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MAR, 1,2002 8~01PM KING SALMON PLATFORM Monthly injection Report NO, 558 P, 5 WATERFLOOD IN~CTOR MONIHLY REPORT I[I~6 SALMOH H.,ATFOtLM: IiBU K-15' 50T332017101501 i i iiii · _ _ iii __i wen OaJe ars ~olmpe Tbg 9.62~ Csg On .,InleoM Press Press It-ess i i ~ l i ~ ;~ _ _, ~ :.~ _ _. ii ~. i i .. ~Il .... ' - I ~U K-15 ~4/02 ~ 115~ ~30 ~ .19 -- ~ s L sk ~ m ~ m ~ ........ m .... ".~ ~- ......... : ..... ~U K-15 ~5/02 ~ 11491 ~20 ~ 30 ~ ~-15 ~7/02 ~, 11709 ~20 ~ 30 ~ K-I~ W~02 ~ ~20~8- ~ ~U K-15 ~I 1/~ ~ 11506 ~ ~ 30 ., .., . __'- ___,.. ,- ~ ~-1~ ~/~ ~ 76~ 1700 m~-i~~ ~13/62 ~ 9~ ~i~ 3o ~ ~-15 ~14/~ ~ 11010 ~16 30 .'15 ~U ~-15 ~15/~ ~ , 10670 ~ 0 ~U K-15 W16/~ ~ 10981 P~ ~0 ~U K.15 2/17/~ ~ 10805 ~ 30 5S ~U K-IS ~19/~ ~ 11216 ~10 20 0 ~U K-15 ~20/02 ~--~ 1125~ ~20 ~ 5g ~U K-15 ~211~ ~ 70~0 1900 50 55 -~U K-IS- ':: ..... 2/~'~ ...... ~ '~11456 "~20' :' ~U K-15 ~/~ ~, 1~76 ~ $0 55 ~U K-15 ~/~ ~' ~275 ~20 50 55 , _ ~ i __ ~ i i ~::lB ~ i m _ s~ . : ................. ~j ....................... : .~.,~,-r,-~'.'~ ~U K-15 ~/~ ~ 10196 2150 50 55 ~U K-15 ~7/02 ~ 9869 2110 55 59 - ~U K-15 ~g/~ ~ 10506 2170 55 5g . . .............. ¥o~ atn u~er n~ 2~ ~n this w¢~it~ and th~ I~T: hvs lx~ hk 1~ ~imes sln~e 10/27/2090, htlp ://kodiak. anchortown,unocal, com/Survdllauce/Inj ector_V adanceReport, asp 3/1,/2002 FEB, 1,2002 3'41AM KING SALMON PLATFORM ~~1~, 0,,.~~ Monthly Injection Report NO, 861 PP, 51. o£: WATERFLOOD INJECTOR MONTHLY REPORT KING SALMON PLATFORM: TBU K-15: 507332017101S01 On Inj~d ~e~ Press ~ress ~u K45 ~/~02 24 ~ ~ 8 ~7 2~4o ~o 39 TBU K-15 II3/0~ ~ 12325 2~40 35 59 ~U K-15 I/4/02 ~ 11934 2340 30 59 mU K:i5 '- 1/5/02 24 1i654 ~40 30 60 ~U K-15 1/6t02 24 11443 ~40 30 60 ~U K-15 1/7/02 24 · "i17~. 2340 30. 59 ~U K-15 1/~02 24 11504 2320 40 20 ...... . ....................... TBU K-15 ' I/9/02 -' 24 11~72 2~'2~ ..... 40 ........... 20 ~U K-15 1/10/~ ~ 11745 2320 40 20 ~U K-15 1/11/02 24 11769 ~20 40 30 ~U K-15 1/12/02 24 11731 ~20 40 30 ~UK-I5 1/13/02 24 11318 ~20 40 .................. '~'5' ~U K2i5 1/14/02 ~ .............. ~]'191 2320 40 30 ~U K-I 5 1/15/02 ~ 112~ 233 0 28 55 ~U K-15 1/16/02 24 11123 ~30 28 55 ~U K-15 1/17/02 ~ ~i541 ~50 29 55 ~U K-15 1/18/02 24 11571 2330 29 ~U K-IS 1~i/02 "~ 11899 2330 28 55 mU K-ltl lm/~ ~ 11937 ~30 28 27 ~U K-I~ 1/23F02 ~ 11861 ~0 29 27 ~u K45 V~/02 24 "-i~2~5 - ~2o 28 ~U K-15 1/25/02 24 11698 ~40 2g 30 TgU K-15 1/26/02 24 11721 ~40 30 2a ~U K-IS 1/27/02 ~ 11409 2320 30 29 ~u Kd5 ~a~02 ~ ~ in0~ ~40 29 ~,0 ~U K-IS ........ lB0/02 16 7705 ~I0 ~U K-15 1/31/02 24 11931 ~30 ~ 59 http://kodialcanchortown.unocal.com/Surveillance/Injector_VarianceP, eport.asp 2/1/02 DATE ~2/0f/0f f2./P4/01 fW0?/0f f2/Oa/Of f2/fO/Of f2,'f,~'O'~ f 2/ f TtO f f2/fglO! f2/f9/Of f2/2f/Of fZ,'27/Of f2/Zg/Of 'fZ,~f/O'~ .~E~fe o o ! ' '~oo '~oo eo 'g~113 o o I too 85 58~1~3' ~ o 'l too "1oo 59t7Zt ~09 6.~ff 2~0 20 0 .._ ~3528 ' 11807 ~ 2330 20 10 . . 6~68 .._ ~ 1.7~ 70 . 20 ., 20 6~e o o 6o ~o 6o 609627 6~9 9.7~ 22~ 30 10 5~ODff 2~9 ~.6 60 40 20 6~4287 ' 2192 ~'.25 ~0 40 ' ~26~0 ~1623 ~ " ~20'" ~ lO 637736 " 1't~2~ ~ ' 2320 ~ 64~ 1t3~ ~ 2~2b 20 10 672861 '- 1t7~ '~ 2320 ~ " 20 6~18 .: t~857 ~ '23~, , 20' 20 696101 11689 24 2620 ~ 20 '- 707~ 1173~ 24 2330 "~0 20 71~ 4166~ 23 2310 ~ 26 732176 - 4~774 ~ 2320 20 20 ,, 74~G~ ~6 ~9 232o 20 20 753~59 4t~5 ~ 2320 ~ 2S 766929 1~5 ~ ~20 20 20 7~8362 ' t~23 24 '~ ~ .... ' ~50A65 12213 ~ 2~0" ~ 26 802403 11938. - 24 236~ ~ 25 81~ 1t~7 ~ 2360 ~ .. 20 ~59 1t~ ~ 23~0 40 20 83729~ "-1t~ '~ 23~0 40 ~693 t13~ ~ 2360 40 30 8~t25 11432 ' ~ 235~ 40 8716~0 4~426 24 2350 40 i I i iii TOTAL. 28643T !(-22 METE[ ~ '" " BA~C$ ~RG TUBIN$ 9 r~6 'IS 3/~ READ]NG INJECTED INJ PRES~ PRESS PRESS 2~709 o '" o' [, o b' 330 2.56f, i~ 0 0 0 5 ' 360 2~7~ " ~' 0 0 0 37~ ~ ~ o o , ,o, o 2~6789 "0 ' 0 40 O 420 i il 2~6~89 0 0 O 0 180 2~6789 ' ' 2~6789 "~ b 0 ' ' 0 0 420 2~6789" O 0 0 O 360 2~Tee 0 0 '- 5 0 4~ ~9789 0 O' O 0' 450 i 266789 0 0 O 0 460 256769 0 0 ' ' g 0 4eo 266785' " 0 ' 0 'O 0 46O ZA67~9 0 O' 0 . , 0 480 266769 0 0 0 0 480 2~789 o o o o 48~ 25578e - o o ' "266785 0 o " D 0 ' 2~7~9 O. 0 .... 0 ._ 256789 O 0 0 0 605 266769 0 '- 0 'b 0 505 2ff6~69 .... 0 ' 0 0 0 6t0' 256769 0 O' "0 0 '~10 2BsTd~ o o o o ' ~6789 o '- o 265789 0 O 0 0 60~ ' '2~6789 0 " O O 0 60P . , -. 288789 0 0 0 0 605 2~6789 0 0 0 0 ~08 ~ 2~TflB 0 '" 0 0 0 i , , TOTAL 0 "'K-t; I · METER ' ;iARREI.~ ' HR8 '~UmNo 9 6~1~ t3 3]8 ~EADII~ MaECTED flu Pm~ F~tETS.q ~s 0 0 .... 0 '" 0 'O 60 ' 42ff- '42~ - O 0 O ~ ~0 430 874 874 2 1490" ~O ~ __ -- .. ~- ' ~428 9J82 22 Z~SO;0 0 ..... 4~8~ ~8378' ~.7, ~00'' 26 ' o' , ~ , , ~ S473T t~g~ ~ fl~ 20 0 666?o " ~q~3 24 ~o 20, o ' ~763' 13202 ~ 2~ _20 0 e5732 - ' ' t0~9 ~ 23~ 20 o 76~28 ' , 4~7~ '24' ~o ' 20 ,' 0 ~ 87T~ff 1t2~ ~ 2360 20 O e~12' ' ' loe~ ~ 23~ 20 0 109302 ' t~ ~ 2350 20 " 0 120~ 10~2 ~' ~325 20 0 ' ~3~2~0 41016 '~ 23~' ~ 0 _ ~42291 - '~t~1 ~4 "'~30 20 0 _ . . 1 S~7O" 105~ ~ 2320 20 O ' 163~53 10674 ' ~ 2~ 26 'O - i 7~OO -1 14t69 24 ~20 ~ 0 ~a~ ' 1~e7 ~ , ' '2660 ~ 0 ,, 190093 . 4229~ .... 24 wo 0 o ~ ., . ~2i1167 '4~74 24 ~70 0 ~. . 0 . 2~5 12176 ~ ' ~ ~0' ' ' 0 0 ' 2476~ t2t7~ ._24 ~eo 0 0 ~ t3~ 25 ~0 0 9_ 27~610 t2312 ~ 2~' 0 0 28~1 _ .t~g~ ~ ~0 O. .. 0 I 2~7~7~ ~2~s ~ ~o o o TOTAL 32266R K:22 J ... , " METER. BARRELS HF~ 'TUB1NO 9 ~6 ~3 REAOING. IM,JEG.TED INJ PRE~8. PRE~8 PRESJI ,o ~ ,~o · o o 460 0 O 0 ' 0 '0 496 ..... 4022 4022 ' 9 1250' 1~'00 160 _ 122e9 e2rr ~ 1249 ' t2~0 L 160 2'i'371 9072 24 '~ t4~ t260 18 · 30346 ' 8e~'4 :2o' 0 1280" 18 - 3402,5 " 36B0' ' ' 9' 1aGo 'L"-16:~O ' - 230 4~7t3 '116ee 2.4 2t00 . 1780 240 e447e e~s,. 't~' 0 0 , 120 -- s,~,7e; o 0 0 .0 , aa6 ~4478 o o o' ' o 400 ,.u~;F8 5, o . o' 'o , -' ,0o"' - 64478 0 0 0 0 44O 64478 O 0'' 0 ' ' 0 ,, 470 _ -- '64479 0 0 O 0 490 64~17,9 ' 0 ,' O, · 0 0 SO0._ 6,4,478 ' ' 0 0 0 0 500 ._ "'~1~78 6' '~ o ' o " o 84478 ' 0 ' ' '0 0 O 510 __ - ;54478 ' O 0 ' O 0 520 , , . , , , ,.. , - 64478 I 0 .4~e o' o" o 'o 82o '~s,47a' 'o ' o o ._ _o 620 '' s~78 ' .0 .... o o o 620 54478 '~o' (~ o ' o "620 64478 ' o o .... o .. o 62o _ - ~E)4478 0 O' ' 0 0 520 - ,,q,479 " 0 ' ' 0 0 ' 0 620__ 64478 ' O 0 '0 0 ,.520 .... 817't0 ' - ,7232 11 "1900 't56(~ ' 90 TOTAL 81710 _ OCT, 1, 2001 4'35AM KING SALMON PLATFORM o, >Historical D~a :,Wells ~ (d~lly I~ ,terflood Injectom Select Tbg S~rtng: ITBU K-15 i~_ Select Time Period: ILast Month Report Name NO. 852 P, 5 ,,~ Tbg String Time Period Date Created Waterflood Injector Well Status T~U K-lS Last Month 1011101 Date Leng~ Volume %"bg Press Cs'g Pre-ss Outer Csg Press (hours) (bpd) (psi) (pm-) (psi) 9/3o/0z 0 o S0 420 69 9129/0! 24 0 40 400 69 9/27/01 24 0 40 420 69 9/26/01 24 0 40 420 69 9124/01 24 0 50 380 69 9/23/0[ 24 o 50 380 59 9/22/0! 24 0 ~0 400 69 9/2%/01 24 0 SO 385 68 9/20/01 2~ 0 50 360 69 9/~9/0! 24 0 50 360 66 9/18/0! 24 0 40 370 67 9/17/01 24 0 0 340 69 9/16/0t 24 0 '0 330 69 .9/15/01 24 0 ' 0 310 68 9/14/01 24 O 0 280 68 9/13/01 24 0 0 270 69 9/12/01 24 0 0 270 69 9/11/01 24 0 0 260 69 9/10/0~ 24 0 0 245 6S 9/9/0:1. 24 0 0 240 65 9/8/0'~ 24 0 0 200 65 9/7/01 24 0 0 200 60 9/6/01 24 0 0 980 ~0 9/5/01 :[4 0 0 970 60 9/4/01 24 0 0 850 §0 9/3/01 24 2028 100 700 63 9/2/r0! 24 8742 2220 460 63 9/1/01 24 9021 2210 460 63 Comments P~ge 1 o,f I End of Report SEP, 1, 2001 2' 15AM KING SALMON PLATFORM NO, 274 r~p, 4- U.L t ]xt'tp://kodiak:.anchortown.unocal, com/Surv~ifla-cedInj~or~a~p 9/1/01 1,2001 7'54AM KING SALMON PLATFORM /I '--NO. 576 .... P. 5, 1 ofl RECEIVED Monthly 'Injection Report JUN O ~~ WATERFLOOD INJECTOR MONIItLY REPORT KING SALMON PLATFOP, M: TBU K-15; 507~32017101S01 i[ i i i [ _. ~ i i. _ i wen Vat~ ltr~ Volume Tbg 9.62S C~ 'i3.3'/~ C~g On /njected Press Pre~ Press ,s'u~:-t~' ,,," dKol ' .'2~ ' m1~ , "~ ' ~o " '~00 --' , i n , .i [ .. mu K-~s 5/~101 24 x2,~ ~0 520 500 , .. i , · ,' ' ,, ,.. , , n ~, ~U K-15 5/~01 24 12848 ~0 520 ~0 I Il ] ' Ill ltl I I ~U K-15 5/~01 ~-" 12700 2~ 520 ' '- 500 I n I Il Ill II J II n III ~U K-15 5/7/01, 24 12~ ~2'0. - 520 .... i i mi [ i l, , ,, ,,,..~ . '' I , I i , ,, , , l, d ~ , d . . ~ K4s ~! ~4 ]~06 2~0 s20 mU ~-IS 5/10/dl ' 24 125J 1 2420 520 " ' m m .m mm ~U K-i'~ 5/11/01 24 ' 1286g ' ~20 S20 " 44 ~U ~-]s 5/txo~ ~4 nsss i~60 s2o ~. . ~U K-IS 5/13/01 24 1~36 ~20 520 45 --- . . . ,,, ,, ,, '~U K-15 52i~01 24 I~ 2g$0 S80 , · , ,, { ~ ~ ,~, ,. m ~Uk-IS 5/15101 ~ 12119 - ~ -- 5so 4o .... , ......... , i,1, ill a Il[Il [ I . . i . i ~U K- 15 5/16/01 24 121~ 2~ 580 40 ~U K-t5 5/17101 ~ 12063 2400 600 , :~u ~.is s/~)o~ 2~ n09s 2~0 ~ - 42 m, il d , . I * * I I I, mU K-IS 5/19/01 ~ 12002 ~0 6~ ~ 42 m , Il .... mi m il J m ~UK'Ifi 5al/Ol 24 I21~7 2400 620 42 s . s, ,~ ~.. ~U K-i~ 5/2~ 24 i2142 24Z6 640 ~U'K-15 Sa3/0t ~ 12124 ~30 ~0 45 ~U K-J5 5]24/01 ~ 12133 2~0 ~0 , , . ,,, ,,, t,, ......... i,, , ~U K-15 ~-/~/01 ~ 1~42 ~0 -~50 45 i, i, i m . I m .., Iii ,, , ...... . ,.~ · . . ,, , _ ,., ~U ~-1~ " $~7/01 '2~' 12520 2~ 660 mU K-I~ 5/2V01 24 1~90 2~ 650 46 TBUK-I~ 5)2~m1' ,,24 1~37 , ~0 650 42 mU K-15 -'5~1' 2i 1233( 2400 ~0 -' 42 ~U K-15 531101 24 124~ ~10 680 ~ro~ at~ met uUmln:x 4715 ott this w~bslte ami th~ page iu~ been hit 35 lieael sin,, 10/27/2000. http:/Jkodbk, auchorto~unocal.com/$~~e/ktjector_VafianccR~o~p 611/01 DATE: 0~o~! METER 'BARRELS HI~ TU~G 9 &l,8- ~J3 _1,,.44~ ~..4z~ 23- 2620- 4.o 2~ . .. !~ ~ 2630 '4,0 430 ~2304 1~ ~ ... ~620.. ~ 40~ 420 ~371. .1~. . ~ 2620 4ee 61~ ~0 8,6 lOO 7e0 746 .... 6~62 ~2t 7 2300 640 620 - . ~ ......... 781~0 ~3~8 ~ ~o 4eo ~o, . 9~212.- _; ."~2 _ . ~2~eo 4,0 1037~ ~2~2 24 ~0 .. ~ . .~0. !a~3~ ... ~7 ~ ~oo __~ ~2616 42g~ 24. _ 2600 ~O__ 1~!9' .. 12~ 24 2~ __ ~ _ 11~ .t2f21 . ~ 2~ ~ ..... ~977 11079 .. ~ 2390 490 " ~0' 2~26~ tt9~_6 _. ~ ~3~0 ~0 2~743_ 11M ~ ._ ;390 _ ~0 460 .2~S~3 _ 117~ ~ 2450 _ 480__ 248~ ~. 24 ~4eo. .- 6Qo 46~. 26Q885 .... !~ 24 2400 $0e ._t8o 272776 ~t~t 24 2060. ,,51o 490 266318 12~2 24 ~oo S~b ...... 207~6 .... 12~ 24 ~00 510 ~.,~. ~8823 .... 12~7 24 . ~. 6~ ..... 490 322143 _ !~ ~ . ~ ~ 3~t _ ~2~ ~ ~ ~p . ~7 ,492 ~8 .121~ . ~ ~ ~7 402 .. K:22 1 METER ~,RRELe -'#~ TUBli,~ 0 rde n~_..ml~ mJ;~D INJ ..Pl~Sq...~ . PREss.. ....~l~SS o 2?70' '27~o z:i ,'i,'a~o ~ ',~o .6,,670 ...... 2,m)o ~ 11oo . _ .840 t8o 8358 2788 24 t10r0 92O 18o ii I I I · _'U170 .. 28~ .... ~ t100 02o 180 .. 12o2.4 ~746 .... e:6. 1oo o tQo I I I I . P,rora,ted 876 7_ _ . t200 1020 220 . p .r~'. a..te:d ' .,~2. 24. .. t200 11)40 220 1..8eOD. ...... .,~t2 24 _. 12S0 1Q60 2.357.2, ...... 4..772 .... ~. t260 1060. .210 , ,28~302 .... 47~ 24.* i260 1070.. ~3037 4736 24 1250 1060 206 _ 3.")7.48..~"' 47t,j 24. t260 I080 L:_ .200 '~. l.. 4..2.409 ...... 4661 24 1250 1060 20,0 . --. .... 24 1260 1060 206 , 4,,7,om~ .... .4~_? ...... 8,~.0_ .. 46.74. ~ _ 24 125P 11)60 200 8.6.226 4586 ___ 24. _. 1260 1060 204) 60848 4622 24 1260 1060 210 ,, , , ~ - 65 596 47.48 24 1266 1060 210 10488 ....... .4_,_,_,_,_,_,_,_,~_ __ 24 . 1260 . 1.0.60 210 7.~452 ,.,4~16~..; . ~24._ _1260~j .. 1.060. .2t0 .... 8.046.2. 601.0 24 1260 1060 _.210 ,.. p.~,~40. . 6o78 .2.4._ . 12p0 ., 1,o6.0~ .22.o .... 8.0.607 .... S0~7 24--- 1250. _ 1060 .2.20 . 95618 .... .60~.~_ _ 24 _. .1260. 1060_ . 220 100653 604 24 1260 1050 22~ 110646 4962 24 1260 'Jo60 2,30 t½0997 8440 '24 '? ' 1260 -'~ -t082 23o - 1~099'7 '4000 ' 24!, 1260 .." ~0.62' ' 230 .......... 126007' . _4..91~q.. . 24 . !6Q0_ 't360 260 , 'q,26897 o , TOTAL 13O66O Pag~ 1 of 2 Monthly Injection Report 0 . . ~L- WATERFLOOD INJECTOR MONTHLY REPORT KiNG SALMON PLATFORM: TBU K-I 5: 507332017101,.q01 Hfs Volume. Thg ~.625 Csg 13,375 Csg Welt Date On Injected P r~s Press P · TBU K-15 3/1/01 8 1573 tg00 300 280 TBu K-15 3ff2/01 24 2734 1720 ' 340 . 300 TBU K-IS - 3/3101 24 6351 1940 [, 300 ..... 