�gg.g 0 i i 9 it ¢ irP4 2' lil �i .7 11 18 1 7® na V 1800. 1800,0 111 111 ll q; 111ir l 1 III 111 111 11 1 Y' 111 I 1 1 11 1 III *I .t �P.1 1 111111 111 1 CDP Spacing = 110 ft Figure 17 1 PHIIIIPS € H LUPS PETROLEUM COMPANY Project: NPRA ' Pore Pressure and Fracture Gradient System Well: Spark 8 10/13/2001 K. He NCTL: 152- 4.5e -5 Spark 8: PPG Predicted from Seismic (In I 49993) (depth) 152- 45- 50S_PPC_Z SW SPARK_8 A � p 0 1 pp pp pp 1 NE 0 0 0 0p 0000000000 0000 i0 1 1 000 0000 0 0 0 5 0 5 00000 6 655 000000 p 11 o00 1 CDP 33 g 9 3 9 3 39 933gggg 44 44 4} t, g 5 2 i 0 . 6 6 0 6 6 6 6 8 6 6 6 0 I 0 2 2 0 1 7 8 0 0 1 2 3 • 0: 7 0 i l; 6 6 3 4 5 6 ¢. 7. 8 111 2 2 3 4 8 70 7 108 MSLOA U0 3 85485 ' 6000 � • 8 605 5 v 50 5 5 6 6 0 8.00 8.50 9.00 • ,006.0 I , ;?+ N„g "S ",'+�'� =v„. w ^",vs r $ ,44 :> ''''''N:::1,,,, 4 t 'r 10.00 , 'u .# w Y n #, z. .. .� ? 1050 200 _.... ' y 71.00 11.50 ' 12.00 3000.0 ., „. • _ _ 12 60 13.00 _ ..:, . 14.00 D4000.0 -- ...... ^•"4 _-- ^._- -- - -- -- - - -- - ,, .: 5i - - ° - h x r T �•� �.... 16.00 fl '� -• �' 10.50 , 17.00 - 1750 0000.0 . -- a__u _.� _______._.`..._ ___ _._� __-- -- _ ._..�..�..,..._...._...____`___ - 18.00 7000.0 - - - - _ -- _ ._�. - .�. 6000.0 . , ma x ` 1 ''-',: ., 9000.0 y .0.- • � .. - r„ _ <. s°'A.i�LP . yl T -aj 4 l:” ..:°:- Y , 'p4 V - '$ Y w, -- .. ��u. 4l.L s'�- •EZ�i +. ."3 -" . _ :�.„ I , 10000.0 CDP Spacing = 110 ft Figure 18 PHILLIPS PHILLIPS PETROLEUM COM Project: NPRA '' ' Pore Pressure and Fracture Gradient Syste Well: Spark 8 10/13/2001 K. Heinle NCTL: 152- 4.5e -5 Spark 8: PPG Predicted from Seismic (Inline 49993) (time) 1S2- 4S -60S PPC_i SP e $,h.ie :AL1W0 EEEYIO S 0 W 0 ' '' pp 4 p 6 g Hi o oo ggogoggg NE CDP3 7785 5g 1 33 15 56677 ` 788A9001 1223 33 0 4 15 56 ' 5 88 8 8g5 8o8 1 2 3 0.02. 0 5 6 5 0 5 8 6 0 6 0 0 6 0 6 0 6 0 5 5'• 0 5 5 6 5 0 5 0 5 f 5 0 6 i 5 0 5 0 6 0 6 0 5 2 PH 1 i i 4 8.00 100.0 Nr �� .-,,. a: Jay a:. « a r , �`� j# a 200.0 ...2 �� iii aina�..cray.�;: _ . � r Al [■ .1�� 111111111 i 111111 l i1i11111 1 �1 � 1 ,. � 9.00 300.9 ' ��1111111111111181iD11111111111 111881811UI1N #1118118�1U II�IIII 111 1111111110011h um :.: 9.50 • •,000 1290.0 i111111111OI111I 11 O 111 I11l 1 11111111 11 1 111111111111 1# IIIIIi 1 ;, 11 Il ^ �1 1121 1 1111 !� �� 111111111111111111111111111111111111991 I !�� 1 1111 I '"--'411 1 1111111111111# 1f11O1111#11N1 1 .�. 1 11 I1 I IIIOIII I r _ ' 13.50 12. 700 : $3 ii ,a tJ ... # Iil h IlIIllhI ll1 1 III ( . hII)I ,x.00 11fI1 1 1i 1450 #11111 � 811�1 111111 III III 11 SIXI' M 909. i 111 11111111F « 1 1111 site I � � Two 11 R ili s 1a.00 i ,8°0 1i #i1iI1 II i i� f t 1tl a Iii! i i i i iiii ii i � �i ;�1 #1111 ii11 h1I0 1 11111111 t11 Mill J #1 1211 11 I i1 i 11111 IMI 200.0 . 1t1111111111 1 11111i11 #11111 #1 1 1 #.1 111111 : 1 11 1# 09„„1111111111 „ 11 1# 1 11 1 1 11 # _ ;a "a 9111111 1, 11111111111111111111111 #1111111 1 11 111 1 111111 #1 � 1 11 #I# 1 VI A 19 1400.0 �1i111i# i111111111111f1 f11111111111111111i111 #11 1111 1 1 111111111 I SI g Ittil�! 1500 0 111111 1 1 1 1 11 1 1 1 1111 118 1 1 1111111111111111111 11 11 � 5 �� • .� »a I I gKiI $'� M R �� '�� M UU � i J ]i ,'�� s srsy>, . „.,. .�. , 1 BY JF 1/ fr.. S��JTI� <ti....x..r. - ..-.. ...., ..ra• F bT #fJ! F.ES XP 1 1 11 0 , > __ � . .114$4 . 1soo.o ��ii;+Y:, s “ Rat li - - - ,- ' rxss t t � # mod ;7i31r��;�a��tti- i . s , 1700. Nk .� , i i it r ill 7..- p �j4 x� r Ili 11111111 , .�11111 � 1 11111111 1 11 1 11 ,800.9 1111 1111111fOE i11111 11 11111111 1111 1111 1 1 111 1 1111111 1 1 11 1111141 1 : 1 . 1 1 1 1 111 1 1 1900.0 i o .;_t_t a gg@ � , . ,�... �� .. qA i�AI � �� T 1A� 01 '� $44� '. -�-... -.. ' �N .�,.. -. v-e�, g .,< .. .” s " $ , ' ”. rvs ,,: - ««. r .., . .., 2000.0.. 4: s `.4..as. :asYr_..s. �L51i'itili?: t17:IAA S sSii�it 7 t$3tJt2lr�YylYl}t$ I► i`� l 0. .._ ��..� t r. _ ?� d � CDP Spacing -- 110 ft Figure 19 PHILLIPS Project: NPRA PHILLIPS PETROLEUM COMPANY Well: Lookout 2 Pore Pressure and Fracture Gradient System NCTL: 155-4.5e-5 10/13/01 K. Heinlein Lookout 2 (Inline 49540, Xline 10845) DEPTH (Datum setto MSL) FEET MSL -- 17, - .I. - _, -- L - itr • -_-,- 4 , . _ r-- ' 1 ;, .._..L. . f f f , , ; . { IS E.; • _L. ' .1...“ l' i • _,.. • : • , • ! : - ;• 1.• - •-• 4 i 1 j n in - , ' - •-•:- --" --:- I n -4 'il-t-'-'•-!-'11 : • ' . -- I • • ' 1000 ..•••-•`. "•;-"-, " -4 , .• 1 -P.ii ----1-- -7----r el +L.' -1— • - ,--- , 1.1;. 12.1 - - . i " - ' - F = : . 1 , .. -...,,,. " I -- . !! ' -.E , - --t---i-l- . : . -.-±: g Hi :Mug 2000 : 2000 • . ' : , , I " ! I - , : ' . • I . . I ' . . • , : . : • ' _,_•... -__L.... -.1._:_. ..;_:).......... L.:_,. • c 4.; : ...4 ' - ' 1 . - -', -i- ;•- --> -;--;.'- -i.-;- --- ------ • 1'1 - il - t - r - - r '1 Ai, . • , ..1. , r . r — ;II i . . r il r - -- i — -'- --,-- _._ _ - 3000 '' : : : ........— W " - • : ? : 3000 _ --,-.4:=L---H — I , --- -. ■ .-1... •- . ,._ I il m AEI ___,_ f __ , _4_ , 1 1- ' -1-7-t-1- -_ 1 -I. , __. ..-.- 1 -11- ... 1.1 r.,t I ._ _„ -_ _, - i ._ . _ . --I. r' 4 . , r Li _____;,_ 1 • t _ 4000 ; 4000 i - h i r ' M WV ti i 1 i i i iini t, i 1 .. • 1' r" " ' I' 1-1- 111111111 , • " T._ 1 . . _.,_ ! i ---4--- - _ • _I ___ r--. --, woo . -- __; , ---1.---r.. -mragr -..iird Luna I I-- i , , -1 „._._ .T___ ' 6000 ' L_ILLI__LL -: t''' - 2 , - ■ . LE it: 1E9 1 di i : = I__ ' ,. i " 1 . ' + P .11 i —4— 1-- ._. —, ; r f-----i t • 1 --- ..1 - t , 1 - "r - .1 , ....... MO —1 i - I MO I ; L 1111111111 7 ■ ra i in 1 ' , I-1 I 111111114111,01 - _ - _1 1— . . _,, 4 r -- —I • -- I 1 --- ... 1--- 1 -- i i .-:1 I : - I EIPB11011111111111 • • • li ._ __i__ - _,L ' 1 i _ . ._i_ -- im nu ou inti ...._ • r 1 — - I - --- mom asa nOlurdiROKRAilit --'---- I I • -1— , , 7000 7000 ! W 111111111141PIIIMI : ___ _L 1 l it tri BEM .-- 4 - 1 --- i V -1- , ' ___H___ ! _L_____1__ _,_ , Emmilimammi pi 5100curiimil . 1 -I-- - . 1 - • min 0 Illeriims mitajnin um Full 11111 : I I , _....i. ..,....,.. . , , , . , , , i , . .... norm t pm 1 I ; 8000 0•1011111111•INAN talli HAM I f 1 ; i 1 NI .. _.. . _ .,,_..._ . ..; . .,...._.. .. , I. . i ... , . , 8500 : me .tal £-- ' 1 1 I 1 ______t 14 8500 40 60 80 100 120 140 160 180 6 8 9 10 11 12 13 15 16 17 PPG rim Intercept dal .155 Logarithmic Slope -5 a -41e-115 -0-155-45-5 i 0S PPG z Figure 20 -0- 155-45 PHILUPS Project: NPRA A PHILLIPS PETROLEUM COMPANY P ore Pressure and Fracture Gradient System Well: Mitre 1 � � ` Y NCTL: 155-4.5e-5 10/13/01 K. Heinlein Mitre 1 (Inline 49567, Xline 10712) DE MSL (Datum F EET m setto MSL) SL MSL ! 2 ffi _L 1 Yr t 1000 i _.. i � . � , s 1000 ¢ 1r' ! r ,l, TT. .`dHl ... _ _ . Tt, r. ., ' ij i.. r .. 2000 2000 4 i iL � , � f . .. J ' J — i- � —�- -mo 1 .– ' -4-- - r - " .:.__.1 J.._ .. t .._ E : L r J . . L 1 . : tut _. �..- ---'-- - - _i --- - --- - I - ---- 1 - ` ------- ---- ----- ---' -'-f-- -- - H-1-1- _ .4 ' IIJE -rs ` i 1 (— = t _ - - t ---- -- r - --- 5000 U II - IERI NU M + D , — -- T ' .. num rA l Ial -t ._... -- f — — — i i h --F 3000 SI'm- r!!!!lel:a, ill {I �� ....._._______._.. , — �! i!i!!l EN111 1 ,RS 6 taAtllll l litt i -- f — i I - 1 .._f_ - - CO , f II Nu on 1 e 1� 1 � 11 g1 N 11ip M p IM Itai t - 4000 9 S::9 iim i __ - - -�� ? i - t - -- 0; 400 f i 11111111111111111 RU 1161 itt t1m —' -- - ' - �_ U l N 111 1 MX t E l L I Fl .; - -1_ 47._ 5000 ' 4- r fie -- -1- -- - "-- a --- - -- - , - -- --- -.._.._ + - t�1•el�ml!!!11MW7g lgmDelittl lriil�1 — i , !. 11 1� !! tt>EDllill tut 1 i �i�.11lli !! IIWEEI11{1 {titpp { , ( , 1 1 I "111 ii r . @I lletI A1M 1)i i I i . 1 _ w e Itl r ia m � y1fni 1u t1luiM 6000 e!r•a�l..v uHrNHtcues time I I 4 6000 �!!!! ` [gyp { ri j i-- ; • 11111111111111101111H111111111118 VIA 611111.1111811UHIMA >t�� ! `ARM Ni eft tH ltifin i wroommimar �� En 1 JIM ( t ; I � I l pp iHl 1 !B lrul[Itl L . ' C J - -. � -- --- _.. .... ` __ 7000 - 1• R e e[e 1 11516 - , — ; 7000_ I 1 - !m8. nt 1 lit111A1 I J - -.. tt : ri as uu nahil� puIIn - - ; - I - - { - -- - i - _ -� i - 1 !/ 11111eft tt 11!111811 - f - — d �! i - - - , lift! I.f..fef1IF1{MI i 1ii1 i : —_-- - ,I t 4 - - F es ' liati t,':" ��,, ' Ery�t 't'� ' tl , � q � l it ' i =- --- ;--- --4- -- - 1--- -- __ ,_ __. - -i-- f Fa a ,[ullfep u tFa�1 - ' _ 8000 8000 . 1 c 1. _ �._. _. i + i i X0 40 ' 7 8 9 10 11 12 13 14 15 16 17 8500 60 80 100 120 140 160 180 6 NCn Intercept GL t 1ES PPG Figure 21 Logarithmic Slope e - I3e-IE -e- 155- 45- 5OS_PPG 2 -e- 155 -45 -505 FG 2 • PHILLIPS Project: NPRA P PHILLIPS ETROLEUIVI 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) DEPTH (Dein setto MEL) FEET MSL MSL .4 ..,..intl 1.1.44 41 if , _ 1! 1_ . . ..i.. !., .. ....`J. _I 4 ,..! ..,_,.!.. ., ; • ' 1 I 1 --;.