280 TBU K-15 _3/4101 24 11:526 2~50 ' 220 ._ _ _ 200 TBU K-15 315101 24 11700 2540 200 36 TBU K-I 5 316101 24 11000 2540 220 [_ 35 TBU K-15 3/7/01 24 18802 2540 220 35 ! · TBU K-15 3/8/01 24 13900 2540 220 35 TBU K-15 3/910t 24 ! 3939 2560 450 36 TBU K-15 3tl 0/01 24 13922 2560 480 36 i i i !· i i i -- 111 TBU K-IS 3tl It01 ~4 1a948 ~560 480 440 i I I I II I I~U K.I$ a/12/01 :14 14171 2540 ~0 i i i- i ~BU K-IS 3/IJ/OI 24 14lgl 2550 4~6 35 ..... TBUK-15 3ti4t01 24 14t12 2550 465 - - :~ 36 i ,,, , Ta U K- 15 3/15/01 24 13982 2550 465 36 TBU K. 15 3/16/01 24 13912 2550 450 36 ,_ TBU K-15 3/17/01 24 13873 2550 460 36 II I Ill I · TB U K- 15 3/18/01 24 13834 2560 460 36 TBU I'(- t 5 3II9/01 24 13921 2560 470 36 Tard K.15 j 3/9_0/01 24 14044 2550 0 37 TBU K- 15 3/21/01 24 14028 2560 460 38 i - , , -- , TaU K. 15 3/22/01 24 14066 2550 460 38 TBU K- J 5 3/'23/01 24 14080 2560 460 37 TBU K- 15 3/24/01 24 13 945 2560 460 37 em I I I I II - _ ~ I i i RECEIVED APR 0 2 2001 http://kodiak, anohortown.unocal.¢om/S urveillance,/Injoctor_V arianceRcport, aSl0 4/1/01 Page 2 of 2 TBU K-15 3/26/01 24 i 3774 2560 460 37 TBU~k-I~ 3/27/0t '24 13672 25~0 460 430 i · ,, . n, '~BUK-15 ~/28/01 24 134~4 2560 460 430 TBUK-15 3129101 20 "119~-~' ' 2500 '~80 '440 Ill · i tlUU I'BU K-15 - - 3130t01 24 14481 2520 460 430 ....... IBU K-I 5 3t3 it01 24 14262 2520 0 430 ........ ~. , -- .... ., RECEIVED APR 0 ? 2.001 Ala~l~a O. & Gas Cons. Commission Anchorage http:t/kodiak.anzhortown,unocaLcomlSurvoillan¢¢llnj~otor_VafianceRelport.asp 4/II01 Re: K-15RD Variance Request Unocal Corporation Agricultural Products 909 West 9* Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL ) Tom Maunder State of Alaska AOGCC 3/22/2001 Dear Tom: We have completed the pressure test for K-15RD on March 13th which demonstrates tubing packer integrity. Attached are a Form 10-413 and the pressure test data sheet. Since this well was just worked over with new tubing/packer and we have proven their integrity, we are asking for your approval of the attached variance for 4 years. Please call me if you have any questions, 907-263-7830. ~'l~i:i stto~h~ Senior Reservoir Engineer \XAk-Anchorage\Groups\AOGCC\Correspondences\Aogcc King K-15RD Variance Request 3-22-01.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: MIT Perforate: Other: 2. Name of Operator UNOCAL 3. Address P.O. Box 196247 Anchorage, AK 99519 - 6247 4. Location of well at surface Leg 2, Conductor 9; 611' FSL, 121' FEL, SEC 17, T9N, R13W 5. Type of well: Development: Exploratory: Stratigraphic: Service: X 6. Datum elevation (DF or KB) 7. Unit or Property name Trading Bay Unit 8. Well number K-15RD 100' At top o[ productive interval 2283' FNL, 4' FWL, SEC 22, T9N, R13W At effective depth 2526' FNL, 125' FWL, SEC 22, T9N, R13W, UM At total depth 2577' FNL, 147' FWL, SEC 22, T9N, R13W, UM 9. Permit number 79-0034-0 10. APl number 5O- 733-20171-01 11. Field/Pool McArthur River (Hemlock) feet 12. Present well condition summary Total depth: measured 12200' feet Plugs (measured) true vertical 9829' feet Effective depth: measured 12170' feet Junk (measured) true vertical 9804' feet Casing Length Size Cemented Structural 204' 24 Pile Driven Conductor Surface 2301' 13-3/8" 1150 sx Class G Intermediate & 400 sx Class G Production 10690' 1000 sx Class G Liner 1720' 382 sx Class G Perforation depth: measured RECEIVED Measured depth ~R ~__TrTuTveO~!al depth 84: . 384[laska Oil & Gas Co'ns. Co~mlssmn 2401 Anchorage 2293' 9-5/8" 10790' 8631' 7" 10457' - 12177' 8374' - 9810' 11070'-11100', 11120'-11180', 11220'-11240', 11260'- 11300',11380'- 11440',11520'-11540' 11596'-11630', 11660'-11702', 11764'-11840', 11880'-11920', 11940'-12030', 12045'-12126', 12146'-12160' true vertical 8870'-8895',8912'-8964',8999'-9016',9033'-9068',9136'-9188',9256'-9274' 9322'-9351 ', 9377'-9411 ', 9465'-9530', 9563'-9597', 9613'-9688', 9718'-9768', 9784'-9801' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 @ 10,372' MD; 3-1/2", 9.3#, L-80 f/10,372'- 10,600' Packers and SSSV (type and measured depth) Baker FB-1 Packer @ 11,451' MD, Camco SSSV TRDP-1A @ 295' MD 13. Attachements Description summary of proposal: Detailed operations program: BOP sketch: See attached data 14. Estimated date for commencing operation 16. If proposal well verbally approved: Tom Maunder Name of approver 3/22/2001 Date approved 15. Status of well classification as: Oil: Gas: Suspended: Service: Submitting data demonstrating csg integrity. 17. I hereby//ce~fy~tha~;~'".~/~:==~'~the fore_acing is true ...... and correct to the best of myk~'-~kn°'"wledge' Signed: / ~r///'~/ix ,/ Title: ~...,i U-'/,~' " FOR coMMIsSION USE ONLY Conditions of approval: Notify Commission so representative may witness °' Plug integrity BOP Test Location clearance 0 Mechanical Integrity Test Subsequent form required 10- ~,~Q ~ c~. - / Approved by order of the Commi~ioner 0 T~y!or ~am,~:~nt Commissioner Date Form 10-403 Rev 06/15/88 O IGINAL SUBMIT IN TRIPLICATE k'-/,Yl iz=.~~. ...... ~ Enter Ac}. ual_~t~t Datetrlnm in thi~ Cell ~ a ~' and ~a ~" ~ prm 200 ~1. Z- ~ - o 1 /: N~ ~ E~r ~1 O~i~ of ~*Tu~e 0~nqe Hem MonRoHng ~ h~r ,. 'v,' ........... UNOCAL ) RKB to TBG Head = 33.47' 10,457' 10,790' SIZE 13-3/8" 9-5/8" 7" Liner 3-1/2" Scab Liner Tubing: 3-1/2" 4-1/2" WY 61.0 47 38 9.2 9.2 12.6 ,,i'" Trading Bay Unit Well # K-15RD As Built (2-10-01) CASING AND TUBING DETAIL GP~tDE CONN ID TOP BTM. K-55 12.515 33' 2,401' N-80&P-110 8.681 34' 10,790' P-110 6.184 10,457' 12,176' L-80 Butt(SPC) 2.992 11,579' 11,714' L-80 Butt (SPC) 2.992 10,372' 10,600' L-80 Imp Butt.(SPC 3.958 33.47' 10,372' NO. Depth 1. 33.47' 3.958 2. 3. 10372' 2.992 4. 10600' 4.00 5. 10600' 4.00 6. 10649' 2.813 7. 10682' 2.992 Casing Scab 8. 11579' 9. 2.992 10. 11714' JEWEI, RY DETAIL Item FMC Tubing hanger,UH-TC-14, Type H BP¥ Profile 12" x 4-1/2" EUE Top x Bottom (x-over below hanger) 4-1/2" L-80 Imp Butt 12.6 lb/ft and 3-1/2" L-80 Butt 9.2 lb/ft Tubing x-over 4-1/2" Butt x 3-1/2" Butt Locator seal sub (4-3/16" OD) and 15 each seal sub 13.53' in length Baker Model "8340F-1 permanent packer with 11' SBE and V2 muleshoe "X" Profile Nipple WLEG Baker 7" 8340F-1 with 5' MOE 3-1/2" scab liner with locator and 5' seal stack Baker 7" 8340F- 1 permanent packer w/bottom guide _--_= G-1 ---- G-2 -=-= G-3 ---- G-4 ---- G-5 ---- G-6 B-2 10 B-3 B-3&4 E---~ B-4 =- --- B-5 COTD = 12,175' TD = 12,250' MOl F AN~I PERFORATION DATA Zone Top Bottom Amount Details G-1 11070' 11100' 30' 4-5/8" 6spf (2-02-01) G-2 11120' 11180' 60' 4-5/8" 6spf (2-02-01) G-3 11220' 11240 20' 4-5/8" 6spf (2-02-01) G-4 11260' 11300' 40' 4-5/8" 6spf (2-02-01) G-5 11380' 11440' 60' 4-5/8" 6spf (2-02-01) G-6 11520' 11540' 20' 4-5/8" 6spf (2-02-01) HB-1 11596' 11630' 34' Isolated by scab HB-2 11660' 11702' 42' Isolated by scab HB-3 11764' 11840' 76' 3-3/8" 6spf (2-02-01) HB-4 11880' 11920' 40' 3-3/8" 6spf (2-02-01) HB-5 11940' 12030' 90' 3-3/8" 6spf (2-02-01) HB-6 12045' 12126' 81' 3-3/8" 6spf (2-02-01) HB-7 12146' 12160' 14' 3-3/8" 6spf (2-02-01) Fish: 7" bridge plug drilled up and pushed to bottom of well 10/89 Note: Pressure tested tubing x 9-5/8" annulus to 1000 psi for 5 min on 2-11-01. Pressure on 13-5/8" annulus built form 0 to 100 psi. ;\Lk..E~ VED MAR 2 7 2001 Anch~ISED: 2/10/01 Change to K-15RD Surface Hookup. Subject: Date: From: To: CC: Change to K-15RD Surface Hookup. Tue, 27 Feb 2001 16:17:38 -0800 "Ruff, Christopher A" <ruffc@unocal.com> "McMahill, Randy" <mcmahir@Orion. Unocal.com> '"Tom Maunder'" <tom_maunder@admin.state.ak. us>, "Johnson, Dwight E" <johnsond@Orion. Unocal.com>, GRP AK CI OO&E Team <GRPAKCIOO&ETeam@Orion. Unocal.com>, GRP AK King Salmon Platform <GRPAKKingSalmonPlatform@Orion. Unocal.com>, "Dolan, Jeff J" <dolanjj@Orion. Unocal.com> Great job, everyone. Randy, I am fine with leaving the well the way it is setup now (ie. 13 3/8" x 9 5/8" alarm set at 1000 psi) summarized below. As far as FDC (Field Data Capture program) is concerned please record the tbg, 9 5/8" and 13 3/8" casing pressures as the tubing, casing and surface pressures respectively, on all wells on your platform. I have made the changes to the guidelines on the web, which are located at http://kodiak, anchortown.unocal.com/da/using the pulldown "INFORMATIONIFACiLITYIlNJECTION GUIDELINES". Surface Hookup allowing us to start injecting up to 2900 psi. 1) Install an alarm on the 13 3/8" x 9 5/8" annulus, set to notify the operators if the pressure exceeds 1000 psi 1500 psi 2) Install an alarm on the Tubing x 9 5/8" annulus, set to notify the operators if the pressure exceeds 1500 psi 3) Connect the Manumatic Shut-down valve (SDV), which is installed just upstream of the injection choke, to activate if the Tubing x 9 5/8" annulus pressure reaches 1900 psi or if the Injection Line pressure exceeds 3200 psi (or what ever it is currently set to activate at). 4) Don't install a PSV or discharge line to the Tubing x 9 5/8" annulus, we believe the Automatic Shut-off is a safer solution due to the possibility of the discharge line causing other problems. We are now ready to run the MIT procedure, below. Please start the Pressure monitoring procedure when you have time. NOTICE: I made some minor modifications to step 3. MIT Procedure 1) Increase the injection pressure to 2900 psi or what ever pressure the Bingham Injection pumps will allow. 2) Monitor all annuli and injection pressures every 4 hours for the first day and once a day for the next 3 days. Log the readings in the attached spreadsheet. 3) After 4 days of monitoring, Change the tbg x 9 5/8" annulus pressure one time then monitor: the tubing and 1000 A) If the tbg x 9 5/8" annulus is below 700 psi, increase x 9 5/8" annulus pressure by 300 psi and monitor. B) If the tbg x 9 5/8" casing pressure is between 700 psi psi, reduce the pressure by 300 psi and monitor. 4) Monitor all annuli and injection pressures every hour for the first 12 hrs and once a day for the next 3 days. Log the readings in the attached 1 of 2 4/12/01 10:49 AM Change to K-15RD Surface Hookup. spreadsheet. 4) Send results to Chris Ruff in the Anchorage office. 5) Chris will review the results and present them to the AOGCC for review. <<MIT for K-15RD Feb 2000.xls>> Good Luck, Call me if there are any questions... Chris 907-263-7830 907-360-6162 cell DMITfor K-15RD Feb 2000.xls Name: MIT for K-15RD Feb 2000.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 2 of 2 4/12/01 10:49 AM K-15RD Pressure Monitoring for MIT !,' ,, ,, ,2/1'~,'~1 11':00 AM <= Enter Actu;I Start Date/Time ir~ this Cell' ' I~jecti0n ..... Pressures E~vent ..... Date/Tim~ ~f Reac~ir~gs Rate Tj3g , 9 5/8'~ Csg 13 3/8"'Csg 20'I ~sg' Started Injection at full pressure' ' 2/19/01 1'1:00 'AM ........ Monitoring every 4 hours 2/19/01 3:00 PM Monitoring every 4 hours 2/19101 7:00 PM Monitoring every 4 hours 2/19/01 11:00 PM Monitoring every 4 hours 2/20/01 3:00 AM Monitoring every 4 hours 2/20/01 7:00 AM Monitoring every 4 hours 2/20/01 11:00 AM Monitoring daily 02/21/01 Monitoring daily 02/22/01 .Monitoring daily 02/23/01 Reduce 9 $18" and 13 3,/8" csg press 200 psi. .." ~Z~/01"11:00 .~,M <= Enter Act'Ual D~te/Time 'of'PressUre change Here Ii i i I i i i i i i i I . i I ! I i Monitoring eVery hour ~ 1 ~1 :(~0' AI~I Monitoring every hour 2/23/01 12:00 PM Monitoring every hour 2/23/01 1:00 PM Monitoring every hour 2/23/01 2:00 PlY Monitoring every hour 2/23/01 3:00 PM Monitoring every hour 2/23/01 4:00 PM Monitoring every hour 2/23/01 5:00 PM! Monitoring every hour 2/23/01 6:00 PM Monitoring every hour 2/23/01 7:00 PM Monitoring every hour 2/23/01 8:00 PM Monitoring every hour 2/23/01 9:00 PM Monitoring every hour 2/23/01 10:00 PM Monitoring every hour 2/23/01 11:00 PM Monitoring daily 02/24/01 Monitoring daily 02/25/01 Monito, ring daily ........ 