- ---- --' -- ' I . • .1. I' - .',I wi 1 . . , f•t, :- -,--. 1.4.. -± - - i • , - , , 'H ..Li:. _,..1; __1_ ! ___... ,' _i__ ' .] . , ,.. . : . , ' _ i . - - I --i .-i- --4--.. .i.i.!.i. 1 ,., i : - . - -- ,-' - 1000 --..,—,---, . , ,/ , ,. i 1000 : ; _,_____,_ _ __1_,_.: ._ ,-__,_ .4.4- ■ i ..- 1- F ' --,---- -kV __,. .- ---- i _. I i..!1 ,;•;! I,, A . ' I 1- • • -- --, 4 - : • ' ii. --, 1 i- r-- ; 2000 2000 ! - --+ ,-- "- li, 7 -,. --- . .; : i • - 1 ,,, . , , '1 • . . i h , I ; , , ' , ---- i ',. t -4 . ._,.. . .1 ____I„ 1 1 ' i I ,:. 1_ : • , r ; Pil ; . . A.T. t 11_77 ---. r ._. _ -:- --. .,_. A_ ,_ , , -4 -:,- f . T- 7.1 - 1 ' . : - • i •-' ,C, .L. ' .14 , t It i it I ..... -- i t i , . -. ---i.---4-;-;--- -I- t±F- --i :-!"'" 4 - --! + ' -- -4 . ' i- --r•-• 1 ■ ■ 3009 I ' , ....k IIF. , 7 pi 41. INF! ,- --4-- i i i -i r_ r , -, i • -i, -,-, :- r : , I 114- ,_ ___ , - I i - f ._ 1 . _ . . t _ . . . - -I - • • ,Li• 1 4 CI ! ' r 1 1 ..... h 9 1 -- - i — , ____ ,_______- 1 iiinwitinv pliminimmi _____i____ i 1 i --;-- 4- f" . ! -I .11M1111.1111MI —} 4000 . ,i i 1 4000 -1-4: -- I-4 HEMP'S -Jk 1 -4 -ILL-- -- ----- --- i-L_- ---_:-L_____-J,_•-•___,1:•_:-••_L_I__. i , ■ 1 - i • -4 I ' tili4 .)grilliniliti I -1 ___ :11115 .1 "I 19 I 1111111 A i El a 6000 : d 1 i.. 4 1 m.,,ii Ingicw.1011111181 MI 1 ---- t 71114Tr iiiiMph I - I ._ 76 • _,E__, __.4 1 , li M 11161 —_1:11+ _ ___II' • I au- s irt L PEnure m inutil I , ....... 1 ......... , 11111111111111•1111, ilf11.5/11311...-Amml1111:1 111 i I MIIIIMINIIIMIIIIHITVIIIIIKIIII IIMUIM11 ' r- ± i I I ' I -,------- 6000 ' ' I. Ell a II #101Hill L , — i - . a - 1 , , lar g ti 1 -------------- 11 . 1 - ....si , •. iranoun ta a HA 1 ; 1 p ir i 1P I e , i [ 6000 7000 =2C- N - .14sinp,k' , ' Rai,. " HZ I i I 1 7000 MTAIMILL 114 III M — —I-- — 1 i 1 - , =man MUM ild r i, r ------. ii■N_ 1 . I- ' laill PIN __:,- 1 - i -- - - -- t ._ i __I_____ 1 ___,_____ ...___ ,_______ --1-- • i iim ad , --+- -I-: EMI In Pr lli I 1 .*--...._....4_.....____._............_.1- , ---- ----n, U . ln a ussi i i T i I ' 1 -1 - j 8000 r. .. ,, --1- f i , L 1 - 7 L---.-3- 11 ...., 1 1 , -7- 1- -4----4---- - 8500 t ' 86 '00 ' AMEN MIM IN MI • 1 I 40 60 80 100 120 140 160 180 6 7 8 9 10 11 12 13 14 15 16 17 Figure 22 ticninter•eptriat.. SI PPG Logorilbmie Slope o -43045 -0-- 155-45-50S_PPG i -e-155-43-sos_PGI PHILLIPS Project: NPRA ; - PHILLIPS PETROLEUM COMPANY r g, N , F I 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) F EET DEM (Datum sdm 6ASy S. . _�___ —_.L1T .J_�_._� E _ — L - -.. -- - -_ - J_._ -_ -_- i -,-- 1000 : . . . 1000 + {1..�.f ._. ._ .. _..... - _. - ....._ -__. ■ i ' - LI = ! i'+ 'i E i i ) i1{ ir1; _ . __ i E III L i 1I 1 I TI i± , . .. .. _ . -- - - ` 2000 2000 .. . , - Q� { tttt 11711 KTO 1 1 r- + i 1- ___ , r-H ' _ lt� — L • 3000 It :, 's ' (! . i ! ? � 1 y € t l l I { { _ ( +_ 0000 ' + ■1 t 1 1tl __L_ —_ + __�. - -__ - + , -000 :..--!- -4-4-- -- -1 -- - #1 jil limo nu 1 ::::__,.._..- 400 :=1::-+-'-' ,. J :t 1 19M i FIROM IR — - _ 1 - - -- —_ _ - - - � _�_ ,'0 . _ �1!• l el HE n [I � + FI „E - tll I I_ 1 5000 y , • • Q� llll I WI i 111 1 — 000 + - - 1 - � � ' r if H IM I 1 - - -1 - r - 6000 6000 .. ., ._ ?., - 1 - r - - -- -- - ■ alinemEliI Val r E ■ l EJItiihl , – — '1 �l1,, ! E Nt101H itltl[}}II � { �.. - — � i i ■011 lout!! Ril) 1 -1 - -- ' - - - fff 1 t I I — -- -.�._ 7600 t�Ep1 7000 4_4_ li r l l 1111 _ — . - I - -- -- - o it - L - - -end ms. it..+11....i m -mu —� -- fit- _ ems 6600 1 ' ( G E„' u; °""° 1 { E • f 8500 I Iniffnall -1-1 f - -- ... -... X 40 60 80 100 120 140 160 180 6 7 8 9 10 11 12 13 14 15 16 17 Intercept ,d GL,, PPG Figure 23 Logarithmic Slope _ - 45e-1E - 155 45 - 5OS PPG i X155 -45 -5OS FG 7 PHILLIPS Project: NPRA PHILLIPS PETROLEUM COMPANY Well: Oxbow 1 Pore Pressure and Fracture Gradient System NCTL: 150-4.5e-5 10/13/01 K. Heinlein Oxbow 1 (In line 49471, Xline 10461) DEPTH (Dm lum setto MSL) FEET MS1 MSL ■ , - : 1 ; . • , ; - :- .•• ) '.-' ., 1 , . • ' ' . I • ' • • • -• . , • - - : • s.- -4-- . -:-. .__;_ : -.-- - --1--- i - - ;-: - j t ---: :--- ;--- - . 1000 ' ' ' ' 1000 lel ... . _ : TE - "...- - 7: - . - ......fiT... TIP- II I : -, • --:- , , . . . _ . , ... . • • • • 7 " : I' , 'I.' : ; : :I'', i , • ,•; i i___i.:._:_ ; • : : :11 : 4 - , i_ ____t ___i_ • - • _,_— 9 _ . , . • ? i 2000 - . . . 2000 . . . , 4 - - : :-- 1 t - I i i , ; ___,_-___-____ • • 00 , : f : . . Id T___—_,_ ' ; -.---- • . — moo 00 ' ' : ' - ----------- -4--i- .1- --4H- 11 • ' "MI -4 4 - 4- ,--- : --- , - ..,. - ' 1 t 1 + j i Li / i 1 " I ! • - - - --■ - --I.- ' --1 _ I I i - 7 - *,--- - 1E4 - 4 -- mi xm .. • i q — 1 -- ' t - . r_ 1- - , _.. _ _l______ _t_____ 1 4000 - 40°° • --4-- 4 -- - I- - i-i' -4- I 1 -HA I _,___ I_ __,, ,_, — :71.7.17 . 1 - Tr. MI. -- 1", t : --L- .1: 1 . ,. . .7. 1- ---"-- -1 -1-.171-1__T-.,....-T.-L1..-.-..,.1., i .. .. L I • - ". • J.. - 1 - 4-' I -- 5000 --1-- --'---- 411 .iti-F raw . -i--- H- . . It T ,_ _ _(...._. ._,_. = ,_____4.. —L -i---- s i 1-- __s— 1 _ , _ II II .,,,q.0 1 -- --- 11- , 1 , ____ . ; - . I . H.... 6000 i 4 -I- ------ r '1 ' :- - - t - ---4 ' -.- . 1 -4--t - A - trli g min . ; t 1 •,_ _ _ 6°°° leramiligia _4_ i ____1. -4- ■ i NAM MU THITERIX X i 1 !----- H- 1 • 1 . 1 e III EMI wittlilin --r= I s ...I I. L ...I -. ... ; Al' Ill , 7 1 .11 L . *1 1 • - -4 - - , - • 7000 ' ' 7000 1-- - 1 —TT- -1- i I , I ■ , , ' -- Mal M ■ ■ : 1 , 1 ___I IIIIIIIIMI Irin -rr. . 'II Iii — ' . 1 — ± A lli IMINIMITEIIII q 1 I =111= MIMMIMI 1 , • . 1 1 • • • 1 -- ' - - in 1 I I *.i A . -- ......_ . 4 lift ', '1,.11111 I L 8500 -, • '---- 1 — 1 - 1 - ■ i .: 1 mg hemp _____F ____;._ , . ,__ • + 7 40081.0 a me um ut I J , , 40 60 80 100 120 140 160 180 6 7 8 9 10 11 12 13 14 15 16 17 NCTL Intercept at GL =152 PPG , Logarithmic Slope • -4Se-IS -0-152-45-50S PPG 2 Figure 24 - 151-45-50S2 FG PHILLIPS Project: NPRA r ' A PHILLIPS 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) Ma NET OEPIN( sdlo MSL) MSI _ - • - ii'."1 ,i t'i i l 1000 ' i �_ i, • } i � _.. - --- -- - - --- ..- 000 { - - _ t 2000 einI Il —f --- , + . - 2000 -- - - - - ui -- - - --i -- -- -- -- -- • -- —'— ` _ • t , i ( • .F t _ s_.1 T t'• 1-1-:-1- { I TT, - __} _4.. _f _....' _.. �. ..._i_._... -_ _. _ —. - -. _. _.. _ __... le - r - r -' "- INNER "--:- __ ' �_ , 3000 3000 ' � 1 �5. { .1� ..._:._,..._,__ 1 .. } ..J_.:.. _ Rill -_ , F � -__1 __ _ +— '.. ----,-- , 4000 ■ rut uu , � —_. _ — i— ? --'a . ■ - --.i — '-'- -- - -- _'_- _ i - =}F- — _ 4000 .1_1.. .. .p i i ild iiil 1 , L 5000 mi ff 1■ N.NN ll � - - _ — i -__�, _--1---1 J -Y '1 _ I i . t� ' -' }_.. __ i -" —_! _ - .. - _ _... 6000 _ _ 6000 — 4' 1 .__ ,,- -_-_„_. -,_ -1-- i_ _ � ,N �u 'i 1 1 ( 1- — i I - . IMO IBM 111111111114 i ��r ti>•I...IN tI1fl/H1111111 1 1 �mlHf' _ .!. 1/1111111/1 ti. 1 s I i i I._ - f' 7000 IL O NI I 1 l— — ' ∎ 7000 °�iTii� I ,„_ EIBPRIIIIIINI „........, 9000 .� n� I.In 11 l ie n j_ qq��p _ EIMII ® I i 1 ' r f ifii — 1 v 111111hil - - - --1 8000 ___: _ "- -- - ' _ _ _ -_ __ ! iii u 1[EB®n S f - i I MI 8500 MUM � � u 1 E u l lua — — —} !�i — 6600 40 60 80 100 120 140 180 180 6 7 8 9 10 11 12 13 14 15 16 17 Ne'L Intorsept at GL .152 PPG Logarithmic Slope e - 4ae -E5 -- 0-152- 45 -50S PPG Z Figure 25 -0- 151- 45 -50SFG 8 PHILLIPS Project: NPRA PHILLIPS PETROLEUM COMPANY Well: Spark 6 ,,,,, • _ C ... r Pore Pressure and Fracture Gradient System NCTL: 152-4.5e-5 10/13/01 K. Heinlein Spark 6 (Inline 49800, Xline 10551) DEPTH (Datum sett)MSL) ee. . FEET MSL MSL , Mu , ■—___-_, i___.__ _i_______; • 4- r -. --- 1 .1. -I. .i.. .,.. 4- i.. 4.- 1:-.. ■;11 i 1 Pil . 3 , - - i .Th : i . . ,, , ■ -! 1000 ! - • , , , , 1 : , ■ I : , , • - i e 1 , , - ' i ;" '-0 '.1 1 i 1 t 1 . • . , - ---- ---- -- ------- ----- ' L - 1- - , -: - ■- ---! - 7 !-- -+-;•--, - 1.- :----"- ? :-'4 . -I- '. 1000 T..: I - - - . _ -_- -,: ) I, s. , ! . ___,. 4 _LI --i-- - - . ; '; : i i i 4, 1 ...4. 1 . 4 1 - 1 ; --- 1.... -T-t- --.-----,-- ' , , —' — -.-- „„ 2000 . —,,,,„..., 411 ,,, ...!_,,. . : • . , -- _ ._. • ..._ ... ,,:, hi,. ,••,,•••,... f h ....': . ;- - . 4 . J. - 1 .1, .L11- 1.,'Il '1.4 4 iii- M 1 i i . i- tT, —1---..-'-- -i-r-E-4 4 t =h. , =i , _ : i , , ,,, i _ , HIE 111111] r —}7 r---1 T --L-t- -i- ' -2, ining........, : _H- --,---_-_ - -÷t i 1 UZI= "MI 1111 ' 1 i I --1. 4000 — ÷- --'------ 4000 iiiii 1 ' . ' Inv gffilworom —I---4-- , -4- -+ , ___i - -- , - - -i-1--„ j _ _____ ; , i ; . I I 4._ ----- ri liZi — ; 1-- • i --,-- _ _, -- qii , , .,_---- ,_. 1 171_71:1. ..7.i 71.:. h,,, tit 44 all 11 .., • I-. -1 f --I - t - 1 - f - 5000 ' 5000 ......._ ± ... _.._i _____ .. . _.. .. _ _ .. _ _ 1._.