02/26/01 MIT for K-15RD Feb 2000 4/12/01 K-15RD MIT 10:49 AM (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATIONCOMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: X Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: RT 100' to MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, Alaska Service: X Trading Bay Unit '4. Location of well at surface King Leg 2 Conductor No.9 8. Well number 611' FSL, 121' FEL, Sec 17, T9N, R13W, SM K-15RD At top of productive interval 9. Permit number/approval number 2049' FNL, 110' FEL, Sec 21, T9N, R13W, SM 179-034 At effective depth 10. APl number 2526' FNL, 147' FWL, Sec 22, T9N, R1.3W, SM 50-733-20171-01 At total depth 11. Field/Pool 2577' FNL, 147' FWL, Sec 22, T9N, R13W, SM McArthur River Field/Hemlock/G "12. Present well condition summary Total depth: measured 12200' feet Plugs (measured) true vertical 9819' feet Effective depth: measured 12166' feet Junk (measured) true vertical 9801' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 384' 24" Driven 384' 384' Su trace 2401' 13-3/8" 1550 sx. 2401' 2293' Intermediate 10790' 9-5/8" 1000 sx. 10790' 8631' Production 1720' 7" (381b/ft) 382 sx. 10457-12177' 8374-981 O' Liner Perforation depth: measured See attachment .. true vertical Tubing (size, grade, and measured depth) 4-1/2" 12.6 Ib/ft Imp Butt L-80 at 33'-10372', 3-1/2" 9.3 Ib/ft L-80 Butt at 10372'-10600' Packers and SSSV (type and measured depth) Baker Model "F-I" packer set at 10,600'~1~'~,, ~,~:'~'~:~ ......... ~,~,~,,,h,.~, 13. Stimulation or cement squeeze summary Intervals treated (measured) F,~. B Treatment description including volumes used and final pressure Alaska ()il & Gas Cons. Cor:;mission Alqchot'8~l~t 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Water Injector 1436 BWPD 1660 psi 1660 psi Subsequent to operation Water Injector 4904 BWPD 300 psi 1800 psi 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: Suspended: Service: X (Water Injector) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ~/~/j~ ... Title: Drilling Manager Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ORIGINAL · UNOCAL ) RKB to TBG Head = 33.47' Han er connection: 4-112" EUE SIZE 13-3/8" 9-5/8" 7" Liner 3-1/2' scab Liner Tubing: 3-1/2" 4-1/2" {' Trading Bay Unit Well # K-15RD As Built (2-10-01) ........... DEX m ...... GRADE CONN ID TOP 61.0 47 38 9.2 BTM. 9.2 12.6 K-55 12.515 33' 2,401' N-80 & P-110 8.681 34' 10,790' P-110 6.184 10,457' 12,176' L-80 Butt (SPC) 2.992 11,579' 11,714' L-80 Butt (SPC) 2.992 10,372' 10,600' L-80 Imp Butt.(SPC 3.958 33.47' 10,372' 10,457' J0,790' NO. Devth _~ 1. 33.47' 3.958 2. 3. 10372' 2.992 4. 10600' 4.00 5. 10600' 4.00 6. 10649' 2.813 7. 10682' 2.992 Casing Scab 8. 11579' 9. 2.992 10. 11714' JEWELRY DETAIL Item FMC Tubing hanger,UH-TC-14, Type H BPV Profile 12" x 4-1/2" EUE Top x Bottom (x-over below hanger) 4-1/2" L-80 Imp Butt 12.6 lb/ft and 3-1/2" L-80 Butt 9.2 lb/ft Tubing x-over 4-I/2" Butt x 3-1/2" Butt Locator seal sub (4-3/16" OD) and 15 each seal sub 13.53' in length Baker Model "8340F-1 permanent packer with 11' SBE and ½ muleshoe "X" Profile Nipple WLEG Baker 7" 8340F-1 with 5' MOE 3-I/2" scab liner with locator and 5' seal stack Baker 7" 8340F-1 permanent packer w/bottom guide = G-1 =-- G-2 E_= G-3 .-'= G-4 == G-5 E-- G-6 B-2 10 B-3&4 _-~--., =-- B.-4 == B-7 COTD -- '12,175' TD -- 1~,250' MAX HOLE ANGLE = 45.25° @ 5400' PERFORATION DATA Zone Top Bottom Amount Details G-1 11070' 11100' 30' 4-$/8" 6spf (2-02-01) G-2 11120' 11180' 60' 4-5/8" 6spf (2-02-01) G-3 11220' 11240 20' 4-5/8" 6spf (2-02-01) G-4 11260' 11300' 40' 4-5/8" 6spf (2-02-01) G-5 11380' 11440' 60' 4-5/8" 6spf (2-02-01) G-6 11520' 11540' 20' 4-5/8" 6spf (2-02-01) HB-1 11596' 11630' 34' Isolated by scab HB-2 11660' 11702' 42' Isolated by scab HB-3 11764' 11840' 76' 3-3/8" 6spf (2-02-01) HB-4 11880' 11920' 40' 3-3/8" 6spf (2-02-01) HB-5 11940' 12030' 90' 3-3/8" 6spf (2-02-01) HB-6 12045' 12126' 81' 3-3/8" 6spf (2-02-01) HB-7 12146' 12160' 14' ' 3-3/8" 6spf(2-02-01) Fish: 7" bridge plug drilled up and pushed to bottom of well 10/89 Note: Pressure tested robing x 9-5/8" annulus to 1000 psi for 5 rain on 2-11-01. Pressure on 13-5/8" annulus built form 0 to 100.psi. 2 7 Alaska Oil & Gas Coas. Commission; Anchoca§e REVISED: 2/10/01 Perforation Record King K-15RD Zone Measured Depth TVD Comments G- 1 11070'- 11100' 8860'-8886' 3-5/8" 6spf TCP, (2-02-01) G-2 11120'-11180' 8903'-8955' 3-5/8" 6spf TCP, (2-02-01) G-3 11220'- 11240' 8989'-9006' 3-5/8" 6spf TCP, (2-02-01) G-4 11260'- 11300' 9023 '-9058' 3-5/8" 6spf TCP, (2-02-01) G-5 11380'-11440' 9127'-9178' 3-5/8" 6spf TCP, (2-02-01) G-6 11520'-11540' 9247'-9264' 3-5/8" 6spf TCP, (2-02-01) HB-1 11596'-11630' 9313'-9342' Isolated by 3-/12" scab liner HB-2 11660'-11702' 9368'-9403' Isolated by 3-/12" scab liner HB-3 11764'-11840' 9456'-9520' 4-5/8" 6spf TCP, (2-02-01) HB-4 11880'-11920' 9552'-9586' 4-5/8" 6spfTCP, (2-02-01) HB-5 11940'- 12030' 9602'-9677' 4-5/8" 6spf TCP, (2-02-01) HB-6 12045 '- 12126' 9689'-9757' 4-5/8" 6spf TCP, (2-02-01) HB-7 12146'-12160' 9773'-9785' 4-5/8" 6spfTCP, (2-02-01) I-IB-7 12161'-12166' 9786'-9790' 4-5/8" 6spf TCP, (2-02-01) Alaska Oil & Gas Cons. r' · o. Anchomge Workover Summary King K-15RD Water Injector Day 1 (1-23-01) Commence operations on King K-15Rd Workover at 12:00 hrs 23 January 2001. Installed BPV and removed tree. Commence NU of BOP's. Day 2 (1-24-01) Continue NU of BOP's. Function test BOP's and continue rig activation checklist. Day 3 (1-25-01) Test BOP's and choke line valves to 250 psi/3000 psi. Test choke manifold to 250 psi/ 5000 psi. RU hose to annulus and fill annulus with 25.4 bbls FIW. MU spear and stab tubing hanger. (Landing joint threads washed.) Day 4 (1-26-01) Pull hanger free and circulate 1-1/2 times tubing casing annulus. POOH laying down completion tubing. Day 5 (1-27-01) Continue laying down completion tubing. MU test plug and test lower ram cavity (VBR's) to 250 psi/5000 psi. Test plug rubber washed out. Redress and test annular to 250 psi/3500 psi. Rubbers on test plug washed again. Prepare to RIH with packer picker. Day 6 (1-28-01) RIH with packer picker. Trouble shoot problems with rotary torque gage and leaking swivel. Day 7 (1-29-01) Continue trouble shooting rotary torque gage problems. RIH with packer picker. Unable to enter liner top. POOH with packer picker. Day 8 (1-30-01) Determined 7" casing is 38 lb/ft not 291b/ft. Wait on correct packer mill. RIH with packer mill and mill on packer at 11456'. Day 9 (1-31-01) Mill on packer and pull free. POOH and lay down packer assembly. Make up clean out assembly and RIH to tag at 11811'. Circulate sand and "tar" like substance from well. Day 10 (2-01-01) Continue clean out to 12175'. Pump hi vis sweep and recovered sand to surface. Displace well to clean FIW. POOH with clean out assembly. Alaska 0il & Gas Cons. Commission Anchorage Day 11 (2-02-01) RU Schlumberger and run GR/CCL to 12162.5'. RD Schlumberger. PU Halliburton TCP guns and test tools an RIH. RU Schlumberger and space out guns. Fire guns perforating G and Hemlock zones. Unseat packer and reverse circulate. Day 12 (2-03-01) POOH and lay down TCP guns. Test BOP's. Left test plug 11-1/16" "ting" in wellhead. Day 13 (2-04-01) RIH and set storm packer at 40'. ND BOP's and recover test plug "ting". NU BOP stack and complete BOP test. Day 14 (2-05-01) Recover storm packer. Make up cleanout BHA and RIH to ETD at 12175'. Circulate well clean and POOH. Day 15 (2-06-01) Continue POOH. RU Schlumberger and RIH with FB-1 packer. Unable to pass 10778'. (Casing tight - dog leg). POOH and RD Schlumberger. Make up hydraulic packer setting and RIH with FB-1 packer on drillpipe. Set packer and POOH with setting tool. Day 16 (2-07-01) Continue POOH with setting tool. Make up top scab assembly on drillpipe and RIH. Stab into lower packer and set upper F-1 packer at 11579' elm. POOH laying down drillpipe. Day 17 (2-08-01) Continue laying down drillpipe. RU Schlumberger and RIH and set top production packer (F-I) at 10,600' elm. Pull wear bushing and install 4-1/2" pipe rams and test. RIH with 4-1/2" x 3-1/2" injection string. Day 18 (2-09-01) Continue RIH with completion string. Stab into packer at 10600' and pressure test annulus to 1000 psi- good test. Space out and displace well to 3%KCL + 1% CRW-132 corrosion inhibitor. Day 19 (2-10-01) Land out hanger and install BPV. Pressure test annulus to 1000 psi for 5 minutes- good test. ND BOP's and NU and test tree to 5000 psi. Rig released at 18:00 hfs 10 February 2001. ,Alaska Oil 8~ Gas Cons. Comrr]issbn Anchorage RE: Startup Injecting on K-15RD Subject: Date: From: To: CC: RE: Startup Injecting on K-15RD Thu, 15 Feb 2001 13:23:20 -0800 "Ruff, Christopher A" <ruffc@unocal.com> "McGahan, Greg" <mcgahag@Orion. Unocal.com> "'Tom Maunder'" <tom_maunder@admin.state.ak.us>, "Johnson, Dwight E" <johnsond@Orion. Unocal.com>, "Atkins, Mark C" <atkinmc@Orion. Unocal.com>, "Waski, John" <waskij@Orion. Unocal.corn>, "McMahill, Randy" <mcmahir@Orion.Unocai.com>, GRP AK CI OO&E Team <GRPAKCIOO&ETeam@Orion. Unocal.com> One change to Step 3 of the surface hookup .... Change the 2000 psi to 1900 psi. :> :> ;> :> :> ;> :> ;> :> :> :> ..... Original Message ..... From: Ruff, Christopher A Sent: Thursday, February 15, 2001 12:07 PM To: McGahan, Greg Cc: 'Tom Maunder'; Johnson, Dwight E; Atkins, Mark C; Waski, John; McMahili, Randy; GRP AK CI OO&E Team Subject: Startup Injecting on K-15RD Greg, ! just got off the phone with Mark and I am sending this email to document the discussions with everyone this morning. The plan is to bring the well on today at 1900 psi with the same monitoring that was done before the workover. Once the well has the Suface Hookup (as outlined below) we will increase the injection pressure and run the MIT Procedure (outlined below), i modified my original plan to reflect the above and here it is... Surface Hookup (required before injection can be increased above 1900 psi) 1) Install an alarm on the 13 3/8" x 9 5/8" annulus, set to notify the operators if the pressure exceeds 1500 psi 2) Instal/an alarm on the Tubing x 9 5/8" annulus, set to notify the operators if the pressure exceeds 1500 psi 3) Connect the Manumatic Shut. down Valve (SDV), which is installed just upstream of the injection choke, to activate if the Tubing x 9 5/8" annulus pressure reaches 1900 psi 2000 psi or if the Injection Line pressure exceeds 3200 psi (or what ever it is currently set to activate at). 4) Don't install a PSV or discharge line to the Tubing x 9 5/8" annulus, we believe the Automatic Shut-off is a safer solution due to the possibility of the discharge line causing other problems. Start-up procedure (limited to 1900 psi with same monitoring procedure as before the workover) 1) With the well shut-in. Bleed off or pressure up the 13 3/8"x 9 5/8" annulus and the Tubing x 9 5/8" annulus as needed to set the pressures to 700 psi. 2) Begin injection and take the injection pressure up to 1900 psi. 3) If the 9 5/8" casing pressure rises and continues to rise, call Chris Ruff at 907-360-6162. Minor fluctuations in the casing pressure may occur due to temperture and tubing movements, this is OK. 1 of 2 4/12/01 10:54 AM RE: Startup Injecting on K-15RD · :> · ;> · :> · · · · · · · · · · · · · :> · · ;> · · · · · · · MIT Procedure (After all the above mentioned Surface Hookup is completed) 1) Increase the injection pressure to 2900 psi or what ever pressure the Bingham Injection pumps will a/Iow. 2) Monitor all annuli and injection pressures every 4 hours for the first day and once a day for the next 3 days. Log the readings in the attached spreadsheet. 3) After 4 days of monitoring, reduce the annuli pressures to 500 psi. 4) Monitor all annuli and injection pressures every hour for the first 12 hrs and once a day for the next 3 days. Log the readings in the attached spreadsheet. 