__ ___F. .. . . _ i I i ■ -- !Edison/mum. ..tillninithiloi , 1 a , i 7 4, 1373 wir, a a i , -1-- , i _, _ __;____ NI Be ! it “i'l I 1 -4 I 1 _i_ , _ _ I . ■ 6000 ZEN. a a ar rilfaili MI . I ---- ___I 1 6000 , r am ummellp --s- i .. _ ,__ • . al II __,_ - - ! - - -.1----4 1 I 1--- I- . _____•,____.. ,,,.. . 11.01 . _ 4) ___.+L-_-_-__i__ ..k .111 _I I 't --1 1 - - I — 4 • t • -- t 1 4+ .- I 1 1111 H4 7000 i I 7000 • .i. - i... • i. I ..! ./. . 1 4.i . .. .14 . ! 6.; - ---- - -: 1 t I —1 : 1 . - 1 ' --- '.- 1 . L. 3 , 4 . .., . „4, I , . I .. _ .1-5 1 Et. . I!. . 4 ,-1' III - .- -..- -- . " - t .. - _ - ) T 1 - . _:__ ._,__ _ 4_: ___ ___H --- H----- , - i - - . - - :_=:r - - - - . - - 1 1 j ! } t 47:, • +.!.1-1 ' I L - d_,..9 ----1_— ,, , , _--..,_ . , , , L___. li alt0M1 I -- I , 1 i 8000 8000 4- - , 1_4 : I 111 .14,4.1 _I —1_1_ -1,--- - iii' . . - . f !.- ! ! , HT 1" . 8600 1 8600 40 60 80 100 120 140 160 180 6 7 8 9 10 11 12 13 14 15 16 17 NCTL Intercept at GL . 152 PPG Loggratunic slope . -43e-15 -0-152-45-SOS PPG I - 108-45_ _ 50s Fc_f Figure 26 PHILLIPS Project: NPRA PHILLIPS PETROLEUM COMPANY t 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) ___ , DE (Mtn sett, MSL) MSLi , MSL - , f I • _4_._ _ __..t.. .__ _L_. U. i • i i i _ ._Y_ _ _ —_1__ - .y— _ — - -_ ._ L ____ i _— y. - ..._. ._ i .... i I.,i ..., . . ' • t i.i • 'P _ .._ — _ . . . . 1•.• - _ 1 I ^ 7 • � � I _. T tom ' tom r - - r t - I - -` - - - - - - - i - ��.:. -..i� ;.z iii - L �r_ i . }.. 2000 --Y- 000 3000 — _ _--,--1,-- m manual _ ' - y. _ _ _ - j : - 3000 �� — - — . - 1-t-' ti -Y -- - - - --- '' ,- ,- , ,._ • ;_,. - - � - -- ° -ice - -} i -- � � H spy _ 1 - E. - __t __._ . .._ t.. .�.__. '.� -1 --' = yy..��■■1 ■ ■I-f EF�E�E�IE�EIE�I I - — .l , • 4000 ; gl i��E- [ri�hri . 1 — ' 4000 �" �plj 1 __ r iii 1 Iml �; ` ( ' = i A iial f- Ip I ' ■ I { — - I .1 i/a Qiii num @II7 p -- - -- - ' ��11=11111111111' — 6000 —2 t — '" MIN Mgr MEIULUW B IUi I 5000 �t i Sty irQi BW4EIil 1 i 111 1 RN --i- -N ..1. m ii inuiuun ■ , woo SON W "mils: iFP nhn , ; T� - 1♦E�Itf �ii irip - . - -- -- i - . .IC _ = _ _ mm _ i 8000 - r F.. t i li ih u n l i n ii i l k 44 , i— - i_�� - I --I- -- - -- - - -- -- - - -- -f -. 6506 40 60 m 100 120 140 160 180 6 7 0 0 10 11 12 13 14 15 16 17 NCTL Intercept d GL -152 PPG Logarithmic Slope = - lie-15 -e-152-45-50S _PPG i Figure 27 X152 -45 -SOS FG Z PHILLIPS Project: NPRA PHILLIPS PETROLEUM COMPANY 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) RPM (Datum sotto MSL) FEET ha . Mk , -7-_- 1114 111 !_1-, I 77. I ii -, 1 7 . . , ! I i : • : • . 1000 1,1 :_._,_....—. . 1000 ! i.. .! 1 Ha A .. . -, - 4 - ,-- , ---- 1 -- , --. : --1 : • 4- , '., - ---i-------,-----1---;-- ! i : 4- • -'' -,--4-- -. • • 4- 1 ----- — ---.-- -,---- -'- - , __ 2000 " , 2000 • i : ; ' • ; f , ,_ . ._,.... . , , ,. , ; i : I I ; • ; ;; - 1 - - 7 4 1----- ' --I ,.. .. : -.,. I, :...: : , : • • 1 , ,. , 3000 • i • ! MILIEF BIM i , : — 0 , - • : 1 ---- -,- • • ; , 1 I ; i• , , ; _____J____ _,.. - r , 1— H ---!- ! —i-- -1- -,----- . 1 -i - 1 • 4 I r . IN ' : . 1 - - i ' . - ; -- I 1 • : I 1 IN1 ' kill MO WIl 1 14 Pit I I ; ' ' - ____:_ , i f -1 1 _!. i , ___, i 1 VinitEMIN , _ , , - .. t- ______E,FE,, r figramms I 1 i ____ __,_ 1 la mum -- --rt- - -i---er=r- A % as Will Inn - -I 1 ; 00 • , i I I -I---(-- . 5000 -1--- IH NIIII IIII ■ . ' .i , 50 _,---1- r •* .1 ,' 1 ' i - H-- 71 I ... 1.. I I "1 -- ...t.E.1,-- -1 ' ylt 10,4 It • ... . . 3 I El I 1 MEI ju lEW: nr RU Hill a gm i ' I 1 6000 MIMI/ MIIIII11111111111MINIMIIIIIIIiiklIffla 1 • • $ 80)0 a 2 ,-. 7 , ritam ,. 1 asiniMumalWAngiusu i 1 = rilimml wows . ; _, III 111111110111112 11411011111111 ■ I -, 1 ! ' 11 1. 'Ti EITH a AFIM11111 ! _______ ___1-1— •_,, --4 _ I -- - - I 1 a twin i . i . I r -: -1 — 1 - _ 1 --- , I , NI ' i ; k • 1 NM ; Imi ..r 1 ... ., . - 1 - ; moo "I ' — - c i ! 7000 ' I in 4':'I 5g ,=,1 pi -- ,_ 1 , .i ___ .4 - 4 1 , ___ - --- !--I I- -- ----f----- + " 1 . I I • 1 ....: , i ni. 601661100 . 1 1 ; -,—F-1 iii . .16A ...mum , . . . _ 1 .8w8868m8611101111121 ■•l . . : . 11111 -1 IMMIIIIIIIMME11119 _ -I , b..... , 4 8°°° M _ . • _ III ! • • I iii,711 I _L_ J : 1 8000 --, -,- 1- r t. . ,._ 1 . .. 8500 , 8500 40 60 80 100 120 140 160 180 6 7 8 10 11 12 13 14 15 16 17 NCTL Intercept id GL = 152 PPG Logarithmic Slope . -450-15 -0- 152-43-50S_PPG Z Figure 28 -0-163-30.500 FO! • • • MICROFILMED 03/0112008. DO NOT PLACE rr~ °,. "`~ ~: ;~, ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_Inserts~Microfilm Marker.doc ) ) FRANK H. MURKOWSK', GOVERNOR ALASKA. OIL AND GAS CONSERVATION COMMISSION Paul Mazzolini Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage AK 99510 333 w. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: NPRA Spark #8 ConocoPhillips (Alaska), Inc. Pennit No: 204-015 Surface Location: 1260' FSL, 253' FWL, Sec. 6, TI0N, RIE, UM Bottomhole Location: 1260' FSL, 253' FWL, Sec. 6, TI0N, RIE, UM Dear Mr. Mazzolini: A review of our files has indicated that the approval letter for the subject well was not complete. Here is the correct approval letter for the above referenced exploration well. The approval date remains the same, which was January 30, 2003. This pennit to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confinned by a valid Fonnation Integrity Test (FIT). Cementing records, FIT data, subsequent LOT data following setting production casing, and any CQLs must be submitted to the Commission on fonn 10-403AD prior to the approval of dispo'sal operations. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the pennafrost or from where samples are first caught and 10' sample intervals through target zones. In your application, it is indicated that testing and stimulation of the productive intervals in the well may be perfonned. A Sundry Application (Fonn 403) detailing the planned activities should be submitted for approval. ) ) The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the diverter function test and BOPE tests must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field' ectorre North Slope pager at 659-3607. Sine -el , BY ORDER OF THE COMMISSION DATED this 30th day of January, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. } r L~:'1 FRANK H. MURKOWSK', GOVERNOR AI/ASKA. OIL AND GAS CONSERVATION COMMISSION Paul Mazzolini Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage AK 99510 333 W. "{TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: NPRA Spark #8 ConocoPhillips (Alaska), Inc. Pel111it No: 204-015 Surface Location: 1260' FSL, 253' FWL, Sec. 6, TI0N, RIE, UM Bottomhole Location: 1260' FSL, 253' FWL, Sec. 6, T10N, RIE, UM Dear Mr. Mazzolini: Enclosed is the approved application for pennit to drill the above referenced development well. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the pennafrost or from where samples are first caught and 10' sample intervals through target zones. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tennsand conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission -witness any required test. Contact the Commission's North Slope petroleum fiel' ector t 65 -3607 (pager). ( IY~/~// / ,f .f / {:;l "--1- K., , . / ",/ ~ J /// - ~ BY ORDER ~F THE COMMISSION DATED thi~day of January, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploratory~ Development Oil U Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 Spark #8 6. Proposed Depth: 12. Field/Pool(s): MD: 8350' , TVD: 8350' NPRA Exploration 7. Prope~ De~i ~a, io : . Aíl ¿), I, -- ft 8. land Use Permit: ~,'~, ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: Drill ~ Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Redrill U 1 b. Current Well Class: Stratigraphic Test 0 P.O. Box 100360 Anchorage, AK 99510-0360 4a. location of Well (Governmental Section): Surface: 1260' FSL, 253' FWL, Sec. 6, nON, R1E, UM Top of Productive Horizon: 1260' FSL, 253' FWL, Sec. 6, T10N, R1E, UM Total Depth: / 1260' FSL, 253' FWL, Sec. 6, T10N, R1E, UM 4b. location of W:fl~~~;ase Plane CoordinateS):S-7'o/ó628 zÞnc:. '1 Surface: x- 747654 y- 5943634 Zone- 5¡Ø 16. Deviated wells: Kickoff depth: 0 ft. Maximum Hole Angle: 0° 18. Casing Program Size Specifications Hole Casing Weight Grade Coupling 24" 16" 63# B PES 12.25" 9.625" 40# L-80 BTC 8.5" 7" 26# L-80 BTC-M 6.125" 4-1/2" 12.6# L-80 IBT-M ./ ¡/ ,~nl AA081806 9. Acres in Property: 5672 10. KB Elevation GL 50' & 28' RKB 17. Anticipated Pressure (see 20 AAC 25.035) Max. Downhole Pressure: 4005 "psig Setting Depth Top Bottom length MD TVD MD TVD 80' Surface Surface 108' 108' 2350' Surf. Surf. 2428' 2428' 7750' Surf. Surf. 7828' 7828' 672' 7678' 7678' 8350' 8350' 19 Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Length Cement Volume Size MD Perforation Depth TVD (ft): 20. Attachments: Filing Fee 0 Property Plat 0 BOP Sketch U Diverter Sketch 0 Time v. Depth Plot ~ Drilling Fluid Program 0 Date: Drilling Program ~ Seabed Report 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name P. Mazzolini Signature ?