4) Send results to Chris Ruff in the Anchorage office. 5) Chris will review the results and present them .to the AOGCC for review. << File: MIT for K-15RD Feb 2000.xls >> Thanks, Chris Ruff Reservoir Engineer OO&E Team 907-263-7830 (office) 907-360.6162 (cell) 907-337.3682 (home) .... Original Message ..... From: Tom Maunder [mai/to:tom maunderC~_,admin, state, ak. us! Sent: Thursday, February 15, 2001 11:03 AM To: Chris Ruff Subject: Startup Injecting on K. 15RD2 Chris, This note confirms our discussion to bring the well on in compliance with the original sundry, with a maximum surface pressure of 1900 psi. I understand your manpower crunch with everything happening out there. Once all the equipment hookups are completed (in about a week), you will plan to increase the injection pressure to about 2800 psi and begin the MIT process at the higher pressure. Good luck with the start up. Tom Maunder, PE AOGCC << File: Card for Tom Maunder >> 2 of 2 4/12/01 10:54 AM o J Monthly Injection Report WATERFLOOD INJECTOR MOI%~HLY REPORT KIN~ SALMON PLATFORM :TBU K-15: 5073320 i.[i -- i i i i~ i i i t i i l_ i Well Dale H'rs Volumt Tbg 13.37S Csg 24 Csg On lnieeted Press P rfls Prt~s i i £ i )1 i mU K-I'5 171~01 24' ~039 !(~0 16~) 7Bu~.15 " ~moi 14.5 '~76 , ~ " ioo ~o~ ' .. ,,. TBU K-t5 t/3/OI 9,5 394 1330 1350 lOS ..... b ' 'h ...... ~U K-15 1[41 I 8 05 0 0 105 ~D K-15 1t5101 . . 8 . 748 . 1~0 .. 1640_.,. ~UK.15' t/T/OJ 2~ ~ 17~g " I630'~ ' 1680 JO5 ~H~-15 1/~01 24 1701 1600 1620 ., ,,... .., ~ i T~U K-l~ " ~/9/0~ ~ t64~ ~62o 164o ~U~-IS 1/10/Ol ~ ' 1715 1620 'la0 t02 Illl _ . il ~1 I t~UK-I~ i/1 i/01 ~ 1766 1640 i~ 102 TBU K-I 5 1/1~01 24 1736 1660 1670 = " [ n[ f i ns , TBU K-tS ltt3/01 24 i709 1640 1660 ,~UK-I$ ' Itl~O~ - 24 ~' 1673 ]~ ' 16i0 ,, t_ _ i i, [ ~ i r - ~U K-15 ffl~/01 24 I6,$ 1680 1670 10S ..... it ~ r i i i i · i ~U K-15 l/l~0l ~ 1717 1660 1670 105 il I / , 11 I I I r ~ - ' ~ K-I ~ 1/17/01 ~ M3 166¢ 1670 10~ lull , il II I i I ~TBU K-15 111~01 ~ 0 0 0 95 [~U K-15 1/D/0ff 24 810 1640 l~O 95 ~UK.15 " I/2fi0'[ ~ ' 1952 '1660 1650 95 ii i _il I f mill ~ K-15 ' lal/01 ~ 547 166~ qfiS0 '' -. i i i j i i ,~UK-t5 I~01 ~ 0 0 0 95 I I I . - i II I I ~UK-15 I~]t01 24 ~ 0 0 m I I ~ mi ~l I I I I Ill I II I I http ://ko diak.anohorto wn, ~'1o c~ l. ~f)i-ii/S ll~ voilbnce/lnjeotor_V arianeeRopon.asp Page I of 2 RECEIVED FL.9 0 1 2001 Alaska Oil & Cas Cons. Commission 2/1/0! r I81 ~11~ Page 2 of 2 RECEIVED ~'3S 0; 2001 Oil & Ga~ Com. Comnli~ak~ o http : //kod iak, andtorto wn, uno oal. com/S urvcOlanee/I ffjeet or_VarianeeR cpo rt. nsp 211/0t King Salmon K-15RD2 Workover ,~' Subject: King Salmon K-15RD2 Workover Date: Ffi, 19 Jan 2001 17:48:38 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Chris Ruff <ruffc@unocal.com>, Dan Williamson <williamsond@orion.unocal.com>, Tim Billingslea <billita@unocal,com> CC: Julie Heusser <julie_heusser@admin.state.ak. us> Chris, This note confirms our discussion at about 1730 regarding approval to proceed with the workover as outlined in your note to me dated January 9. While it would be preferable to have the work return the well to a condition that would allow passing the normal MIT, we recognize the economic implications and potential futility of that quest. Your work should result in the well having tubing and packer integrity. Given that you plan to increase the surface injection pressure, in addition to the in place pressure and rate monitoring, it will be necessary to provide some "relief valve" protection for the IA and potentially the OA of the well. We can discuss this matter next week. Good luck on the workover. Tom Maunder Petroleum Engineer AOGCC Tom Maunder <tom maunder@admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 4/12/01 10:47 AM ,,, STATE OF ALASKA ALASKA d,,_ AND GAS CONSERVATION L ..)MMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: X Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: PeRorate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of Califonia (UNOCAL) Development: RT 100' above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Trading Bay Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: X 4. Location of well at surface King Leg 2, Conductor 9 8. Well number 611' FSL, 121' FEL, Sec 17, T9N, R13W, S.M. 44-.1,2.E~ ~.~ ~S ~'~'~")~T'~--- ~'/'/"/ \ At top of productive interval 9. Permit numberI''~ 2283' FNL, 4' FWL, Sec 22, T9N, R13W S.M. '51~=-7-3~-2'0~7..1~ ~r"~l~-- O-Z¢~. At effective depth 10. APl number 2526' FNL, 125' FWL, Sec 22, T9N, R13W, S.M. 50-733-2e.14~'~ ~(~\t~, _ At total depth 11. Field/Pool 2577' FNL, 147' FWL, Sec 22, T9N, R13W S.M. McArthur River Field/Hemlock 12. Present well condition summary Total depth: measured 12200' feet Plugs (measured) true vertical 9819' feet 0(~.i.,. Effective depth: measured 12166' feet Junk (measured) , , true vertical 9801 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 384' 24" Driven 384' 384' S uRace 2301' 13-3/8" 1550 sx. 2401' 2293' Intermediate Production 10790' 9-5/8" 1000 sx 10790' 8631' Liner 1720' 7" 382 sx 10457-12177' 8374-9810' PeRoration depth: measured (See attachment) true vertical ORIGINAL Tubing (size, grade, and measured depth) 3-1/2" 9.2 Ib/ft L-80 at 10080' - 11496', 4-1/2" 12.6 Ib/ft L-80 at 34' - 10080' Packers and SSSV (type and measured depth) Baker FB-J at 11451', Camco TRDP-1 TRSSSV at 295' 13. Attachments Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 11/15~2000 16, If proposal well verbally approved:' Oil: Gas: Suspended: Name of approver Date approved Service: X (water injector) 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: (~~_,~ ~ Title: Drilling Manager Date:/t~ -'/¢"' ~) ' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so repres~e~tative may witness IAppro~a~N~. /,,,.,'/ Plug integrity BOP Test ~ Location clearancei ,j/~/u Mechanical Integrity Test N~. Subsequent form required 10- ~'"~t.~-~- ORIGINAL SIGNED BY D Seamount Approved by order of the Commissioner Commissioner Date//~") Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Unocal Corporation 909 W. 9th Avenue Anchorage, AK 99501 907-263-7660 UNOCAL( Dan Williamson Drilling Manager October 16, 2000 Mr. Dan Seamount Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Ak 99501-3192 Re: Workover of King K-15RD Dear Mr. Seamount: Unocal plans on working over the King K-15RD well in mid November 2000. The well is currently a Hemlock injector. The well appears to have tubing/annulus communication as well as potential 9-5/8"/13-3/8" communication which is thought to be wellhead related. The objective of the workover is to restore the mechanical integrity of the well and add G zone perforations for water injection. Please contact the undersigned with any questions regarding this application. Sincerely, Dan Williamson Drilling Manager enclosure King K-15RD Perforation Interval (Current 10-16-00) Interval (MD) Interval (TVD) Status Formation 11596-11630' 9322-9351' Open for Production HB-1 11660-11700' 9377-9411' Open for Production HB-2 11764-11840' 9465-9530' Open for Production HB-3 11880-11920' 9563-9597' Open for Production HB-3/4 11940-12030' 9613-9688' Open for Production HB-5 12066-12126' 9718-9768' Open for Production HB-6 12146-12166' 9784-9801' Open for Production HB-7 UNOCAL RKB to TBG Head = 33.80' Tree connection: 10,457' 10,790' Trading Bay Unit Well # K-15RD Last Workover 10/24/89 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 9-5/8" 7" Liner 61.0 K-55 12.515 33' 2,401' 47 N-80 & P-110 8.681 34' 10,790' 29 P-110 6.184 10,457' 12,176' 12.6 L-80 LOCK-IT 3.953 35.1 9.2 L-80 LOCK-IT 2.992 10,081' JEWELRY DETAIL NO. Depth Il) Item Tubing: 4-1/2" 3-1/2" 33.8 1. 295' 3.813 2. 10,080 2.992 3. 11,450 2.984 4. 11,450 4.00 5. 11,453 4.00 6. 11,469 5.40 7. 11,484' 2.75 8. 11,495' 3.00 btm 11,496' 10,080' 11,450' FMC Tubing hanger, 4-1/2" 4-1/2" Camco TRDP-1A SSSV Crossover, 4-1/2" x 3-1/2" Locator Seal Assy w/9' of seals Baker Model "FB-1" Perm Pkr, size 85-40 Seal Bore Extension, 15' MOE Camco "D" Profile Nipple, 2.813 Baker 3.5" Shear-out Sub 11,450.9' WIRELINE PROBLEMS Made 53 bailer runs 2/16/00 to 2/23/00. Unable to bail below 12,074' WLM 12,074' WLM B-1 B-2 B-3 B-3&4 B-4 B-5 Zone HB-1 HB-2 HB-3 HB-3&4 HB-4 HB-4 HB-5 HB-6 HB-7 Top 11,596' 11,660' 11764' 11774' 11836' 11880' 11940' 12 066' 12 146' PERFORATION DATA Btm Amount 11,630' 34 11,702' 42 11,774' 10 11,836' 62 11,840' 4 11,920' 40 12,030' 90 12,126' 60 12,166' 20 Condition Open Open Open Open Open Open Open Partially Isolated by Fill Isolated by Fill B-6 B-7 PBTD = 12,170' TD = 12,250' MAX HOLE ANGLE = 45.250 @ 5400' K- 15rd dwg current STL 10-24-89.doc REVISED: 9/26/00 DRAWN BY: SLT UNOCAL( RKB to TBG Head = 33.80' Tree connection: 2,401 Trading Bay Unit ,. Well # K-15RD PROPOSED CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61.0 K-55 12.515 33' 2,401' 9-5/8" 47 N-80 & P-110 8.681 34' 10,790' 7" Liner 29 P-110 6.184 10,457' 12,176' 5-1/2" Scab 17 Butt 11,550' 11,730' Liner Tubing: 4-1/2" 12.6 L-80 Imp Butt.(SPC 3.958 35.1 10,800' 10,457' 10,790' JEWELRY DETAIL NO. Depth ID Item 33.8 1o 2. 4.00 3. 5.40 4. 3.813 5. 3.00 Casing Scab 6. 7. 8. FMC Tubing hanger, 4-1/2" Baker Anchor w/ nitrile seals Baker Model "84SAB40" hydraulic set packer 5' MOE Otis "X" Profile Nipple WLEG Baker 7" ZXP with hydraulic holdowns 4-1/2"/5-1/2" scab liner Baker FB-2 permanent packer with 1' nitrile seals :: G-1 ---- G-2 _=_= G-3 _:_= G-4 _==- G-5 ---- G-6 B-1 B-2 6 8 =-_-- ----- B-5 ~ 5-6 ---- B-7 PBTD = 12,170' TD = 12,250' MAX HOLE ANGLE = 45.25° @ 5400' B-3 B-3&4 B-4 Zone G-1 G-2 G-3 G-4 G-5 G-6 HB-1 HB-2 HB-3 HB-3&4 HB-4 HB-4 HB-5 HB-6 HB-7 Top 11 070' 11 120' 11 220' 11 260' 11 380' 11 520' 11 596' 11 660' 11 764' 11 774' 11 836' 11 880' 11,940' 12,066' 12,146' PERFORATION DATA Btm 11100' 11 180' 11 240' 11 300' 11 440' 11 540' 11 630' 11 702' 11 774' 11 836' 11 840' 11 920' 12 030' 12 126' 12 166' Amount Condition 30 Proposed Peds 60 Proposed Peffs 20 Proposed Per~ 40 Proposed Per~ 60 Proposed Pe~s 20 Proposed Per~ 34 Isolated by Scab 42 Isolated by Scab 10 Open 62 Open 4 Open 40 Open 90 Open 60 Open 20 Open REVISED: 10/16/00 ORIG. BY: SLT Procedure Summary K-15RD Workover 1 Rig up on well 2 Check for tubing pressure and set BPV. 3 N/U and test 13-5/8" 5K BOP's 4 P/U landing joints and screw into hangar top. 5 Attempt to pull tubing/seal assembly loose from packer 11,451 6 Pull string loose and circulate well to FIW. 7 POOH laying down tubing 8 RIH with packer mill to mill over packer at 11451. 9 Mill over packer 22"+/- Circulate hole clean. 10 POOH with packer milling assembly and packer. 11 RIH with bit and scraper. Clean out well to ETD at 12,170' 12 Circulate hole clean and pump hi-vis pill. 13 POOH with scraper assembly. 14 Make up and RIH with RTTS and hang off below wellhead. 15 Pressure test pack-off and replace as necessary 16 Continue RIH and test casing integrity. 17 Test casing and recover RTTS assembly 18 Make up 7" permanent packer and set on e-line to cover HB- 1 &2 19 Make up 5-1/2" scab liner assembly 250' on permanent packer and RIH 20 Anchor into packer set packer and POOH 21 Repair possible casing leak with scab assembly. 22 MU TCP guns 600' and RIH with test assembly 23 Fire guns, perforate G and HB, circulate well clean 24 POOH and lay down TCP assembly 25 Run 4-1/2" x 3-/12" completion tubing with anchor seal assy. 26 Displace well to inhibited packer fluid. 27 Space out set packer 28 Run BPV and N/D BOP's 29 N/U tree and test to 5000 psi 30 Turn well over to injection K-15RD BOP Stack Top of Rota~ Table 13 5;8" Hydril 4.54' ,,, · 2.05" Btm of Trolly beam 3 x 4 1116"5M DSA 4.75' Top of drill deck A 4 t/16" 5M Foster HCR Valve B 41/16" 5M Manual gatevalve C 3 1116" 5M Manual gate Kill line D 3 1116" 5M Manual gate Kill line 6.00' 12.83' Page I of 2 TBUK_I5 --- ~ ~Sep~em~e;i ~ ~ Monthly Injection Report <2> WATERFLOOD INJECTOR MONTHLY REPORT lONG 8ALMON PLATFORM: TBU K-15: 50733201710t801 Hfs VMm~e Tbg 13.37~ C~g 24 Csg W~ll Date O~ Injected ~ ~ss ~BU K~i5 9~60 ~ 1718 "'15~ "' 15riO " 110 ~U K-15 ..... 9m00 24 2fl~ 17~ i~30 ' iI 1 ~U K-15 91~0 ~ 2084 1700 1740 111 ...... ,. ~,.., ~U~-15 9t5~0 24 ~83 1~0 17~ 110 ~UK'IS " 9/6[00 ~ ~f19 1~0 1~ 112 ~UZ15 '" ~7~0 '~4 190 16~ '" i7~ ' -' ...... -- ~U K-I~ 918~0 g i ~ 14~ 1520 .......... ~U ~-15 919~ ~ 18~ 16~ 1~0 111 .. .......... ~U K-I5 911~0 ~ i 845 16~ 1~0 111 . ..... ~U g:i5 " 91~2~0 ~ ~9 16~ ~6~0 112 . . . ........ ~U~-15 9~3~0 ~ ~4 16~ 1640 1 ,, ~U ~-15 9~00 24 1~2 l~O 1630 112 ~_. ~u~-ts 9fl~ 24 i7~ ~580 ~6~ H2 ............. ,, ~ ~-15 9/l~ffi ~ 1737 1580 1~0 113 , ~ mb ~-15 " ~/17/00 "~ 17~ 15~ 161o al3 .... ~U K-15 911~0 24 1752 15~ 1610 ~U'k215 9~0 ~ 1767 " t5~ '" 1660 112 ~OK-15 ......... 9arno " ~ 1~0 IS~ I "' 1600 112 ..... ~UK-15 9122tfl0 24 1286 1540 15~ [ 114 ....... .............. ~U K-15 9i~ ~ 1703 1420 M~ 112 . . ...... mU K-iff 9125/~ ~ ~29 t610 I~ 113 i http://kodiak,ar~t~rtown.anocal,com/Sut~illame/IOjecto r_VafianceR~ofl,~ t 0/1/00 .- _ Page 2 of 2 .. .. IIIU K2iS " 9/2//00 24 171'5 "' 1520 t560 113 TBUK-lS ' ' ' 9/30/00 ~.. . 1802 1600 16:20 ..... J,.113 htlp ://kodlak. anchorto yin.unocal, c om/Surve~T~.ce/lnj e c~o r_Var~ceReport,asp 10t 1/00 RE: K-15RD (PTD 79-034) Variance- ...tension ,,nt il Workover in November Subject: RE: K-15RD (PTD 79-034) Variance - Request for time extension unt il V~brkover in November Date: Wed, 2 Aug 2000 14:20:27 -0700 From: "Ruff, Christopher A" <ruffc@unocal.com> To: '"Tom Maunder'" <tom_maunder@admin.state.ak. us> Thanks Tom. ..... Original Message ..... From: Tom Maunder [mailto:tom maunder@admin.state.ak, us] Sent: Wednesday, August 02, 2000 12:49 PM To: Ruff, Christopher A Subject: Re: K-15RD (PTD 79-034) Variance - Request for time extension until Workover in November Chris, . Thanks for the quick reply. You are correct that the injection performance has decreased, however the pressure information indicates that you are continuing to operate the well within the 13-3/8" pressure limit. You have approval to continue injecting per the requirements of the May 21, 1999 approval. We are encouraged that the well has a place on your repair list. I have further checked the file information we have regarding the expiration date. It appears that there may have been a date error in a few locations. You clearly applied for a 2 year term and our internal note reoommends a 2 year approval, but the dating came up one year short. If you have any questions, please get back to me. Tom Maunder "Ruff, Christopher A" wrote: > Tom, > As we spoke of on the phone, the wells poor injection rate at the limited > '1900 psi, the recently redrilled M-32 well and the price of oil has > convinced me that this well should be worked over, therefore I am requesting > an extension of the variance on K-'15RD in order to continue injection until > the well is worked over. The workover is currently scheduled for this > winter. After the vvorkover we should be able to run a standard MIT and >retum this well to normal injection pressures. > > I am attaching the rates and pressures since the well was brought back > online. 1 of 2 8/2/00 1:48 PM RE: K-15RD (PTD 79-034) Variance - ...tensio~' "t il Workover in November > <<Injection History. xls>> > As you can see from the two charts and the data, the well isn't taking much > water and there is no indication that the injection water is going anywhere > except the perforated intervals. Please grant this extension. I well let you know if there are any major changes to our workover plan. Chris > Narre: Injection History. xls > Injection History. xls Type: Microsoft Excel Worksheet (application/vnd. ms-e xcel) > En©ding: base64 2 of 2 8/2/00 1:48 PM K-15RD Injection History 35O0 3OOO 2500 2000 1500 1000 500 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 Injection Rate 8~2/00 \~k-Anchorage\Groups\OOE\OOEFields\Tbu\King\Wells\K~15\K-15RDInj\Well History\Injection History.xls 12:49 PM i --e-- Rate Tbg Pressure 13/3/8" Csg Press. 8/28/99 10/17~99 12~6~99 1125100 3/I 5~00 5~4~00 6~23~00 8/12~00 10/1/00 METER BARRELS HRS TUB]NG 9 6t8 READING INJECTED IN~ PRES8 PRESS PRF.~ ,.., - o 0 ' 9 0 0 '350 ,- o 0 o o -' 340 0 ,. o o o 5 s~' o __ o o 5 o ~o o 0 o o o 330 , -- 0 0 0 0 34o .. o 0 0 o 340 o ,, .. 0 0 O 0 340 O , o 00 0 o 330 o 0 0 o 0 330 o . , o 0 0 o 340 - ,. 0 0 o o 340 o o o o 5 s40 o o o o o' ~40 ' o -- 0 o o o 340 0 O 0 o o 340 o 0 0 0 0 341} 0 . . o 0 o o 340 o o o 0 5 s~ o 0 o o o 840 o o o e o ' ,~6o "b o O o 0 350 0 0 0 0 o 34O 0 o o o -o 34b o o o o 0 340 o , , o o 0 o 340 o ... o 0 0 00 34o O' o 0 0 o 340 o .,, o o o 0 35o 0 o o o '5 s~ o o ' o o' 6 sro' o ,__ TOTAL METER BARREL8 ' I~R8 TUBI~IG' 9 ~8 13 READ]X6 II~IECTED JNJ PRESS PRESS PRESS 1607 "i597 ~' ' '1S2o 16~0 SS43 1646 ' 24 ''' t,610 ' q~O '~490 ' 4~3 1590 23 1500 1520 14.80 653I t598 23 9496 I~10 t470" 8072 " 1541 ~q,6 'i'400 1.~)0' 1450 97-'1 t 1e39 24 14~ 1460 1420 113'~6' 1604 ~ 24" ' 1450 14Bo 1430 .. · 12917 1602 24 1460 '1490 1440 14444 1627 24 t450 1490 1430 1606t t 617 24 1454~ t 490 1420 176~0,. "~ 6.TO ~'4 14,50 " t4,90 19279 1639 24 t~DO 1620 1460 20446 1167 17.26 1600 1620 1460 21764 ~... 1308 20.25 1540 1,'~..0. 1540 237oe tg,~4 24 1590 1620 1570 , ., , . 25918 1040 24 16~ 1620 16700 27533 1916 24 1600 1620 1~4~0 2e4~6 ' 1893 206 t6~30 '!620 '~,'~0 ii i 31249 1823 24 1600 1630 1.680 ' ' 33104 1666 24 1590 le;~0 1665 ' 3484o 1.1'36 ' ~.. 1600 t635 1690 36734 1694 24 t6~0 1~0 15/'3 $eEq~" 11'8; 24 ,1600 '1640 1~2 40160 1634 24 t450 1490 1430 ' ' 41760 1610 24 1'470 1,50,0 1478 - 43442 t682 ' 24 15~0 '~520" 1620 . , , , ,4~206 1764 24 15.80 t~30 1530 4698~ ;l"J'76 24 1540 'J63~ ~ `1530 - . ,... · 46466 t604 t9,2,6 1590 1620 '1660 .. .. _~ · ., 60413 1927 24 1,~50 1600 1640 52234 1821 24 '[540 1580 1520 . TOTAL 62234 DATE 04/30/00 05/O f /O0 05/02/00 05/03/00 05/04/00 05/05/00 05/06/00 05/07/00 05/08/00 05/09/00 05/10/00 05/f f/O0 05/12/00 05/13/00 05/f4/00 05/f 5/00 05/16/00 05/17/00 05/18/00 05/19/00 05/20/00 05/2f/00 05/22/00 05/23/00 05/24/00 05/25/00 05/26/00 05/27/00 05/28/00 05/29/00 05/30/00 05/31/00 K-11 I METER BARRELS HRS TUBING 9 5/8 13 3/8 READING INJECTED INJ PRESS PRESS PRESS 0 0 0 0 0 0 0 0 0 0 161 0 0 0 0 0 162 0 0 0 0 0 165 0 0 0 0 0 168 0 0 0 0 0 169 0 0 0 0 0 171 0 0 0 0 0 175 0 0 0 0 0 200 0 0 0 0 0 200 0 0 0 0 0 210 0 0 0 0 0 200 0 0 0 0 0 210 0 0 0 0 0 210 0 0 0 0 0 220 0 0 0 0 0 190 0 0 0 0 0 192 0 0 0 0 0 195 0 0 0 O 0 197 0 0 0 0 0 199 0 0 0 0 0 199 0 0 0 0 0 204 0 0 0 0 0 220 0 0 0 0 0 22O 0 0 0 0 0 220 0 0 0 0 0 220 0 0 0 0 0 220 0 0 0 0 0 220 0 0 0 0 0 22O 0 0 0 0 0 215 0 0 0 0 0 217 0 DATE 04/30/00 05/01/00 05/02/00 05/03/00 05/04/00 05/05/00 05/06/00 05/07/00 05/08/00 05/09/00 05/10/00 05/11/00 05/12/00 05/13/00 05/14/00 05/15/00 05/16/00 05/17/00 05/18/00 05/19/00 05/20/00 05/2 f /oo 05/22/00 05/23/00 05/24/00 05/25/00 05/26/00 05/27/00 05/28/00 05/29/00 05/30/00 05/31/00 K-15 J METER BARRELS HIS TUBING 9 5/8 13 3/8 READING INJECTED INJ PRESS PRESS PRESS 0 0 2055 2055 24 1670 1670 1650 4036 1981 24 1660 1730 1678 5969 1933 24 1650 1720 1677 7873 1904 24 1650 1710 1666 9726 1853 24 1630 1690 1651 11374 1648 19 1640 1700 1679 13229 1855 22 1640 1640 1621 15207 1978 24 1600 1550 1631 17134 1927 24 1600 1660 1580 18976 1842 24 1610 1660 1580 20323 1347 17 1550 1590 1530 21982 1659 20 1625 1670 1600 23709 1727 23.25 1420 1460 1400 25493 1784 24 1590 1640 1580 27248 1755 24 1600 1640 1570 29010 1762 24 1610 1670 1647 30747 1737 24 1610 1670 1648 32436 1689 24 1620 1670 1650 34138 1702 24 1620 1680 1658 35582 1444 18.75 1700 1740 1711 37565 1983 24 1650 1720 1703 39409 1844 24 1670 1720 1698 41284 1875 24 1670 1720 1650 43075 1791 24 1670 1720 1650 44796 1721 24 1660 1720 1640 46530 1734 24 1660 1720 1640 48312 1782 24 1660 1720 1640 50097 1785 24 1660 1720 1640 51893 1796 24 1660 1720 1640 53674 1781 24 1680 1735 1716 55446 1772 24 1680 1750 1728 TOTAL = 0 TOTAL 55446 g DATE 12/~f/99 0~/~ 0~/~ ~/~ O ~/~ ~/~ 0~/~ 0I/~/~ Ol/3f/~ · METER B~RRJJLS '" HRS TUBING 9 ~r8 t$ 3i~ READI~Ie [f4JECTED INJ PRESS PRESS PRESS 0 '-4~o~1 ;;031" 24 280~ - i40 o ., 26376 13345 24 2800 140 0 39713 13337 24 2800 150 O . , _ , 52909 13196 24 28OO 150 0 .... , 66164 t3245 24 2eoo 160 72144 5860 14 2800 t60 O ' 8-'~54 136~0 24 ;6~0 160 0 .. . 99430, 13416 24 '2600 160 0 .... ~i~o9 .. t3t79 ,' 24 28o~, .16o e , '~26764 t3tr~ . 24 _28oo 'T60 t389~1 t3'~37 24 2800 1-'5~ O t 52023~ .... 13122 24 ' 2800 t63 0 ._ 165255 13232 24 2800 165 0 178416 13160 '-' 24 2800 161 0 ~98020 9805 16 28~0 310 0 ., ,, ,.. 188020 0 0 0 ,. 820 .. t~020 0 O 0 ~ 0 ,, ,. t-88020 0 D ' 0 IO89 0 --, '188020 0 0 0 t150 0 --, 188020 0 0 0 'J 200 0 . . 169020 0 0 0 ~240 0 --18~020 (~ 0 0 12~0 0 .. ., · ~e,6020 0 D 0 1300 0 ,16802o 0 0 0 1330 0 , 188020 0 0 O 4330 0 · 188020 0 0 0 ~38D 0 18.9020 0 0 0 't330 0 ,. ~11~020 O 0 0 1350 ~e~ao _. o .. o o ~5~ 108020 o o 0 135o o TOTAl- = "/88026 METER BAR ~,',.$ HRS TUBII~ 9 6~[~ 23~ 2396,' ~ t6~ ,. t660 4~80 4800., " 24~ 24 ~6~ t740 7062 2~2 24 ~6~ 16~ 1630 41229 2~t ~ t520 1620 .... ~2052 e~ tl ~520 1520 ~580 ~4269 2207 ~ 15~ I ~0 1620 ....... 1633? ~78 24 1~0 ~610 t~0 , , 18429 2092 24 t6.20 1680 16~ 20~ 2211 24 t 6t0 1670 ~ 600 22~2 222~ 24 4~10 t~0 I622 2~B 2t76 24 16~ ;~0 t652 ., . . 27191 2~53 [ 2~, 1640 ~7~ 1~7 28468 2297[ 24 1660 t7~ 169~ 34894 2396 ] 23.75 1~0 t740 34332 ~8 24 t~0 ...... ~720 --' 36~1' 2~ ~ 46~ t~ t680 -. ,, _ 38542 1961 24 166D 1~0 ... 40391 t~9 24 1~0 46~ 1'5~ ...... 42142 4?64 24 t~0 1610 4~., - t7t4, 24 1~ 1600 - 46912 1467 t6.6 15~ 1~0 1470 40913 J 190~ ' 24 ~610 16~ ~738 4926 24 1640 f7~ 52669 I93t 24 16~ 1740 1639 54~0 1~91 24 ' 16~ '1720 '* ~649 , ,, , . 5~ 1~3 ~ 16~ 1700 1600 ~780 44~7 24 ~410 1~0 t460 ~468 t388 24 4390 13~ ~ , ~ · 60630 4362 24 t400 t400 ,. TOTAL 00~30 May 19, ]999~c]O:O]AMi.co UNOCAL CORP, Post Office 9o~' '360 Telephone 907 276 1215 CoQk Inlet' F. nglneerlng N0,5977 July 30, 1992 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, Alaska 99501 Re: K- 15rd Mechanical Integrity Test Information. Dear M.r, Wondzelh Attached are copies of the Daily Workover Reports from October 4 and 24, 1989 for K- 15rd well on the King Salmon Platform. Highlighted in these reports are two citations of tests which verify the mechanical integrity of the well at that time, just prior to commencement of water injection. The report from OcWber 4 is a casing only test/n which the production casing was tested to 2,500 psi with a pressure loss of only 40 psi (2%) in 30 minutes. This test was performed prior to running the completion. On October 24 the test was performed after the final completion was run and in place. This test was held for 15 minutes with no reported loss of pressure. As you know, we are planning to perform an official mechanical Integrity test to be witnessed by one of your Inspectors. It is ARCO's intention to do this test in conjunction with the upcoming 'No-Flow' testing. This will most likely take place in early August, If you have any questions please do not hesitate to call me at 263-4107. Sincerely, Sr. Op~En/meer ' JTZ:ka:0006 Attachments May,19, 1999 IO'01AM UNOCAL CORP, 1to,5977 P, 2 ARCO Alaska, Inc. Completion -- Workover Log ---;Daily ! Mill WEll. HI:~TORYISUMMARY LA,~T 24 HR8,: TMOn. I/./ ~ ]KN,,[ AlJl[kllq.¥; [IkCl ,I/IMNII OAILk Pflil IZI · ~KiO~ ,..i ........................... L- -' ill JII Ii ........... '--:i~ May,J9, 1999 ]0'02AM UNOCAL CORP, k, No,5977 P, 3 AR'OD/Alaska, Inc. . ~.,,,..,.,~.- ~ Completion -- Workover Log -- Dally ~ ' - I ~ T~ '" I ~W ~ J '~'~. H~"~,~ ' ....... ~ ~/~ .~e~..._?