~ YI1~ W4A-· II],.. z..!l-O() 'I- 13. Approximate Spud Date: March 25,2004 ",t' 14. Distance to Nearest Property: 253' at TD' 15. Distance to Nearest ,¡,/' Well within Pool: Moose's Tooth C , 3.14 mi ./ I Max. Surface Pressure: 3087 psig Quantity of Cement c. f. or sacks (including stage data) 190 sx AS I 320 sx AS III Lite & 170 sx Class G 180 sx Class G + additives 130 sx Class G + additives /' r /' TVD Shallow Hazard Analysis U 20 AAC 25.050 requirements 0 Contact Tom Brassfie'd @ 265-6377 Title Drilling Team Leader Phone Date Ollrs/tJ4- PreDared bv Sharon Al/suD-Drake Commission Use Only Permit to Drill / / , ¿- API Number: , ~ permit~ppro I See cover letter Number. 2é'r--Ó/~ 50- /63- 2ûC/flz.-ø Date' /, 3~r./ ~Qh"r<;¡¡¡jrJ~e1t ~ Conditions of approval : ~ Yes 0 No Mud I 9 required I I ~~\ .I ~ Vo D _ .'. " , 0 Yes ~No Directional survey required OJ ~~ -:&'!-~B04 5DO P~i Yk-L~k.-tL(.k-1.. '~~(I'~4~h ÞY'-( ~'3D (~) j F I. T ('eD~~~e...t 'S COMMISSIONER BY ORDER OF THE COMMISSION Form 10-401 Revised 3/2003 · ORIGINAL Date: ') ) y ConocoPhillips Box 100360 Alaska 99510-0360 January 13, 2004 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: Spark #8 (Exploratory Test) 1260' FSL, 253' FWL, Sec 6, T10N-RJ E X=747654, Y=5943634 ASPS NAD27 1260' FSL,r 253' FWL, Sec 6, T10N-RJ E 1260' FSL, 253' FWL, Sec 6, T10N-Rl¡E Dear Commissioner: PHILLIPS Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratoif'~' 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 erlltdÜl1 drilling an 8-1/2" wellbore to the top of the objective with a LWD logging suitejf:or/ evaluation. A 7" intermediate casing will be run in order to case off potentiali1v sensitive shales and drilled out with a 6-1/8" bit. Only a minimal amount ofhøl'€ « 1') will be drilled before POOH to pick-up a coring assembly. At least one 60' core vI/ill be v cut through the objective zone beginning immediately below the 7" shoe. The 'well will then be drilled to TD and depending on the logs either a 4-1/2" liner will be !run and the well will be tested, post-rig or the well will be PM'd. The proposed casing program will utilize a 9 5/8" surface casing Stli'¡¡-;lg., 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 MC 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 MC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 MC 25.005 (c) (1). 3) A directional plat showing the surface and bottom hole locations propRECEIVED for the well per 20 MC 25.005 (c) (2.)- straight hole. JAN 1 3 2004 Alaska Oil & Gas Cons. Commission Anchorage ) ) 4) Diagrams and descriptions of the BOP and diverter equipment to be used /". (Doyon 141) as required by 20 MC 25.035 (a) (1) and (b) have been submitted previously. 5) A complete proposed casing and cementing program is attached as per 20 MC 25.030. A wellbore schematic is also attached visually depicting the proposed well. 6) The drilling fluid program, in addition to the requirements set forth in 20 MC 25.033 are attached in this APD package. 7) Seismic refraction or reflection analysis as required by 20 MC 25.061(a). (Previously submitted- on record) 8) PHILLIPS does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be y' functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 9) Complete logging, coring, and mud logging operations are planned and / descriptions are attached. The following are Conoco 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) Greg Wilson, Geologist 263-4748 The anticipated spud date for this well is March 25, 2004. If you have any questions or require further information, please contact Tom Brassfield at (907) 265-6377 or Paul Mazzolini at (907) 263-4603 Sincerely, Tom Brassfield Senior Drilling Engineer cc: CONFIDENTIAL - Spark #8 Well File Paul Mazzolini ATO-1570 Andy Bond ATO-1310 RECEIVED JAN 1 3 2004 Alaska Oil & Gas Cons. Commission Anchorage ") Canaca Phillips Alaska, II' ) Drill and Case Plan for Spark #8 General Procedure: 1. MIRU Doyon 141 over pre-installed 16" conductor casing with welded landing ring on conductor. 2. Install diverter & function test sa~. Notify regulatory agencies 48 hours prior to test." ../ ,/ 3. Spud well and drill 12 1/4" hole to the surface casing point at 2428' MD/2428' TVD.- Run MWD I 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 agéncies 48 hours prior to ~ / 7. Make up 8 Y2" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 8. Drill float equipment and approximately 20' of new hole · Perform LOT (or FIT if gradient reaches 16 ppg equivalent) · Record results and fax to town ,/ 9. Drill 8Y2" hole to top of Jurassic at approx. ±7828' MDI±7828' TVD. Run MWD I LWD logging tools in drill string as required for directional monitoring and formation data gathering. Will trip to pick-up rotary BHA, placing GR/Resistivit): as close to bit as possible to assist in picking casing point. 10. Run 7" intermediate string to isolate potentially sensitive shales located just above the objective (est.@ 7828' MD I 7828' TVD). Cement casing to bring cement ±1000' above 7" shoe. ,/' 11. Make up 6 1/8" mill tooth bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 12. Drill float equipment, circulate & condition mud, displace to coring fluid and TOOH. (LOT is not/' planned for this casing string - see attached explanation). 13. 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. ~ v 14. Drill 6 1/8" hole to ±8350' MD I ±8350' TVD. Run MWD I LWD logging tools in drill string as required for directional monitoring and formation data gathering. · Condition hole and mud for e-line logs. 15. Log 6-1/8" wellbore as necessary. 16. Run and cement 4 Y2" 12.6# L80 IBT-M Liner // 17. Make a cleanout run with bit and scrapers · Displace to filtered seawater or brine- depending on formation pressure. · Pressure test well to 3000 psi for 30 minutes (perform low pressure test on liner lap). · Record results and fax to town 18. Run and land 3-1/2" or 4 Y2" tubing with gas lift completion 19. Nipple down BOP's. Install production tree and pressure test same to 5000 psi. 20. Secure well, release rig. ORIGINAL ) Conoco Phillips Alaska, II) 21. MIRU 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. 22. Upon completion of testing or if the well is not completed, plug and abandon the well, or temporarily /'. shutdown per applicable regulations. Thoroughly clean location and block off further ice road access to location. 'ORIGINAL ') Canaca Phillips Alaska, II ") DRilliNG FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRilliNG AREA RISKS Spark #8 Drilling 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 ± 10% Drill Out Intermediate hole /) 9.5 - v(.J;Ppg 6-kio 5 - 20 35 - 50 2-6 14 - 20 < 6 below 7000' 9.0 - 10 < 11% Production Hole (Intermediate shoe to TD) 9.6 - 9.8 ppg 15 - 25 14 - 24 50 - 70 3-6 3-8 <10 9.0 - 12.0 < 8% Drillin2 Fluid System: /"'. Equipment list for Doyon 141 should be on file with AOGCC. Drilling fluid practices will be in accordance with the regulations stated in 20 MC 25.033. Maximum Anticipated Surface Pressure and Casina Design: 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 108' MD / 108' lVD 2428' MD / 2428' lVD 7828' MD / 7828' lVD 8350' MD / 8350' lVD Fracture Gradient 11.0 ppg 13.5 ppq 17.6 ppg 17.6 ppq Expected Maximum Mud Weights: Pore Pressure Gradient 8.33 8.33 9.3+ ppq 9.2+ ppq Pore Pressure 47 1052 3760 4005 ./ MASP Drilling NA 50 psi 1437 psi 3087 psi ~ ---- 12-1/4" surface hole to 2428' MD / 2428' lVD: 10.2 ppg r 8-1/2" Intermediate hole to 7828' MD / 7828' lVD: 11.3 ppg (for shale stabilization) /" 6-1/8" Production Hole to 8350' MD / 8350' lVD: 9.8 ppg , ORIGINAL ) Canaca Phillips Alaska, II ') 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' 1VD) 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 108' = 50 psi OR MASP = FPP - (0.11 x D) = 1052 - (0.11 x 2428') = 809 psi 2. Drilling below 9-5/8" Surface Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(13.5 x 0.052) - 0.11] x 2428' MASP = 1437 psi OR MASP = FPP - (0.11 x D) = 3760 - (0.11 x 7828') = 2899 psi 3. Drilling below 7" Intermediate Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(17.6 x 0.052) - 0.11] x 7828' MASP = 6303 psi MASP OR = FPP - (0.11 x D) ~,:ö:SJ (0.11 x 8350') L/ psi ~ ORIGINAL ) Canaca Phillips Alaska, II' Casing Design Performance Properties Size ') 16" 9-5/8" 7" 4-1/2" Weight 63 ppf 40 ppf 26 ppf 12.6 ppf Grade // Connection I B PEB L -80 BTC L-80 BTC-M L -80 BTC Internal Yield Collapse Conductor Casinq 5750 psi 3090 7240 psi 5410 8430 psi 7500 psi Tensile Strength Joint Body 979 M 916 M 667 M 519 M 304 M 267 M Casing Setting Depth Rational: 16" @ 108' MD RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. 