~ ~ · ~ ~.. ~, ~,. ~ ~T~. ~~r~ ~~. ........ i iii i ii i i i .... i1~1 i i i i iiiill '-" . ........ :~1 ' i ,.. .,,: '_~ ..... .. -d .., iii ................ Illll I il I .. WILL · .PLO0 PM ~o'~ May.19. 1999 IO:02AM UNOCAL CORP. October 21, 1992 t~e cede~ W5-2 Sub~ieet: .K- 15 MIT rr~m/t, ocatio~ J. T, Zernell ATO- 1366 T~lephoae: 263-4107 To/Loo. tton: P.J. Archey KI Please find the attached revised procedure for performing the MIT testing on the subject well. This Well is currently operated .under a verbal waiver from the AOGCC for continued operation with known PC to SC communication, This waiver was received on September 29th from the Commission's Mr. Wondzell. The basis of the waiver was based on the premise that we install an alarm on the PC that would alert the operator of unexplained PC pressures over 500 psi. Also a .chart recorder is to be installed on the SC. Until recently the PC to SC pressure was only intermittent and had been evident only when the well was on injection. When not on injection MIT test pressures were not transmitted from the PC to the SC. However, more recent testing has found that the communication does in fact now exist .under both injecting and shut-in conditions, Hence the need for the waiver to conUnue operations. The previous MIT procedure for this well has been revised to lira_it the pressure for the MIT so as not to exceed the burst rating on the surface casing since it is almost a certain~ that we will see test pressures on the surface casing. The previous procedure had restricted the SC pressure to 200 psi, however, with the nature of the communication this pressure will occur with a minimum amount of PC pressure which will not suffice to prove the integrity 'of the packer, tubing, etc. Therefore the revised procedure calls for allowing the SC to go as high as 2,000 pst (< 7C~ of the. casing burst). In order to ensure that this pressure is not exceeded it is therewre necessary to restrict the MIT test pressure applied to the PC to 2,000 psi also. If applied with the well not on injection this will provide more than sufficient differential pressure to demonstrate the integrity of the completion with respect to the injected fluids, (It should be noted that earlier this year during a preliminary MIT, t_he PC and the SC were simultaneously pressured up to 2,700 pst without incident). Please let me know if you have any quesUons with this procedure. Attacb_ments C~ Giles/Davis KSP JAR/O'Dell SRF Fax'd to KSP by .~ on ~/,~..~/~ Fax'd to KI by~ on ___/__/.__ rax'd to SRF on l l l I l ~NELL May,19, 1999 IO'03AM UNOCAL CORP, ARCO Alaska, FIELD- DISTRK~f - STATE · -. . No,5977 P, 6 /ELL SERVICE REPORT 1DAYS' IDATE ....... REMARKS OPERATION AT REPORT TIME !0' ~2 ER 'dHOO ]VOONn Unocal Corporation 909 West 9'h Avenue, P.O. Box 196247 Anchorage, Alaska 99519 5/11/99 Blair Wondzell State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Variance request King Platform Well #K-15RD Dear Blair: This letter and the attached form 10-403 support the request to put K-15RD on injection with a variance. K-15RD has communication between the tubing, 9 5/8" casing and 13 3/8" casing. A jug test was done on 6/14/98 which proves this well is able to hold 1920 psi during a 7 day jug test. Summary of Testing I have attached both graphical and tabular data from the jug test. As you can see from the attached data, on 6/12/99 after bleeding the well off to 500 psi, a plug was set in the tubing tail and the tubing was pressured up to 2200 psi (9:45 pm). The tubing and 9 5/8" casing tracked identically while the 13 3/8" casing began to rise. The well was shut-in and the pressures were allowed to equalize. By 5:00am on 6/13/99 the 13 3/8" pressure was at 1770 psi and the tbg & 9 5/8" casing was at 1930 psi. By 6/15/99 at 10:00am all three had equalized at 1920 psi. Further pressure monitoring continued via the morning reports. The morning reports show the pressure of the tubing and 9 5/8" casing to hold a constant 2050 psi from 6/15/99 through 6/20/99. The difference in pressure (1920 vs. 2050) has been attributed to different metering system, never the less, all the data shows that the pressure was a constant for five days once the pressures equalized. Thus proving the ability of this will to hold a pressure of at least 1920 psi. In addition, the results of two temperature surveys, one ran on 1/31/98 after a 30 day shut-in time (following years of injection) and the second one ran on 5/9/98 after a 12 hr shut-in time (following 5 days of injection), depict no injection water exiting the wellbore above the packer. Unocal' s Position It is Unocal's opinion the well can be operated safely with no risk to other reservoir and aquifers. The reasons for not repairing this well and requesting a variance are: 1) Limited life of the platform and field 2) Increased ultimate recovery of oil 3) Prime location for injection (see attached map) Please grant us permission to continue injection into this well under the assumption that we will limit the injection pressure to 1900 psi, monitor the various pressures/rates daily and report this data monthly. We will run a temp survey every two years for comparison with the base survey which was submitted on 4/9/98, but the main source of data to insure the safety of this operation will be the daily monitoring of injection rates and pressures. If you have any questions regarding this, please contact myself at 263-7830 or Steve Tyler at 263-7649. AlaskaOll s Aogcc King ~-~g~DatJ~lew Variance.doc Senior Reservoir Engineer Cook Inlet Waterflood Management 05/11/99 1. Type of Request: 2. Name of Operator STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: MIT Perforate: Other: UNOCAL 3. Address P.O. Box 196247 Anchorage, AK 99519 - 6247 4. Location of well at surface Leg 2, Conductor 9; 611' FSL, 121' FEL, SEC 17, T9N, R13W At top of productive interval 2283' FNL, 4' FWL, SEC 22, T9N, R13W At effective depth 2526' FNL, 125' FWL, SEC 22, T9N, R13W, UM At total depth 2577' FNL, 147' FWL, SEC 22, T9N, R13W, UM Present well condition summary Total depth: measu red 12200' feet true vertical 9819' feet Effective depth: measured 12170' feet true vertical 9802' feet Casing Length Size Structural 204' 24 Conductor Surface 2301' 13-3/8" Intermediate Production 10690' 9-5/8" Liner 1720' 7" Perforation depth: measu red 5. Type of well: Development: Exploratory: Stratigraphic: Service: X 12. Plugs (measured) true vertical Junk (measured) 6. Datum elevation (DF or KB) 100' 7. Unit or Property name Trading Bay Unit 8. Well number K-15RD 9. Permit number 79-0034-0 10. APl number 50- 733-20171-01 11. Field/Pool McArthur River (Hemlock) Cemented Measured depth Pile Driven 384' 1150 sx Class G 2401 & 400 sx Class G 1000 sx Class G 10790' 382 sx Class G 10457' - 12177' feet RECEIVED 1999 2293' 8631' 8374' - 9810' 9322~~9351~~9377~-9411~~9465~~953~~~9563~-9597~~9613~~9688~~9718~~9768~~9784~~98~1~ Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 @ 10,080' MD; 3-1/2", 9.3#, L-80 f/10,080' - 11,496' Packers and SSSV (type and measured depth) Baker FB-1 Packer @ 11,451' MD, Camco SSSV TRDP-1A @ 295' MD ORIGINAL 13. Attachements Description summary of proposal: Detailed operations program: BOP sketch: See attached data 15. Status of well classification as: Oil: Gas: Suspended: Submitted temp data to Blair Wondzell on 4/23/99 Demonstrating Service: csg integrity. Permission to inject w/variance ganted on 4/26/99 14. Estimated date for commencing operation Commence injection on granting of variance 4/26/99 Date approved 16. If proposal well verbally approved: Blair Wondzell Name of approver 17. I hereby certify tha;t the'fol;ego'u~;C'C'true and correct to the best of my knowledge. Signed: L'¢~ Title: j~.~/'~fl~" ~-~,~--' Date: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval Ng. Plug integrity BOP Test Location clearance '', I ~7,¢~- _., Mechanical Integrity Test Subsequent form required 10- /~.~"'~.~ ~ ..... ./_ ~;~i~,~ - oo , . Approved by order of the Commissioner Ur~ginal Signea By David W. Johnston Commissioner Form 10-403 Rev 06/15/88 tbu-k15info PTD 79-034 - Re-Start Injection into TBU well K-15RD2 May 1 9,1 999 Problem: Well has communication from 4.5" tubing to 9-5/8"x7" long string to 13-3/8" surface casing. Considerations: (Jack, Blair, & Bob discussed 5/19,99) 1. McArthur River Field well TBU K-15RD2 is on the King Salmon platform along the West Side of Cook Inlet, offshore from Trading Bay. 2. All aquifers under the McArthur River Field were exempted by EPA prior to the Commission taking primacy. 3. The exemption is from the mud line down. 4. Temperature surveys on 1/31/98 and 5/9/98 indicate no fluid is exiting the well above the packer. 5. The plot of rate vs injection pressure from July 1994 to July 1 998 shows consistency. 6. The tubing leak(s) have been found - 100 joints have 41 - 85 % wall loss, therefore attempts to patch the tubing are not feasible. 7. K-15RD2 is a good injection well, capable of 12,000 B/D rates (platform total, with K-15RD2 shut-in -4 wells- is about 40,000B/D). 8. A plan was developed to repair the well either by replacing the tubing or by running a CT inner string (this option was cheaper but would reduce rate). The plan was set aside because of the drop in oil price and partner's (Force Energy) economic situation. 9. Attempts to locate the leak (s) in the 9-5/8" have not been successful. 10. A jug test of the tubing and casing strings in June 1998 demonstrated the integrity to hold at least 1920 psi. 11. Limiting injection to 1900 psi surface pressure should insure that all injection exits the wells into the intended Hemlock-G zone pools. 1 2. By increased monitoring of the tubing and casing pressures and of the injection rate, we can confirm that fluid is not exiting the well at a shallow depth. 13. Bi-annual temperature surveys will confirm that injection is only into the Hemlock-G zone oil pools. Recommendation: We recommend that water injection into TBU well K- 15RD2 be allowed for a period of 2 years at surface pressures of less than 1900 psi, 'provided that on a daily basis the tubing pressure, long string pressure, and surface casing pressure be recorded, evaluated, and submitted monthly to the AOGCC. This approval shall end May 31, 2000. K-15 Date Time Tubing Casing Casing Casing 9 5/8 13 3/8 20 21:45 2200 2200 640 120 22:00 2150 2150 720 120 22:30 2110 2110 850 120 23:00 2080 2080 960 120 23:30 2050 2050 1100 120 6/13/98 0:00 2020 2020 1220 120 1:00 1990 1990 1420 120~ 2:00 1960 1960 1580 120 3:00 1950i 1950 1660 120! 4:00 1930 1930 1750 120 5:00 1930 1930 1770 1201 6/15/98 10:00 1920 1920 1920 120 6/12/98 21:45 6/12/98 22:00 6/12/98 22:30 6/12/98 23:00 6/12/98 23:30 6/13/98 0:00 6/13/98 1:00 6/13/98 2:00 6/13/98 3:00 6/13/98 4:00 6/13/98 5:00 6/15/98 10:00 o:\ooe\ooefields\tbu\ki ng\wells\K- 15\K-15 RDI NJ\su rveys\injection K-15 Variance Request.xls Jug Test Data 5/10/99 4:16 PM · ,APR-23-99 FRI 13:52 40 O' 1,000' 2,000' 3,000' 4,000' 5,000' 6,000' 7,000' 8,000' 9,000' UNOOAL ASSET GAS GAP FAX NO, 907263.7874 P, 02 King Salmon K-15RD 5/9/98 Temp Survey 60 70 80 90 100 110 120 130 5 days Inj · 12 hr SI · 5/9/98 Temp Survey 3-3/8" Csg , , 9-5/8" Csg --"-Years Inj · 30 day SI · 1/31/98 Temp ., Survey · Shifted in depth and temp 10,000' 4-1/2" X 3.1/2" Crossover @ 10,080' 11,000' __ ,[Pkr @ 11,451' J ................ 12,000' K-15 RD Composite.xls Composite st~,e !Tyler ~'": ;:4/23/99 . ,"' ,*" K-15RD Pressure History 3000 25OO 2000 1500 1000 5OO 24 Hours ~- ~ ~Tubing 5/8 3 3/8 ~Morn Rpt Tbg Pressure '""~*'~Morning Rpt Csg Pressure K~15 Variance Request.xls 5/10/99 Jug Test Chart 4:16 PM 3500 ~ ........................................................................ -~ 30000 ----~- ¢~ 9 5/8 3000 ~13 3/8 ~, 25000 tubing pressure casing pressure 2500 ~injection volume 20000 2000 15000 1500 10000 1000 5OO 5OOO ! / / / '-~TEELHE~ / . ¢~PR-23-99 FIJI 14'03 UN00RL RSSET GRS GRP FRX NO, 9072637874 t" unocal gog W. gth Avenue Anchorage, AK 99501 Fax 907-263--7874 907--263-7665 (confirmation) P, 02/09 79 -o3~ Fax transmittal To' Fax Number: From' Date: Subject: Pages' Cover plus Comments: · APR-23-99 FRI 14' 12 UNOOAL ASSET GAS GRP FAX NO, 9072637874 P, 08/09 K- 15 Wat~Flood Test 12/11/97 Test Preformed by Norm Renney and crow TIME TUBING 13 3/8 01:00 400 PSl 0 01:00 CLOSED WING VALVE 01:15 300 330 01:30 150 110 01:45 100 50 02:00 100 40 02:05 2950 720 02:10 2950 1300 02:15 2950 1700 02:18 2950 1820 SHUT DWN TURBINE 02:30 900 1120 02:45 420 450 03:00 260 220 03:15 190 I60 03:30 140 100 03:45 100 70 04:00 50 40 SURFACE 9 5/8 130 0 130 0 130 140 130 90 130 50 130 2100 135 2210 135 225O 135 2250 135 880 135 420 135 260 135 190 135 140 135 100 135 50 CHOKE CLOSED CLOSED CLOSED CLOSED CLOSED CLOSED CLOSED CLOSED CLOSED K-22 01:00 0 360 8 0 NORMAL OPEN 01:15 2900 360 8 OPEN 01:30 2950 360 8 1700 OPEN 01:45 2950 350 8 1740 OPEN 02:00 2950 350 8 1740 OPEN 02:15 2950 350 8 1740 OPEN Immediatdy after starting the turbine, the pressure on K-15 tubing upstream of the choke read 2100psi. The choke was closed but leaking through so I closed the wing valve. The pressure on the 13 3/8 gauge began to climb right after the turbine was started. By 01:10 it was up Io 600 psi. However, after I closed the wing valve the tubing pressure began to drop. By 1:15 AM thc tubing and casing pressures were equalized and the pressure continued to drop simultaneously. At 2 AM I opened the wing valve on K-15 and lef[ the choke fully closed. Because the choke was leaking by we were injecting into k~15 at a 10 bbl per minute rate. At 2:20 AM, after shutting down the turbine, (2:18 AM) the tubing and casing pressures were almost equalized and bleeding off proportionally. The Oil choke that we installed for this test was closed prior to starting waterflood and remained closed throughout, the test. STATE OF AL.ASKA ALASKA OTL AND G~S CONSERVATION ~SSiO~ o · K-4RD P P Brine ' *'10, 050 ' COM~S: The Pac..kef t'azibd ff.~ test. COMMENTS: TBG. IN,L FLUID CODES TEST TYPE: ~R FLUID:. P.P.G. Grad, WFt__L TEST: F = FRESH WATER lng. M = ANNULUS MONITORING DIESEL G = GAS INJ. P = STD ANNt.rLUS PRESSURE TEST GLYCOL $ = SALTWATER INJ. R = INTERNAL RAD. TRACER ~JRVEY SALT WATER -- N = NOT INJECTrNG A = TEMPERATURE ANOMALY TEST DRI/.LING MUD-- D = DIFFERENTIAL TEMPERATURE TEST OTHER _ OPERATOR REP SIGNATURE: AOGCC REP SIGNATURE: Inilial 4 - Yem )[ Workover -'--"--- _ Other (R~ 9/17~96) Date: Wireline Company: Work Being Done: Present Operations: Unocal Supervisor: Wireline Unit Number: Zero Wireline at: Minimum Tubin;] I.D. CAL ALASKA RESOUI ' =_S WELL SERVICE REPORT 7-17-98 Pollard Wireline Pull Plug Letting well Equalize Randy McMayhill #1 Tubinq Han.qer 2.75 Well Number: Location: AFE # ! PO #: Wireline Crew: Total Wireline Miles: Fill Tagged at (KB): Well KB: Max Tool String O.D, K-15 King Salmon 132480 Barrow/Larson 16 N/A 35' 2.20 Time Operation Details 0800 Arrived at OSK, flew to King Salmon Platform, checked in, discussed job, held safety meeting. 0930 Moved equipment, spot unit, redressed stuffing box, rigged up pressure tested lubricator & BOP. 1230 RIH w/2 Y2 JDC to 11,491' KB, Tried to latched, POOH. Had fill on top of plug. 1615 RIH w/10' - 2", Pump Bailer to 11,491' KB, bailed to 11,496' KB, POOH. Had bailer full of Scale & metal marks on bottom, cleared up bottom. 1840 RIH w/10' - 2", Pump Bailer to 11,496' KB, ball on plug, POOH, had small amount of scale In bailer & marks on bottom. 2040 RIH w/2 Y2 JDC to 11,496' KB, latched & pulled EQ Prong, POOH. Well on strong vacuum. 2200 Rigged down, let well equalize. Work String Detail: 6" RS, 8" KJ, 5' Stem, 5' Stem, 8" K J, 4' OJ, 5' SJ. Description of any None tools or debris left in the hole: Brief Summary of Bailed scale from 11,491' KB to 11,496' KB. Ran 2 Y2" JDC to 11,496' KB, pulled EQ Prong. Total Work Completed: Total Hours Worked 14 hrs Ticket #: I Dailv Cost: Well Downtime Hrs 5 hrs Total Tool Cost P-6007 1660 150.00 Total Hour Cost 1510.00 Day #: [ 1 Cumulative Cost:I 1660.00 H2S ppm O. Approved By: Code: 3.,UN-29-~8 NON 10:00 UNO.O.,'*~{ ¢~SSET O,flS GRPuno~alFaX NO. 9072!.~'"q74 P, 01/02 Fax transmittal 909 W. 9th Avenue Anchorage, AK 99501 Fax 907-263-7874 90%263-7665 (confirmation) Fax Number: From' Subject: Pages: Cover plus Date 6/12~/98 6/13/98 Time Tubing 2000 2200 2150 2110 2080 ,o5o 2020 1~90' ' 1960 1950 1930I 1930! 19201. K-15 '(~sing 9 5t8 2000 2200 2150 2110 2080 2050 "2020 1990 1960 21:35 ~'1:z~5 22:00 22:30 23:00 23:30 0:00 1:00 2:00 3:00 /~l~j' 4:00 ] ,. 5:00 6/15 10:00 J 1950 1930 1930 1920 Cas'ing 13 3/8 640 720 850 960 1100 1220 1420 1580 .. 1660 1750 1770 1~20 Casing 20 120 120 120 120 120 120 120 120 120 120 2011 2ojj 25OO 2000 15OO 1000 50O 0 9 5/8 i '-- 13 3/8 I--' :~> x 0 = ) o:\ooe\ooefieids\tbu\king\wells\K- 15\K-15RDINJ\surveys~injeclion K-15 6-98 Jug Test Results.xls Sheet1 6/15/98 10:16 AM JUN-29-98 MON 13:41 UNOOfiL fi~lglET,, G&S GRP NO, 9072637874 P. O1/O1 Unocal Corporation 909 West 9* Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL June 29,1998 Wendy Mahan Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Status of Unocal's Cook Inlet Injector Work Dear Wendy, This letter is to provide you with an update of the work conducted since our March 27, 1998 letter which you signed granting time extensions for various wells. Testing or work w.a$ completed on the following wells and the results of this work is listed: 15Z- o'~ Z_ Anna 46-42 ':[S-a4'v- King 4RD ~ King 15RD 8o- ~le,-Dolly D-16RD 6~-~ Dolly D-22 ~..~ Grayling 22 ~3' ~ Grayling 36DPN ~'~ Monopod A-12~2 9z-~z~ Mono~ A-29 ~- ~$ Baker 9 q~. ~tn King 22RD 6B-o~ SI MIT approved on 4/17/98. SI MIT approved on 4/17/98, SI MIT approved on 4/17/98. SI MIT approved on 4/17/98. : SI MIT approved on 4/17/98. : Workover completed on 4/19/98. : Workover completed on 4/28/98. : SI MIT approved on 6/03/98. workover scheduled. Jug test proved communication, workover scheduled. Sl MIT approved on 6/03/98. SI MIT approved on 6103/98, planning acid treatment to clean tubing for testing, Variance granted on 6/09/98, Jug test proved casing integrity. Anna 27-42 :Coil Tubing ctean out completed on 6/25/98, further testing scheduled to prove casing integrity. Anna 19-42 :Coil Tubing cleanout completed on 6/27/98, further testing scheduled to prove easing integrity. Granite Point 33-14RD: Wireline fishing continuing to remove wire and wireline fish from well. Grayling 5 : Redrili in progress. Testing or work was attempted on the following shut-in wells and a time extension until Septem~e~r 30, 1998 is requested to compJ, ete further work. and testing, 65 -o t, Anna 19-42: Coil Tubing clean out completed on 6/27/98, furfl~er testing scheduled to prove casing integrity. '-'F/.el g Anna 27-42: Coil Tubing clean out completed on 6/25/98, further testing scheduled to prove casing integrity. · ~a. °-4 Grayling 28: Coil Tubing cleanout planned to follow currently active rig program. ~t~- o7 Grayling 40: Workover schedule in current rig schedule. -~-o4z. King 4RD : SI MIT granted on 4/17/98, workover scheduled. ~.$~King 15RD · SI MIT granted on 4/17/98, Jug test proved communication, workover scheduled. As you can see we are making excellent progress. Unocal re.~peetfully requests a time-extension until September 30, 1998 to complete the work on the above listed Anna wells. The Grayling and King work will be executed per our current drilling schedule, Please call me if you have any questions or clarification on these issues. Cook Inlet Waterfiood Management Please acknowledge the approval of the time extension and your receipt of this letter b of this letter to Christopher Ruff at 263-7874 (fax), Wendy~vlahan Date AOGCC JUN 29 1998 Alaska Oil & Gas Cons. Commis~n JUN-29-98 IflON 10:00 ., UNOCAL ASSET GAS GRP FAX NO. 9072637874 i" unocal ,,,,, 909 W. gth Avenue Anchorage, AK 99501 P. 01/02 Fax 907-263-7874 907-263-7665 (confirmation) Fax transmittal To: Fax Number: From: Date: Subject: w:x ~ .... - ,__L~'~'~ JUN2 9' Date 6/12/98 6/13/98 Time 21:35 ..... 21:45 22:00 Tubin~l 22:30 23:00 23:30 0:00 Casing 13 3/8 ~'~o Casing 2O 120 Tubing 9 5/8 13 3/8 K-15 2000 2200 2150i 1:00 2:00 3:00 4:00 Casing 9 5/8 2000 2200 2150 ~ ..... 5:00 2110 208,,0 2, o5o! 2020~ 64O 720 850 960 1100 1220 120 120 120 120 120 120 5OO ooo 500 ooo 500 o o o 9. .... ~5 ~5 o o o -.... -.... -.~ ~.. 1990' 19601 1950i 19,30l 1930i 2110 2o~o ~o56 2020 199O 1960 1950 1930 1930~ 1920!~201 -I I 1420 1580 1660 1750 1770! 19201 120 120 120 120 12OlI o z z o o ~>. x z o o:\00e\oeefietds\tbu\king\wells\K- 15~K-15RD INJ~surveys\injeclion .~-15 6-98 Jug Test Resuits.xls Sheet1 6/15/98 10:16 AM Date: Wireline Company: Work Being Done: Present Operations: Unocal Supervisor: Wireline Unit Number: Zero Wireline at: Minimum Tubino I.D. CAL ALASKA RESOUR WELL SERVICE REPORT 6-12-98 Pollard Wireline Set Plug Set Plug Glenn Brown #1 Tubinq Han.qer 2.75 Well Number: Location: AFE # ! PO #: Wireline Crew: Total Wireline Miles: Fill Tagged at (KB): Well KB: Max Tool Strina O.D. K-15 King Salmon 130377 Barrow/Bowman 14 N/A 35' 3.8 & 2.8 Time Operation Details 0600 Held Safety meeting, discussed job, rigged up on K-15. 0730 Pressure test Lub. & BOP. 0800 RIH w/3.80 GR to 10,080' KB (Crossover) POOH. 0945 RIH w/4 Y2" Braided Line Brush to 10,080' KB, POOH. 1100 Put well on Injection to flush tbg. 1230 RIH w/2.80 GR to 11,484' KB, POOH. 1345 RIH w/3 Y2 B-Line Brush to 10,240', too tight, POOH, made brush smaller. 1540 RIH w/3 Y~ B-Line Brush to 11,496' KB, scratched through nipple 8 times. Scratched 3 Y2" Tubing twice, POOH. 17OO 1800 2100 Injected water to flush tbg. RIH w/3" A2 BP to 11,484' KB, set plug, POOH. Rigged down for the night. Work String Detail: RS, KJ, 9' 1 3,4" Stem, KJ, OJ, SJ, KJ, 2' 1 3A" Stem. Description of any None tools or debris left in the hole: Brief Summary of Ran GR 3.80 to X-over brush. Ran 2.80 GR to nipple brush, set plug. Total Work Completed: Ticket #: I 1655 Daily Cost:I 217s.00 Day #: Cumulative Cost: 2175.00 Well Downtime Hrs. 12 H2S ppm 0 09:58 UNOCAL aSSET GaS GRP FaX NO, 9072637874 Unocal Co~por~tto~ Ag[icuRur~l ?roduc~s 909 W~s~ ~ Avenue, P.O. Box ~chorage, ~ka 99519-6247 Telephone (907) 263-7830 UNOCAL ) P, 01/01 Aprill9, 199g Wendy Mahan State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Trading Bay Field KING SALMON K-4RD, K-15RI), K-22RO Dear Wendy: This letter is to documem your approval to place King Salmon K-4RD, K-15RD and K-22RD on injection for a period of five (5) days, over the next two (2) weeks, to conduet diagnostic analysis. To verify the WFL results, we ',viii be running a series of temperature logs (before and after injection) and conducting ',wllbore pressure tests prior to the commitment of a rig activation to conduct workover operations on these injectors, Pleas~ sign and send a copy of this letter to my fax at 263-71574 otherwise call me at 263-7830. Sincerely, Christopitter A.XRuff Se~or ~se~oir EnCneer Cook I~et Wate~ood ~gement Pleas~ return a signed and dated copy of this letter m document notification for our records, WendY~a~t AOGCC 'D~te Aogcc King tests.doc 04/2t)/98 i:,,pk- 15-98 NED 15'36UNOO,qL ,flSSET C-0,S GRP NO, 9072637874 ,ii' ?,01/01 Unocal Corporation Agricultural Products 909 West 90' Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL April' 9, 1998 Wendy Mahan State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Trading Bay Field KING SALMON -q~.o3q K-4RD, K-15RD, K-22RD Dear Wcndy: The following procedure was utilized in running