9-5/8" @ 2428' MD RKB Surface casing to provide good anchor for BOPE and sufficient fracture , gradient and well control while drilling 8-1/2" hole to top of reservoir. / 7" @ 7828' MD RKB Intermediate casing is set strictly to provide isolation of potentially troublesome shales. 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. Bottom hole pressures are available from offset data in the area. '2'5.030 (J) Well Proximity Risks: None Drilling Area Risks: Shallow Hazards: See attached explanation Drilling Risks: Drilling risks in the Spark #8 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, Lookout #2, ARCO Spark #1, Rendezvous "A", Rendezvous #2, Mitre #1, and Moose's Tooth "C". 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 Spark #8 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. PAI may request approval to inject or dispose of fluids in the Spark #8 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. ORIGINAL Geoloay: Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows: FORMATION DEPTH (55) UNCERTAINTY POSSIBLE FLUID EST. PORE TYPE PRESSURE. D5i 260 1062 1289 1423 1536 1781 2663 3154 3348 3760 Permafrost K3 Sequence 97 Sequence 95 Sequence 93 Sequence 92 Base Ponded Turbidites Disturbed/Pebble Shale LCU Top Jurassic UJU/J4 Base J4 Silt TD ) Canaca Phillips Alaska, Ir) 600' 2450' 2975' 3285' 3470' 3970' 5840' 6930' 7200' 7750' 200' 200' 200' 200' 200' 200' 200' 200' 200' 200' Possible Oil or Gas v Probable Oil and/or Gas ¡/ 7920' 200' 3799 8272' 200' 4005 ",. 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 01 8-1/2" Intermediate Hole (Surface Casing setting depth to Top J4/UJU) LWD: GR/Res/Density/Neutron/PWD v 6-1/8" Production Hole (7" Shoe to TD) LWD: GR/Res/Density/Neutron/PWD v' Wireline: GR/Res/CMR/MDT/Dipole Sonic (Contingency: PEX/RSWC/VSP) ,/ II. Coring 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 unsuccessful II. Mudlogging Mudlogging service should be in operation from the base of the surface conductor casing to TD. v' Service most likely will include ROP on 5' intervals, lithology, total gas, sample collection, gas analysis of cuttings, gas chromatography, and H2S detection Thirty to sixty-foot (30'-60') wet and dry samples will be collected from surface to surface casing ." setting depth. Thirty-foot (30') wet and dry samples will be collected from surface casing setting depth to well v TD and ten-foot (10') wet and dry samples, or continuous, collected across any hydrocarbon intervals. ORIGINAL ) Canaca Phillips Alaska, II ) III. 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. ORIGINAL ) Canaca Phillips Alaska, II ) Spark #8 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 12-11.4" Hole I ~-,5Ifl' Casina Interval Event Gas Hydrates Risk Level Low Clay Balling Medium Abnormal Pressure in Surface Formations Lost Circulation Low J Medium 8-:"t12"T& 6-11.3" Hole Event Lost circulation Risk Level High Hole swabbing on trips Low Directional Control Medium Sloughing Shale, Tight Hole High Abnormal Reservoir Pressure Hydrogen Sulfide gas Low µ Low J Mitiqation Strateøy Monitor well at base of permafrost, increased mud weight, managed fluid rheologies, decreased circulating times, controlled drilling rates, low mud tern peratures 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. M itiøation Strateøy 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 ORIGINAL Well: Spark #8 ') Field: NPRA Exploration TVD/MD o Est. RKB Elevation @ 78' Permafrost@678' 1000' 2000' _ ~ 9-5/8" Csg Pt @ 2428' /" K3 @ 2528' Sequence 97 @ 3053' Sequence 95 @ 3363' Sequence 93 @ 3548' E:$ltirnated Surface Location: 12:t~O' FSL, 253' FWL ~ SEi~C,,:IE), T10N,R1 E,UM 3000' -- 4000' - Sequence 92 @ 4048' 5000' - 6000' - Base Turbidites @ 5918' 7000' - Disturbed Shale @ 7008' LCU @ 7278' ~ Top Jurassic & 7" Csg Pt @ 7828' / Base J4 Silt @ 7998' 8000' - TO @ 8350' J 9000' I o Vertical Section ORIGINAL ) Spark #8 Proposed Completion Schematic 16" 65# H-40 @ +1- 108' MD Depths are based on est rig RKB Surface csg. 9-5/8" 40.0# L-80 BTC (+1- 2428' MD 12428' TVD) ./" Intermediate csg. 7" 26.0# L-80 BTCM (+1-7Y MD I 7828' TVD) Production Liner 4-1/2" 12.6# L-80 IBT-M (+/- 8350' MD/8350' TVD)/ f ~ l I I i I I i I I I I I i I ~ I ..A\ I ¡:: ~ ~ I ~ ~ ~ I I I ~ ~ ~ I ~ ~ ~ I ~ I JI I ~ ~ ~ ~ I ~ ~ ~ ~ I ~ ~ ~ I ~ i ~ .. r I I I I I ~ I ~ i I IL.... ~ ! I ~ I ~ ~ I ~ ~ I ~ ~ I I I ~ I ~ ~ ~ I I I I ~ ~ I ~ ~ I ~ I I ~ ~ i i I Í'! ... 4-112" FMC Gen V Tubing Hanger, 4-1/2" L.-BQ) IIBT-M pin down 4-1/2" 12.6# L-80 IBT-M Spaceout Pups asd~eqluired 4-1/2" 12.6# L-80 IBT-M Tubing to Surface 4-1/2" Cameo 'DB' nipple wI 3.875" profile 8$tat +1- 500' MD. 4-1/2" x 6' L- 80 IBT-M pup installed above and below 4-1/2" 12.6# L-80 IBT-M tubing to landing rqlip¡:dle 4-1/2" X 1" Cameo 'KBG-2' mandrels wI mi's ,amd RK latch, 6' L-80 handling pups installed above and below. Spaced out w/4·.'lI2ìl, 12.6#/ft L-80 EUE8rd tubing as needed. 4-1/2" X 1" Cameo 'KBG-2' mandrel wI latcl'q·8t.I~ummy, 6' L-80 handling pups installed above and below. 2 joints 4-1/2" 12.6# L-80 IBT-M tubing 4-1/2" x 1" Cameo 'KBG-2' mandrel wI latch8,dummy, 6' L-80 handling pups installed above and below. 1 joint 4-1/2" 12.6# L-80 IBT-M tubing 4-1/2" Halliburton "XN" nipple wI 3.725" prdflle 1 jt 4-1/2" 12.6# L-80 IBT-M tubing Baker locator sub +- 4-1/2" Baker GBH-22 casing seal assem:bi,yw/12' stroke, 4-1/2" L-80 IBT box up Liner Assembly (run on drillpipe). Baker 7" x 4-1/2" 'ZXP' Liner Top Isolation Packer with C-2 profile & 12' PBR Baker T' x 4-1/2" 'HMC' Liner Hanger 4-1/2" 12.6# L-80 IBT-M liner as needed 4-1/2" Baker Landing Collar 1 jt 4-1/2" 12.6# L-80 IBT-M tubing 4-1/2" Baker Float Collar 2 jts 4-1/2" 12.6# L-80 IBT-M tubing 4-1/2" Baker Float Shoe ... a.. 3-%" 9.3 ppf L-80 EUE rd may be substituted fuRn; I N A L T JB 1/9/04, v1 Spark #8 ") WELLBORE SCHEMATIC and CEMENT DESIGN 16" Conductor Casing at 108' MD / RKB Base of permafrost 678' MD 9-5/8" Surface Casing at 2,428' MD ijo f C e at ,8~ MD 7" Intermediate Casing at 7,828' MD 4-1/2" Production Liner @ 7,678' MD to 8,350' MD J I . . ~ 12-1/4" H, I 8-112" Hole l I' I I l6-1I8" Ho/. Conductor Casing Size / Hole Size Depth: Top 01 Cement Excess Calculated: Volume Calculations: (108 If) (0.7854 clll!) (170 cl) 1(0.93 cl/sx) Slurry Volume: 170 cf Slurry Weight 15.7 ppg Slurry Yield 0.93 cl/sx Surface Casing Stage 1: Volume (67811) (950 If) (1,387 cl) (800 If) (363cl) (0.3132 ellII) (0.3132 el/ll) 1(4.44 cl/sx) (0.3132 ellII) 1(2.40 cl/sx) Lead Tall shoe Joint vol 34 cf + 16" In 20" hole 108' MD RKB Surface 100% (2.00):: 170 eI 190 sx or Arctic Set 1 190 sx rounded excess 9-518" In 12-1/4" hole (4.50):: 956 eI (1.45):: 431 eI 312 sx (1.45):: 363 cl 166 sx System: Lead (Arctic Set 3 Lite cement + 9% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% S1(CaCI2) + 1.5% D79 (ext.) + 0.4% D46 (deloam.) Tall (UteCrete @ 12.0 ppg).".e'-) ß~O",~ ~tlc Set 3 Lite Volume around 4-1/2" (52211) (0.0942 el/lI) Vol. Between liner & Int. shoe Joint vol 7 cf + Volume of 200' above liner System: (Class G cement w/Gasblok + 0.1 gps D47 (deloam.) + 3% D53 (Gyp) + 0.75% D65 (dlsp) + 1 gps D135+2 gps D600+ 0.1% D8000º(r .. Slurry Volume: 127 cf or G.ao~ Slurry Weight 15.8 ppg ass G Slurry Yield 1.20 cl/sx /' Thickening Time 3.5 - 4.5 hours Lead Slurry Volume: 1,387 cf Slurry Weight 10.7 ppg / Slurry Yield 4.44 cl/sx Thickening Time 6.0+ hours Tall Slurry Volume: 363 cf Slurry Weight 12.0 ppg Slurry Yield 2.40 cl/sx /' Thickening Time 3.5 - 4.5 hours Intermediate Casing Size / Hole Size Depth: Top 01 Cement Excess Calculated: BHT (Static): Volume around 7 " (1,000 II) shoe Joint vol 17 cf+ (190 cl) (0.1268 ellII) /(1.17 cl/sx) System: (Class G cement + 1% D800 + 0.2% D46 + 0.3% D65 Slurry Volume: 207 cf Slurry Weight 15.8 ppg / Slurry Yield 1.17 cl/sx Thickening Time 3.5 - 4.5 hours Production Casing Size / Hole Size Depth: Top 01 Cement Excess Calculated: BHT (Static): (69cl) 1(1.20 cl/sx) or or ".::.''] (~AG 7" In 8-1/2" hole 7,828' 6,828' 50% 160g F 130g F BHT (Clrc): excess (1.50) = 190 cl 177 sx or ~.-) ~XG 4-1/2" In 6-1/8" hole 8,350' 7,650' 40% 160g F 130g F BHT (Clrc): excess (1.40) = 69 cl 20sx 63sx 40sx Cement volumes and blends are estimates only and subject to change before pumping. ORIGINAL 1/12/2004 Spud Well@ 0900 hrs 3/31/01 1000 2000 3000 4000 5000 6000 7000 8000 9000 116" set @ 108' I DRILLING TIME AND MUD WEIGHT CURVE Lookout #1 ............. Depth -Mud Weight o t!: , Á l' 1_ ~ _:_ _;_ ~ _ - -,- -I I .. _ -IM1RU. 120 rig loads from 100% pad ¡ ) I I ¡ I I I I I 1 -1-1 1-1- - ....j. ~ ~I I I I T -I - I I ¡ I I L_L_I___.l_ -1_.L_L_ ~---r-~-:-~---TI I I I I -'--¡-T-,-- L _1_ _1_ _ _..L L _ L ".. .\ _ _ _ T - ~ -;- -: - - + - ~ Slougingshales. Incf. MW , " :: from 11.3 ppg to 11.5 ppg to ì - ,- control !- !- A " I I ¡ I I -1_.L_L___I_~_-1_.l __L_I_ i I I I I I I I I ~-T r---I--I-~-T r-¡- ..J_..i L_ _1__I_...l J. __L_L I I I I I I I ~-T-r-~-I--I-~-T---~-:- _,_~_IDdll12-.1/4" Hol:I__~ ~I -+ 4 I 1- -~-+-~ -:-~-+---~ 4 I- ~ - 1··- ~I - f-.- - I- I I I I I I t I I i I ~ +; =19-5/8" set @ 3143' I - 14.5 ppg FIT + -~-- - t-;- : I T I I í ¡--I-- i-T " _ I.L -:- - - ~ ~ r-r-t---¡-T " I I I --¡-i-i- .., I -¡ - f-.- -1- -1-- -...¡ , T - 1- ...j. -.1- -- ¡....... , , , T r -- r ---+-+--1- , , , , I I + - I- - I- , I -- + - +- - r- -1- - - -1 - T , , --1-' , , , , I --¡-i- r -¡- - - -¡ - T _ _ -1 _ L _ :_ _:_ _ _ ~ {_ r-I-I---4-1'-,- I I I 1 I I 1 I 1 - r -1- - ¡ - T L _1- _ _ ..J _ ~ _ .L _ I 1 1 1 -¡---T-r r-I- ¡-T-r- _ _.1 _ L _ L _1_ _ _...J _ J.._ 1 I 1 1 1 1 1 1 1 1 _~ ~ I- _ 1__ __ --1 _ --!. _ I I I , T -J- ~-I--+--i----,- I T I I I - - f- -1- -I - -j - I , -t - - - f- - 1- -1- -j - - , _.J_l._L_- , , , --¡-, T r- j_l. __ , , , - r- ¡- - - -I - -¡ Î ï I I 1 1 1 1 I I 1 1 1 I ï r ì- _ L _ L~ _ _1_ .J _ ..L _ L _ I I 1 1 1 1 -T-r-¡-- -I '1 T-r-- L L_ _ _I _ J _ ..L _ L _ I 1 1 1 1 I I 1 1 1 1 1__1--___1_---I_...!-_1--_ - TD/M~ke a·tte~pt @ DPCIogs, run casing wiper trips to clean hole, run 7"/Cement/Run GR/J8/USIT/MDT, run 2000' of tbg and - RDMO ï- - r-I- -1- ¡ -- _ _i__'_ _'_J. _ _ _L _L _I_.J _ __ 1 1 1 I - í - - r -1- -1-1- -- I 1 1 1 I I 1 1 I - I - - - r -1- -1- 1 J. _ _ _ L _1- _1_ ..J I I 1 1 I --¡--i- -,- ì - -r -1- -1-!- ...L _ _ _ L _ L _I _ ..J 1 1 1 I , .l___L_i__I_.J I I I i - Î - - - r -1- -¡- i - -- _.1 _ I _ I- , 1 , , ..J_.1_ 1 1 1 I I -I---T-r-r-i---~ T- __i___I___.1 L L I ..J I 1 ) 1 I I ï -- ¡ r r - 1- - - Î - I - T - I I I , I , r r ..l__L_L_L_ .L , , _J._..L~L 1 I 1 1 -I-¡-T-í- I I 1 I I I 1 ¡ -'-,-T-,- ~I -! ..L L I I I l- - T I l r , , L __I.- o 5 10 15 25 TIME 40 45 50 20 35 DRill (DAYS) 30 55 prepared by WBL 5/0701 I - 1- 11.9 11.7 11.5 11.3 11.1 10.9 ¡... ::¡: 10.7 C) ¡¡¡ :¡: c 10.5 ::::I ~ 10.3 10.1 1- ~ 9.9 9.7 .,. 9.5 9.3 60 2000 3000 4000 5000 6000 7000 8000 9000 10000 o 116" set @ 115' I DRILUNG TIME AND MUD WEIGHT CURVE Lookout #2 12 1000 I 1 I I I I I I I I ~__!__~ ___~ ~__I__~____L_~__~_~_ I I I -T---- -I -+--1--+-- -1- ____L_J__I__l J I I I ¡ I I I ~...j--L_ I I I ----1-1--1-- - r -i I-^ _ _.1 I~ I I I L 11.4 11.8 11.6 11 10.8 10.6 10.4 § :E 1 10 9.8 ~ - I --I- I _ _ J _ I , ----1--1--+ I - - I - - 9 45 o 5 10 35 40 15 20 25 30 TIME TO DRILL (DAYS) Spud Well @ 1800 hrs 3/2102 Release Rig @ 1800 hrs 3/24/02 = jt9199 FIT 12;0 0 1000 2000 3000 0 ::0 4000 - - I- G) W W - II. 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'!!! ..!!. - ...- 5 10 15 TIME TO DRILL (DAYS) 20. 25 30 35 40 45 8.2 / -' ¡ ,~ DRilliNG TIME AND MUD WEIGHT CURVE PAl Spark #1 -+- Depth Mud Weight 12.0 2000 3000 4000 5000 6000 7000 8000 9000 I 1- ~ j ----I-------j '- I I 1---- I~ I I - -. f- _ J_ _ _ I r 116" set @ 1 OT I o I --'- I , - - - -I' I _ __I Drill 9·7/8" Hole r I I I I I -!-------I---- I 1000 ___L____ I I ____I_- I --- ---¡-- - _1___- I -r--- I I ----r-- ___L__ I r _L__ I I '- I r - r L_ I -----¡-- ----r I I I r - - - f- - -- I ^^ ------;-----1- I I -r- _____L I = = = = = -' = _ = _ t = =Icore 60'/reeover 60' _. __ __L___.__" I I ------ -¡-----r -I I I I --1----1-- ~j --r L o 5 Spud Well @ 0600 hrs 4/13/00 DRilLING TIME AND MUD WEIGHT CURVE Rendezvous "A" I ---I- I - -"1 I I I ~_ ___ ____-I _ _L____ _____L_____ __ _____L_ __~_____ ----ì----- I ) ____-1_____ _===j--- =~==-- ~_____=_=_ -_=_---_;----1---- ~--- ì-- --- I ~ ____L__ _J_____ - -ì----------~---- ~-- ~- -------~--- ¡---- ~ - i-- I I I I ¡ _.__~ ___:_ ) I I ,_ I --I --1--- ---j ------!--------- -I I I ----1--- - ----1- -1 11 11.4 ____-1-_____ I -, 11.2 -¡ - - - - r _L___ I I 10.8 - -- I -4 10.6 J _ I j-- ---I I I I I -¡ - - -¡ _-'_____ ____-1_ I I -¡ ---r----ì- _-1_____ _..1 I I I I - - -I _. j I ~l ---1---- r---- ______ .J _ _ L I ---ï--- -¡----- I I I L____~_ I -----¡---- - -- -j----¡ -- - I I I I =====~----==~===~=-=~-~-~-=-=-===~====~=====- I I - ----~----- I ____h- I 10.4 5: C) ¡¡¡ 10.2 ~ ::::¡ :¡: -¡ _____ .J 10 --ï----- --' _ L _ ---1 _ I ~----------~-----r---- - ~,--~ - I ~I I I ---b------I--- I ---¡-- r L: - ~__ ~ I ~~-----~----~-----~- I ! I I 4 r----~-- --r----~--- I I I I I I -------~-----r- -- -----r-- ~-----~ --- ----~ -------- ~~-~ ---,---- ¡---------- I ------ ------ ~=~ __ _ .J I --1--- -ï -- ___.J ___L____.J_____L_ I I I --<¡- --- ~ -,---- 9.2 I -Î-----,--- I I ~I .J___ 5·1/2" esg/Cement ~ --~ --l-~- 15 - -- 9 20 10 TIME TO DRILL (DAYS) 5/4/00 5/701 2000 3000 4000 5000 6000 7000 8000 9000 I I L _______ _L__ _ I I -----r--- -- r _____L ___~L I I -----]------- ____...1______ I --¡ - -1- - ------1 ----I -1----- I _~__ _ L L _____ __ I I I ---- - i-- --r- - r----- -- -r ---, I I I I I I I ------,--- r --,-----r----------r---i _~_ ___L_ __~_____L ___ ___L ¡ I I I --,-----r- -'-----1-------- -r--- __~ _L__ _ L___ ___L I I ) I I I ) I - ----__~----_~__ ___~ ----L I I r~ 1- ---------~-----~--- ~-----~ I r I ! 16" set @ 115' I DRILLING TIME AND MUD WEIGHT CURVE Rendezvous #2 o I I _L -1 I I , _ =1 Drill 12-1/4" Hole I I I I - - - I - - ~I -----1---- I -19-5/8" set @2680' 1 14.5 ppg FIT I I L .J__ I -1-- -,--- ____L _ I I - --1----1--- I I I r- -~ I r I- I I -----).. _L____ I I _ __ .J _ L I I I ì ---------,-----r---- __ __.J____ L__ _ i I I ----,----------,- ---r---- I I I I -------1-----1-- I I, I I ¡---- ¡---- -----~- 1000 I ---1------- ~ I -1------ c' - I I ~ - I ---ï-- ~-- I ,-- __-1 I I I I - --I -I I ~ - I- I -------¡----------- -l- I I ------,- L I = = Control LC. Core 60'/recover 57' , L____ I r I I ----I~ L _L-__.__ - -~- - ,. j ~TD/Run 7"/CementJRun GR/J8/USITNSP1Run ~~-----~- - ~ ~ ~-- 1 I ,'. I I 'l I l _ -J _. _ __" ----I- I- I ~,~ ~---)-- o 5 10 Spud Well @ 1600 hrs 4/8/01 (DAYS) Weight I I ~____L____~_____ ! I , _____1...-____.1_____ I - ,- I I ~-·-'l'-- -, I ---1----- .-j I I .-j I I - 1'- ~ __ ,_ _I- I - --f' _L-____ _ I .J_ _ _ I - --r=---4------ _ .1___ _ I , I I "-·r·-- ï--- __-1 I "l--_··--I--·--ì--- ..1 I I I I ,----- ." I -- -1-- -- ~----~-----~----~----- I I I I -¡- ----¡--- 1__ _ I ____L __L .J__ I I ----ï----- -1 19.2 L 15 2400 hrs 4123/01 prepared by WBL 5/701 11.4 11.2 11 10.8 10.6 10.4 !i: CI ~ 10.2 0 :::¡ :E 10 9.8 9.4 9 20 SpudVVell @ 1400 hrs 3/6/02 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 116" set @ 1 06' I DRILLING TIME AND MUD WEIGHT CURVE Mitre #1 -Mud Weight I o I I I .J. _ _i_ _ 1- _ -J_ I -f- - + -1- - r -...., - _L_ I I I í- - ---!- I --~ I --1 -j _J I I --~ -1- - + - -1- - 1 I ---1 I --1- - - ~ -ì--I- I --~--I--~--I----~- I I --1-- I I I I _1_ _1_ _ 1- I I I - I - -¡- I _ --1 I·· .~ I -. - I 1 I I I T----,--,--r +- - ---I I- I -, o 20 TIME TO 30 35 40 10 15 25 (DAYS) 4/11/02 5 12 11.8 11.4 11 11 10.8 10.6 10.4 0 :::> ::!E 10.2 9 2000 3000 4000 5000 6000 7000 8000 9000 o DRH"'I...ING TIME AND MUD WEIGHT CURVE Moose's Tooth C I I I I - = = I Move in Doyon 141 3/23/01 from Randy A ~ - - = = j ___L__ _J______ I I -----~- - - - -- --~- 1 I I I -J.--- ----------- l 1 I 1-------- ~I __L__ _J_ 1 I -----. r- -----¡--- 1 1000 ----- - ~------ - --- ---"""' -- ------- ------- - ---- -------- - ------- - ---- ------- ------ -------- ------- ------- ------- o I ______ _I I - ---- ---1---- __1____- 1 ...¡ 1 1 - - - - - - .- - - - - - - -J - - - - - _1_ - - - - - - 1 --1------ ~ I - , I I ,-- I T- I I I ______L__________ I I I _L ~ I 1 -I~ - - - - - - r- - -,'CC"--'-'T - - - - - -- - -,- - - - - -- - - - -'.-'~ - - -I- I + - 1 1 -+--.-.---- 1 - ------T------- ---1--- I -t - - - - ___J _____ I ---f--- - -I 1 ---'""-I~--- ------------- ----- _________~_____ _i_______L______~_______ ~ -----1- i10.8 - - -'- - - - ----- - 1 -------------1---- --~-- ------ ---~-------I-- 1 -------------~------ -I 1 1 - - - ~ - - - - _.1- I I shale tontrol t ~ = = = = = - 1 I ...¡ I ____J..____.__._ I - - ì-"-'''''''''- - -'- + - - _:',-',- - - -1----- ~ -I 1 I __L___ ---'------- ------- ----1--- _ L , - --ì'--- -~---- I -------1.-.-- I I --·----4 I --¡ -- --T---- -------- ~~~-- I ------1- - I I + 1 ·--,-·.,.,.·-·-1---·_--- ,.'----- --------r--- ---- ---- - ¡..m I I -------1---- ---------4- - I -------,--- _"_________J__ I I - -,- -1- - - - - -- - - ._ - - - -1- _ _ _ _ _ _ I _I ~ _ _ _ ~ = _ := = = = = = = ~ = = = = _ -"" - - - -- j TA well - - - - 1'- ------,- 5 10 TIME TO DRILL (DAYS) 12.0 11.8 11.6 11.4 11.0 10.2 10.0 wbJ 6101 ConoC:Ópi,¡Uips AIç¡ska,lnc. ) P. O. BOX 100360, ATO-1454 ANCHORAGE, ALASKA 99510-0360 Telephone 907- 265-1505 Facsimile 907 - 263-4966 To: Steve Davies From: Wayne Campaign Petrophysicist Subject: Shallow Salinities in NPRA Date: January 27, 2004 1./ This letter will document my analysis of shallow salinity issues for the 2004 NPRA drilling season. Offset wells include Hunter 1, Miter 1 PB, Moose's Tooth C, and Rendezvous A. A locator map is included as figure 1, and analyzed well plots as attachments. I may also refer to similar letters produced in previous years. Offset wells have been evaluated for shale volume, total and effective porosity, and apparent water salinity using standard techniques previously documented. Since shales contain excess mineral conductivity, I have highlighted the TDS curves for sand only, and use that for the discussion on water salinity. For this purpose, sand is defined as Vshale < 380/0. Temperature logs were run in Spark 1A and Lookout 1, a year after the wells were drilled. The freezing points in both wells were located at depths of around 980'. This is defined as the Permafrost depth. Mitre 1 PB and Rendezvous A have no~hallow sands capable of any fluid flow and thus have no shallow aquifers above 4000'. Moose's Tooth C has a package of Nanushuk Topset sands starting at 3100'. The highest sand indicates a reduced apparent salinity of 10,000 ppm in the top 10', then increases to 18-20,000 ppm for the rest of the 1// interval. The top Nanushuk also correlated with a spike in gas and this probably is the reason for this slight anomaly. I conclude that in this well, the first sands demonstrate a water salinity of 20,000 ppm TDS. The Hunter well to the southeast, has significant sand present in the Colville Group and the Nanushuk section. Ice-Bearing sands can be seen to a depth of 690' and Permafrost is below that. Sands in the Colville occur 1100'-1600'. When we discount the tight streaks, salinities calculate 9-12,000 ppm. In the Nanushuk sands (2420'- 3220'), salinity is calculated at 10-12,000 ppm. Though salinity may be slightly lower in this southwesterly direction, there are no shallow fresh water aquifers in these wells. Over the last 4 years, I have produced similar documents for wells in the "core" NPRA area. In Fig. 1, I have listed them along with their conclusions. From this body of evidence I would conclude that there are no potential fresh water aquifers in the area of ï-/ this year's drilling program. If you have questions or comments, feel free to contact me. Thank you. Wayne Campaign 265-1505 ConocoPhillips Petrophysicist 1. Wayne Campaign Page 2 ) ) ~ ", ~'('/ " ~.~~ ~t;::¡ :.¿;;.~'.:~~~E,ri\ '>i~,tt :.>::X:"':<? .~:.,~ , :, I·' C::·, ..'1" ..' !~'\~\<;:J,,;,¿~·::.,:-Vt;,é;':';'. "' ~?~.> .,' L :'"',L.'c '.~ .1 :. .., ..... '.' '.. . . 'v-: '. .....'. ~_;n . tt{!::}I~:ú}.~~fr· ,~ <' 'iI'\, .; , .> :. .'1.'<./ ".N~< ..^. c :.::;:'<' ~~~i.:" . 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Y:';>~<:i...:. o. ~ ~:'.", ~:; ,,·.,·.',:.U ",:;~ ,..},.,.;,;:, ')¡ .\,:,~:(::;::.;,:;.,::.:;:. .)¡ :'c..:,'·çj,~:'. "",~",,",. ':, .,.'L.·:¡~'4C:,:.:,.··:J':;:}'::f~ '··"\d. ;"'···,{':···;r..:,,:':":¡. ';. ',::"":': ,·..'.'....:cè,:,,'!. ;.:'~"".' '''''',. ".. _'s.,. '>"" .." .,....."...., '...*,. .... ." ',. "~'.. 'J'('. Fig. 1. Locator map of NE-NPRA wells and drilling locations. Several of these wells have been previously documented and are listed here. Wells Atigaru Pt. 1 N. Inigok 1 Inigok 1 Fish Crk Test 1 W.Fish Crk 1 Clover A Spark 1 A Rendezvous 2 Conclusions All sands below 1300' with salinity> 20,000 ppm Nanushuk Topsets with salinities of 16,000 ppm Nanushuk Topsets increase 10 to 15,000 ppm with increasing depth Limited logs, salinities estimated at 11,000+ ppm. Salinites > 20,000 ppm No shallow aquifers. No shallow aquifers. No shallow aquifers. ASP Coordinates for Spark #4, Scout #1, & Spark #8 ) ') ~~j~~:f~~~?~m?~~~¡·~,r~~~,~,~~l1t'~~.:~~~~~~*·,..... .·~~::['µe,13} . ....~(;): "·::3f7:~2~.~.QOQ,···'· . Bob, per our discussion today the coordinates for the above wells in NAD 27 ASP4 should be as follows: * * Spark #4: Scout #1: X=278,294 & Y=5,958,093 X=257,976 & Y=5,958,609 A PTD package for Spark #8 should be arriving shortly (if not already), and the coordinates in NAD 27 ASP4 should be as follows: * Spark #8: X=252,539 & Y=5,943,628 The legal descriptions in the permits remain as indicated. Thanks, Tom 265-6377 (w) 275-7352 (p) 265-1336 (f) 1 of 1 1/14/20047:45 AM Spark 8 Proposed Location SFD 1/21/2004 N ~ . I -~ ~ RECE\VED JAN 13 2004 Alaska Oil & Gas Cons. Commission ~nchorage PAY TO THE c. -r ¡,::.l",TC /¡ç â- c;ßV,' ,¡:-.1 !J~ 4CB/'/ I $ ¡ ,r'I(i /)(~) ORDER OF 7 I / ! . (.... C/ I l - f.-' T ' ( LL..- _ I V.I. C \....1 ---{Jc¿ ~jW'.j eL,¡t~> L-j: ¿PC).~Ò---OOLi'''RS Œj ~a. CHASE Chase Manhattan Bank USA, NA Valid Up To 5000 Dollars . . 200 White Clay Center Dr.. N!!'IIark. DE 1~111 _ .' _ ..,. ~.. . - (-~/ ../í/ j)' - ¡ :;~ 3 . . 0 ;{:~ ~ a.. ? . ~ 0 ? ~ ~? ~.¿~;~;:;z'jf7u <~K;;- .. ,.-.., .~ ./ /5' J/; núi ý"'12U.>/~ --_/"- 62-14/311 DATE SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS 3760 PERENOSA ANCHORAGE AK 99515 1018 ) ) TRANSMJTAL LETTER CHECK'LIST CIRCLE APPROPRIATE; LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ::5rrx..:-v L . -8 ;:2L:J t/ ----0 1,<) PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) "CLUE". The permit is for a new weUbore ·segment of existing well ' Permit No, API No. Production. should continue to be reported as a fUDction' of the original API number. stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot bole must be clearly differentiated În both name (name on permit plus PH) and API Dumber (SO 70/80) from records, data and logs acquired for well (name on permit). Pn.,OT (PH) SPACING EXCEPTION // DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject ,to fun compliance with 20 AAC 25.,055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing . exception tbat may occur. AU dry ditch sample sets submitted to tbe Commission must be in no greater ·than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. PTD#: 2040150 Administration "!~~~:gt!:§~l~;~~T~ Field & Pool._. Company C_QtiO_GOEJ:ltLLJJ~.S_8LASMJtiC..__._ _.____ Initial Class/Type _._-EXELE.EJ'l.I:L__ GeoArea .8.9_0_____. Appr SFD Date 1 121 12004 Engineering Appr WGA Date 1/22/2004 Geology Appr SFD Date 1/22/2004 Geologic C?T.. mis~.ioler: ~~o/ _._----------_._-------"-~-- Well Name: ,SPARK..8_____ ..._._._ Well bore seg Annular Disposal _.______._._____ ProgramExp_ Unit On/Off Shore .on 1 P~~mit.fe~ attached. . . . . . _ . . . . . . . .. . . . _ . _ . . . . _ . . _ . _ _ _ . _ _ _ _ . _ . . _ _ . Y~s . _ . _ . . . . . . _ . . . . _ _ . . _ _ ........... _ . _ _ . . . . . . . . _ _ _ _ _ . . _ . . _ . . . . . . _ . . . _ . . . . . . . . 2 .Leas~ numb~r approp.riate. . . _ . . . . _ _ . . _ . . . . . . . . . . . . .. . . Ye$ . . . . . . . . . _ . _ . . _ . _ _ . . _ . . . . . . . . _ . . . . . . . . . . . . . . . . 3 _Uni.ql,J~ w~ltn_ar:n~ _aod lJlJ..mbe( _ . . _ _ . . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ Yes _ _ _ _ _ _ _ _ . _ . . _ . _ _ . _ _ _ _ . _ _ _ _ . _ _ _ _ _ _ _ . _ _ . _ . _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . . _ _ _ _ _ _ . . _ . 4 WeJI Jo.cat~d i.n.a.defined PPQI_ . _ _ . . _ . _ _ _ . _ _ _ _ . . . . . . . . . . . . . . _ _ . . . . _ . . No_ _ . . . . . . ~PRA exp'-orato.ry w~lt _ _ . _ . . . . . . . . . . . . _. .. _ . _ . _ .. _ . . . . . . . _ . . . . _ . _ . . . . 5 WeJIJo.cated proper di.stanceJrom driJIing unit boundary. . . . . . . . . . . . . . . . . . . . . . . _ Yes. . . . . . . AdjaceoUease MQ8.18Q8.h.as sam~ owner:ship/Jandown~(ship. . . . . . . . . . . . . . . 6 WeJIJo.cat~d prop~rdi.stanceJ(om.o.the.rwells. . . . . . _ . . . _ . . . . . _ . . _ . _ . . . . . . _ _ Yes. . . . . . . ~~ar~stw~lI.is Moose's Tooth C,3 miJe.s.to ea.st. _ . . . . . . . . . . . . . . . . . . . 7 Suf'ficien.t acreag.e_ayailable in.drilJilJ9- unit. _ . . . . _ . . . . . . . . . . . . . . . . . . _ . . . . . . Yes _ . . . . . . . . . . . . . . _ . . _ _ _ . . . . _ _ . _ . . _ . _ _ . . . _ . . . . . . _ _ . . . . _ . _ _ . _ _ _ . . _ _ . . . . . . . . . . . . 8 Jf.d~viated. is. w.eJlbo.r~ platJnc!uded . . _ _ _ _ _ _ _ _ _ _ . . . _ _ . . . _ _ . _ . . _ _ . _ _ _ _ . . NA _ _ _ _ _ _ . V~rtjca'- weJ!. . . . . _ . . . . . . . . . . . . . . . . . . . . _ . . . _ _ . _ . _ _ _ . . . . . . _ . . . . _ . . . .. _ . . . . . . 9 .oper.ator on.ly affected pa.rty. . _ . _ . . . . . . . . . . . . _. .... _ _ _ . _ _ _ _ . . . . . . . _ Ye$ . . . . . _ . . . . _ . . _ . _ . . _ . . _ . . _ _ . . . _ . . . . . . . . . _ . . . _ . . . _ . . . . 10 _Operator bas_apprpprlate_b_ood in Jorce_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ Yes _ _ _ _ _ _ . _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ . _ _ _ _ _ . . . . . _ _ _ _ _ _ _ _ _ _ _ . . _ _ . _ 11 P~(mitcao þ~ issu.ed witho.ut cons~rvation. Qrd~r. . . . _ _ . _ . . . . . . _ _ _ _ _ _ . . . . . _ _ _ Yes _ _ . . _ . . . . . . . _ _ . . . . _ _ . _ . . . . . . . . . . . . . . . . . _ . . _ _ _ _ . _ . . . . . . _ . . . 12 P~(rnitc.ao þ~ i.s$u.eO witho_ut administ~ativ.e_approvaJ . . . . . . . . . . . . . . . . . . . . . . . Ye$ _ _ . . . _ _ _ . _ . . . . _ . . . _ _ _ _ . . . . . . . . .. . _ . . . . . . . _ .. _ _ . _ . . . . . 13 Can permit be approved before 15-day wait Yes 14 WeJLlocatedwithinareaan.d_strataauthori~edby.lojectioOO(d~(#(putlO#in_cOO1m~otS).(for_ NA..... _ _... _....... _ _ _ _ _... _ _ _ _ _ _ _..... _ _. _.... _. _ _ _ _ _ _ _ _ _ _. _ _...... _. _.. _. 15 All wells_within.1l4_mile.are.a.of (eyiew id~lJttfied (F9~s_ervjce welJ Qnly). _ _ _ _ _ _ _ _ _ . _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ . _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ . . _ . _ _ _ _ _ _ _ _ _ _ . . . . _ . _ _ _ _ _ _ . . _ . _ _ . _ 16 Pre_-produced_iojector~ dur¡;¡tion.ofpre-p(oductiOIJ le$s,than.3months.(for.seryiceweltonly). . NA_ _ _ _ _ _ . _ _ . . _ _ _ . _ _ _ _ _ . . _ . _ _ _ _ . _ _ _ _ _ _ _ _ _. _ . _ _ _ _ _ _ _ _ _ _ _ . . _ . _ _ _ . . . . . . _ _ . . . . _ _ _ . 17 ACMP.FJnding .of Consisteocy_ha$ Þ~en Js_su~d.forJbis project. . _ _ _ _ _ _ _ _ _ _ _ . _ . . _ _ _ No _ _ . . . _ _ _ Kaye .Lau.ghlh JPQ: ACMP. d.eterminati.Qo not.n~~d.eO._ 1/21/04 SF:O _ _ _ _ _ .. _ . . .. . _ _ _ _ _ _ _ . . . . . . . . . 18 Cooducto( st~in.g_provi.ded _ _ _ _ . . . . . . . _ _ . _ _ . _ . . _ . _ . . _ . _ . _ _ _ _ . ._ . . _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ . . _ . . . _ _ _ _ _ . _ _ _ _ _ _. _ _ . _ _ _ _ _ _ . _ . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ . _ _ . . _ _ 19 _Surfac~ _casing. protects.. all_known. USOWs _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ . _ _ _ _ _ . . _ _ _ . Yes _ _ _ . _ _ _ ~o USDW, See attache_d.IIShaJlow Salinities. io NPRA'~ reportj(Om. C~AI._ SED 1/21/2QO~ _ _ _ _ _ _ _ _ _ . . . . . . 20 CMTv91.a..dequ.ateJQ çi(culale.on.cQnductQr.& $u.rf.C$g _ _ . . .. . _ _ " . . . _ _ _ _ . . . _ . _ . _ .Yes _ _ _ _ _ . _ AdeçlJate excesS,. . _ . . _ _ _ _ _ _ _ _ _ . _ _ _ _ ..... _ . ._ _ . _ _ . _ . . . _ _ _ .. _ . . . . _ _ _ . _ _ . . _ . . _ 21 _CMT vol. a.dequ.ate_ to ti~-in .long striog to _surf CS-9. _ _ . _ ." . . _ . . . . . _ . _ _ _ _ _ . . . . _ . _ No _ _ _ . .. _ . _ .. _ _ _ _ _ _ .. . _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ .. . _ _ _ _ _ . . _ _ . _ _ _ _ _ _ . . . _ _ _ _ _ . . .. _ .. _ _ _ _ _ _ . _ _ _ _ _ 22 GMT will c;oy~r _all known .pro.duc;tive 1J0.rilon_s _ _ _ _ _ . _ . _ _ _ . . . _ _ _ _ _ _ _ _ _ _ . . . _ _ _ Yes . . . . . _ _ _ _ _ _ . . . __ ... _ _ _ _ . . . . . . _ _ _ _ _ . _ _ _ . _ _ . . _ . . _ . _ _ _ _ _ _ _ _ . . . _ _ _ _ _ .. . _ .. . _ . . _ . _ _ 23 _C.asiog de_sign.$. aclequat~ for:. C,T. B _&_p_ermafrost. _ _ _ _ _ . _ _ _ _ _ _ _ . . . . . _ _ . . . . . . Y~s _ _ _ _ _ .. _ _ _ . . . . . _ . _ . _ _ .. . . . _ _ _ _ _ . . _ . _ _ " _ _ _ . .. _ _ .. _ _ _ _ _ . _ . . _ . _ _ _ _ _ _ . . _ _ _ _ _ . . 24 Adequale_tan.kage_oJ re_serve pit _ _ _ _ . _ . . . _ _ _ . _ . _ . . . .. _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ . . . DOY90 141.. _ . _ _ _ . _ . _ _ . . _ _ _ _ _ _ _ _ _ . _ _ _ _ . . . . . _ _ _ _ _ . _ . . _ . _ _ _ _ . _ _ . _ .. _ _ _ . . . . _ _ 25 .If.a_re-d(iII. has_a_ 1.0:-4_03 fo.r aba.nOonmenl be~o approved. _ _ . _ . . . _ _ . _ _ _ _ . . . . .. _ .. NA. _ _ _ _ _ . . ~~w w~lI, . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ .. _ _ _ _ _ . . _ _ _ _ _ _ _ . _ _ .. . . _ _ _ _ . _ . _ _ _ _ _ _ . .. _ _ _ _ . . . 26 AçJequate _w.ellbore_ separation propOseçJ _ _ .. _ . .. .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ .. _ _ _ _ _ .Y ~s .. . . .. _ .. _ _ . _ _ _ _ . _ _ _ . _ _ _ _ _ . . _ _ . .. _ _ _ _ . . _ . _ _ _ _ _ . _ _ _ _ .. _ _ _ _ _ . . . _ _ .. _ _ _ _ .. _ .. .. _ _ _ . _ _ _ _ 27 .If ..d.iver:t~r J~q!Jire_d, do_es it meet reguJa.tiOl1s_ . . . _ . . _ _ _ . . . _ _ _ . .. . _ _ _ _ _ _ _ .. . _ _ _ Y~s . . . . _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ .. _ _.. _ _ _ . _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ .. .. . _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . . . 28 DrilJiog fluid_program sc.hematic_&.e.quipJistadeq_uat~. _ .. .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Yes _ _ _ _ _ _ _ Max MW_1L3.ppg._ _ _ _ _ . . . _ _ _ _ _ _ _ .. . _ . _ _ _ . . _ . . _ . _ _ . _ _ _ _ . . _ _ _ _ . . . _ . _ . _ _ . . _ _ _ _ 29 .BOPEs,.do .they rneelreguJation .. _ _ _ . _ _ _ _ .. _ _ . . . . _ . . _ . . . . . _ . _ _ . _ _ _ . . . _ Yes _ _ . _ . _ _ . _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ . . _ .. _ _ _ _ _ _ . .. . . . .. . . . . . _ _ _ _ . _ _ _ . . . . _ _ _ .. _ .. . . . .. .. . . . _ _ _ _ 30 )..BOPE_pre_ssratilJgapp(op(iat~;t~stto.(pu.tpsigi.n_comment$.. _ _ _ _ _ _ _ _........ _. .Yes_. _ _ _ _ _Te_stt9.35QO.psimin._ MSP.3087_psL._ _ _. _ _ _.. _ _. _... _ _. _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _..... _ _.. __ 31 _ChQke.manifQld cOl'l1pJie$.. w/~I?I.R~-53. (M.ay 84). _ _ _ _ _ . . _ . _ . _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ .. . . . _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ . . . . _ . . . _ .. . _ _ _ _ _ _ . . _ . _ _ _ _ _ . . . . _ _ _ . . . . _ _ _ _ 32 Wo.rk will Oc;CU( withot,¡t .operation _sbutdown _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . . _ _ . Yes.. _ _ _ _ _ _ _ _ _ . _ _ . _ . . . _ _ _ _ . . . _ . _ _ . _ _ _ . . _ . . _ _ _ _ _ _ _ _ .. _ . . . . _ . _ _ . _ _ . _ _ _ _ _ _ . _ _ _ _ . . . . 33 .Is. pres.ence_ oJ H2S gas" prQb.able _ _ _ _ _ _ _ _ _ .. _ _ . . _ . . _ . . . . . _ .. . _ _ . _ _ . . _ No. . . . . . _ . _ _ _ _ . _ _ . _ . . . . _ _ _ _ _ . .. _ _ _ _ _ . _ _ . . _ _ _ . . . . . _ . _ _ _ _ _ _ . . . _ _ _ _ . _ . _ _ _ _ _ _ _ . . . _ _ 34 Meçha.nical.colJdjti.on 91. weJls within ~OR. v~rified_ (FQr.ser:vic~ well QnJy) _ _ _ _ _ _ _ _ _ _ _ _ _ . NA. _ _ . . . _ . _ _ _ _ _ _ _ _ _ _ _ . . _. _ _ _ . . . _ _ . _ _ _ _ _ _ . . _ _ .. .. _ . . _ . _ _ _ _ _ . . . _ _ _ _ _ . . .. . _ _ _ _ . . _ _ . _ . 35 P~(rnit cao Þ~ issu.eO w!o_ hyçlrog~n_s_utfiçl~ measures . _ . . . _ _ . _ . _ _ . _ _ _ _ _ __ _ _ _ _ _ .Yes _ . _ . . _ _ 1:12.$. was_not Qb$ery~d_ io o~aJby J\10_0$~'s 10.0th. G welt H2S se.nSQrs wiJl Þe !Jtilil~d_ d_urilJ9- driJling operatioos, _ _ _ 36 .Data.pr~seoted Qn_ potential 9verpres_sur~ ~Qnes. _ .. . . _ . . .. . . . _ . .. . .. _ .. _ _ _ _ _ _ . _ _ .Yes ... _ _ _ 10_.5 ppg _pre_S$UJe may Qc_cur.u.nçl~r .permafrQs.t,.drOP$ to normal from .30QO:-570Q'. buHds.to :11.3 at 7.40Q' 0. _ _ 37 _Seis01ic_analys.is.o.f shaJlow gas.zooe.s_ . . . . . _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ . . . . _ . . . . _ _ Yes.. . _ _ _ .. _ Gr_eg Wilson. CP~I. 1/5/04: No.oÞviolJ..s.gas indicators in.shaHow .portions.of this_3.D_dataset._ SfD _ . . .. . _. . . _ 38 .S~abed cond.iti91J survey .(if Qff-sh9(e) .. _ .. _ . __ .. .. .. . . . . . . . . _ . . _ .. . _ _ _ _ .. _ _ . _ . NA _ _ . . . . .. . . . . . _ _ .. _ _ . _ _ _ _ _ _ . . _ . _ . _ _ _ _ _ " _ _ _ . _ _ _ . . . _ _ _ _ .. _ .. . _ .. _ _ . . _ . . _ _ _ . . . . . . . . 39 _c.o_ntact.l1.a!1le!phQn.eJQr.l/\!.e~kly prQgress_reportsle~ploratpry .only]. . . _ _ _ _ _ _ _ _ .. _ _ _ _ _ _Yes _ _ . _ .. _ _ 10_1'11 6rassJielo SQ7.~2.6_5,:6377. _ _ _ _ _ _ _ _ _ _ _ . . _ _ . . . . . _ _ .. _ _ _ " .. .. _ _ _ _ _ . . _ _ _ __ . . . _ _ _ _ . _ Date: Engineering Commissioner: Date H2S was not observed in the nearby (3 miles) Moose's Tooth C well. Spark 8 will be mudlogged, and H2S sensors will be utilized during drilling operations. Shallow hazard report located in Carbon 1 file (203-218). . Public Commissioner Date D D { (