the temperature surveys on K4rd, K-15rd and K-22rd. K-4 RD had bccn on injection for 8 years prior to being Shut-In on 3/04/97 due to MIT failure. K-15RD had been on injection for 8 years prior to being Shut-In on 12/03/97 due to tbg/csg communication. K-22RD had been on injection for 6 years prior to being Shut-In on 12/03/97 due to tbg/csg communication. A Gage Ring nm was made to tag fill. The Temperature Survey tool was rrm ~ 60 fpm, data poillt~ were set to record every second. Senior Reservoir Engineer Cook Inlet Waterflood Management Please return a signed and dated cop)' of this letter to document notification for our records. Wcndyt~han Date AOGCC Aogcc King Temp procedures.doc 04/15/98 A?1~,-09-98 '['HU 10:41 UNOOAL ASSET GAS GRP ,,~' FAX NO, 9072637874 Unocal Corporation Agricultural Products 909 West 9~ Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL ) April 9, 1998 Wendy Mahan State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 P, 01/04 Re: Trading Bay Field KING SALMON K-4RI), K-15RD, K-22RI) Dear Wcndy: This letter is to document your approval of King Salmon K-4RD, K-15RD and K-22RD Shut-In MIT's, Attached is a copy of the temperature surveys completed in February 1998. Please review tiffs dala, If these wells pass their Shut-In MIT, please sign and send a copy of this letler to my fax at 263-7874 otherwise call me at 263-7830, Senior Reservoir Engineer Cook Inlet Waterflood Management Please return a signed and dated copy of this letter to document notification for our records. ~¢nd~ ~ " :i:)at~ AOGCC RECEIVED A?R 09 1998 Alaska Oil & Gas Cons. Commission Anchorage Aogcc King SI MIT.doc 04/09/98 A?R-09-98 THU 10'42 \ 5O ' O' UNOOC, L ASSET G¢,S GRP FO,× NO, 9072637874 King Salmon K-4RD Temp Survey 2/14/98 60 70 80 90 100 110 120 130 140 P, 02/04 ~50 500' 1,000' 1,500' 2,000' 2,500' 3,000' 3,500' 4,000' 4,500' 5,000' 5 6,00C' 6,B0~;' 7,O0U' 7,6CD' 8,0CD' "I 9,0C'J' 9,6CT 10,0(: 5' K-4rd Temp Survey.xls Depth vs Temp :,oo 0~ 1998 '~.t, t~. Alaska Oil & Gas Cons. Commissiol[~ Ancl]orage ~HH09-98 THU 10:46 40 ,~, 50 O' UNOOhL flSSET Gfl$ GRP NO, King Salmon K-22 Temp Profile 60 70 80 90 100 9O72637874 110 120 130 140 P, 03/04 150 1,000' 2,000' 3,000' 4,000' 5,000' 6,000 7,000' B,O00' 9,000 10,003 11,000' K-22rd Temp Survey.xls Depth vs Temp 4/6/98 Steve Tyler aPk-09-98 TtiU 10:51 40 , 50 O' UNOCAL ASSET GAS GRP FAX NO, 90721337874 King Salmon K-15RD Temp Survey 1131198 60 70 80 go 100 110 120 130 P, 04/04 140 1,000' 2,000' 3,000' 4,000' 5,000' 6,000' 7,000' B,O00' 9,000' 10,00(;' 11,000' 12,003' K-15RD Temp Survey,xls Depth vs Temp RECEIVED /'"?':; ('~, !:", 19 9 ~' Alaska Oil & (las Cons. Commission Anchorage 4/7198 Steve Tyler 13:52 UNOCAL (~SSET GAS GRP FAX NO, 9072637,874 i' Uno,al Corporation 909 West 9* Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL March 27, 1998 Wendy Mehan Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Status of Unocal's Cook Inlet Injector Work Dear Wendy, This letter is to provide you with an update office work conducted since our January 23, 1998 letter which Blair signed granting time extensions for various wells. Testing or wo.rk was completed on the following wells and the, results of this work is listed: Anna 29-42: Well head inspection completed (no leaks), Variance granted on 3/3/98. Baker 4: MIT passed on 2/15/98 by Lou Grimaldi Bruce 31-42: Coil Tubing operation completed to repair leaking cement plug. Pressure test completed. GP 33-14RD: SI MIT successfully completed on 2/11/98. GP 22-13RD2: Variance granted on 3/17/98, MIT completed on 12/15/97. Grayling 16: Workover completed on 3/26/98. MIT Passed. Monopod A-SRD2: MIT passed on 1/28/98 by Lou Grimaidi .Testing or work was attempted on thc follo~ng.shut-in wells and a time extension t~.,t,.'.fl,, June 30, 1998 is..rptluested to complete further work and testing: Anna 19-42: Scale cleanout of tubing completed, further testing scheduled to prove casing integrity. Anna 27-42: Scale cleanout of tubing completed, further testing scheduled to prove easing integrity. Anna 46-42: Temp Survey ran on 2/17/98, survey should prove no flow and allow SI status. Baker 9: MIT attempted on 2/15/98, further wireline tesling scheduled to prove casing imegrity. Monopod A.12RD2: SI MIT attempted, Temp Survey scheduled to prove no flow. Monopod A-29 : SI MIT scheduled to prove no flow/casing integrity King 4RD : WFL indicates possible casing leak, well shutin, further testing and workover scheduled. King 15RD: WFL indicates possible casing leak, well shutin, further testing scheduled. King 22RD: WFL indicates possible casing leak, well shutin, further testing scheduled. Grayling 5 : Workover/Redrill scheduled in current drilling schedule. Grayling 22 : Workover/Reddll scheduled in current drilling schedule. Grayling 28 : Workover/Redrill scheduled in current drilling schedule. Grayling 36DPN : Workover/Redrill scheduled in current drilling schedule. Grayling 40 : Workover/Redrill scheduled in current drilling schedule. Unocal respectfully requests a time-extension until June 30, 1998 to complete the work on the above listed Anna, Baker and Monopod weUs. The Grayling and King work will be executed per our current drilling sche_dul.e.21~se call me if' you have any queslions or clarification on fl~ese issues. R E C E ~ V ~ L) , , , na~ Oil & (;as Cons. comm~smor~ Anchorage Please ackno;vledge the approval of the time extension and your receipt of this letter by faxing back a signed copy of this letter to Christopher Ruff at 263-7874 (fax). Wendy~han Dat~e ' I - AOGCC JAN- 14-98 14ED 09' 19 UNO~,,,,. ASSET GAS GRP ,,, FAX NO, 9072637874 P, 02/02 UNO¢.AL 909 W. 9~ Ave. Anchorage, Alaska Blair Wondzell State of Alaska Alaska Oil and Gas Conservatio~ Commission k-(( Re: McArthur River Field Injectors G-22, K-4RD, K-15RD, K-22RD, K-7RD & K-11 Dear Blair: As per our phone conversation on 1/13/1998. The WFL ran on Grayling Platform G-22 showed a breach in the 9-5/8" csg between 4750' and 4800'. The WFL indicated water flowing down the 13-3/8" X 9-5/8" annulus from the breach in the 9-5/8' csg out thru the 13-3/8" shoe,,The well is currently shut-in and will remain so until it can be repaired. I will be forwarding G-22's WFL logs and summary to you when we receive them in their final version from Schlumberger. King Salmon K-4RD failed it's MIT on 2/26/97. The well was shut-in on 3/04/97, Slickline attempts on 4/5/97 failed to obtain a MIT. We plan to run a temperature survey this month and a WFL next month to confirm wellbore integrity, , King Salmon K-15RD, passed it's MIT on 2/26/97, On 11/25/97 the csg _pressured up to 2800 psi (tbg 3000 psi) indicating communication between th~- cd'"~. =1"'~'~ ~l-~'~-~'h-t~ o'n ........... l_2./_.o_3/__gz,.we plan to run a temperature survey this month and a WFL next month to confirm wellbore integrity. King Salmon K-22RD, passed it's MIT on 2/26/97. On 11/25/97 the csg~ressured up to .1.8.0.0...psi _(t_bg .3000 psi)indicating communication between the tb~?'~-~ '~v-'~( 12/03/97. We plan to run a temperature survey this month and a WFL next month to confirm wellbore integrity. King Salmon K-7RD, passed it's MIT on 2/26/97. The well was shut-in on 12/03/97 pending facility upgrades to the water flood system's ability to handle the low injection rates caused by K- 4RD, K-15RD & K-22RD being shut-in. King Salmon K-11, passed it's MIT on 2/26t97. The well was shut-in on 12/03/97 pending facility upgrades to the water flood system's ability to handle the Iow injection rates caused by K-4RD, K- 15RD & K-22RD being shut-in, If you require anything else regarding.what we discussed, please let me know, Sincerely, _ _ Steve Tyler Engineering Technician CC: Chris Ruff JAN ! ..:!. !998 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown__ Stimulate X Pull tubing x Alter casing __ Repair well 2. Name of Operator UNOCAL CORP (ARCO Alaska linc is suboperator) Plugging __ X Other 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Service Leg 2, Conductor 9; 611' FSL, 121' FEL, SEC 17, T9N, R13W At top of productive interval 2283' FNL, 4' FWL, SEC 22, T9N, R13W At effective depth 2526" FNL, 125' FWL, SEC 22, T9N, R13W, UM At total depth 2577' FNL, 147' FWL, SEC 22, T9N, R13W, UM Perforate __X_ Converted to water injector 6. Datum elevation (DF or KB) RKB 100', 7. Unit or Property name Trading Bay Unit 8. Well number K-15 RD 9. Permit number/approval number 79-34 & 9-799(10-403) 10. APl number 50-133-20171 11. Field/Pool McArthur River (Hemlock) 12. Present well condition summary Total Depth: measured true vertical 12200' .feet 981 9' feet Plugs (measured) Effective depth: measured 1 2170' true vertical 9802' feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 284' 24" 2301' 1 3-3/8" 10690' 9- 5/8" 1 720' 7" measured See attached sheet true vertical See attached sheet Cemented Pile Driven 1150 SX CL G & 400 SX CLASS G 1000 SX CLASS G 382 SX CLASS G Tubing (size, grade, and measured depth) 4-1/2", 12.6# L-80 @ 10080' MD, 3-1/2", 9.3# L-80 f/10080'-11496' Packers and SSSV (type and measured depth) Baker FB-1 packer @ 11451' MD, Camco SSSV TRDP-1A @ 295' MD Measured depth 384' 2401' 10790' 10457'- 12177' True vertical depth 384' 2293' 8631' 8374'-9810' J U L .2.. 13. Stimulation or cement squeeze summary See attached sheet Intervals treated (measured) Gas ' , A~ch0rage Treatment description including volumes used and final pressure 14. Representative Daily Averaae Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run -- I Water Injector x Daily Report of Well Operations ~X Oil _ Gas Suspended I hereby c that the foregoing is true and correct to the best of my knowledge. 17. ,~fy Si~ned [ ~' ~,~,,v//, ( ~ / ~ Title ~a Drillin~ En~i~ Form 10~04 7/~ Rev 05/1 Service SUBMIT IN DUPLICATE ADDENDUM WELL: 10/20/89 Step Rate: Data Frac 1. 2. 3. 4. K-15 RD 11,596'-11,630' @ 5 SPF Filtered Inlet Water: Pmp 2 bbls @ lbpm 2650 1'psi Pmp Pmp Pmp Pmp Pmp Pmp Pmp Pmp ISIP: ZONE: Hemlock Bench '1' 4 bbls @ 2 bpm 31351'psi 8 bbls @ 4 bpm 3680 1'psi 12 bbls @ 6 bpm 4060-4078 psi 16 bbls @ 8 bpm 4316-4255 psi 20 bbls @ 10 bpm 4517 psi 24 bbls @ 12 bpm 4810-4723 psi 28 bbls @ 14 bpm 5071-5060 psi 30 bbls @ 15 bpm 5277-5350 psi 3680 Fmc Grad: .84 Perf Fric: 800 25 bbls YF140-D 5-12-15 38 bbls YF140-D 1 0 37 bbls YF140-D 5 192 bbls WF-40 Flush 15 3300-4500-5250-5000 psi 4250 psi 3500 psi 4690-4660 psi ISPF: 3698 Fluid to Recover: 436 bbls Sand in Zone: 0 Date~ · d U L p_ 0 ^laska Oil & Gas Oons. Comm~ssio~ Anchorage ADDENDUM WELL: 1 O/2O/89 I o 2. 3. 4. 5. 6. 7. K-15 RD 11,596'-11,630' @ 5 SPF ZONE: Hemlock Bench '1' Pmp 84 bbls YF140-D Pad @ 15 bpm 4380-4522 psi Pmp 11 bbls YF140-D w/2 ppg 16/20 Carbolite @ 15 bpm 4522-4508 psi Pmp 9.5 bbls YF140-D w/4 ppg 16/20 Carbolite @ 15 bpm 4508-4480 psi Pmp 11 bbls YF140-D w/6 ppg 16/20 Carbolite @ 15 bpm 4480-4445 psi Pmp 12 bbls YF140-D w/8 ppg 16/20 Carbolite @ 15 bpm 4445-4366 psi Pmp 11 bbls YF140-D w/10 ppg 16/20 Carbolite @ 15 bpm 4366-4275 psi Pmp 184 bbls WF 40 Flush @ 15 bpm 4275-4650-4536 psi ISPF: 3346 Fluid to Recover: 322.5bbls H20 Flushed 3 bbls shod of top perf Sand in Csg: 957# 16/20 Carbolite Job Complete: 10/20/89 Ave Press: 4450 psi Sand in Zone: 12,942# 16/20 Carbolite 758.5 bbls H20 to recover Total: Fmc, Data, & Step Rate Date! ' J U L 2 0 19,92 Alaska Oil & Gas Co~s. Coramission Anchorage ARCO ALASKA INC. DAILY OPERATIONS~- PAGE: 1 WELL: K-15RD WORKOVER BOROUGH: COOK INLET UNIT: TRADING BAY FIELD: TRADING BAY LEASE: API: 5013320171 PERMIT: 79-34 APPROVAL: 9-799 (10403) NO. ACCEPT: 09/26/89 SPUD: RELEASE: 10/24/89 OPERATION: WORKOVER DRLG RIG: ARCO RIG 58 WO/C RIG: NONE 09/27/89 ( 1) TD: 0 PB:12100 09/28/89 (2) TD: 0 PB:12100 09/29/89 (3) TD: 0 PB:12100 09/30/89 ( 4) TD: 0 PB:12100 10/01/89 (5) TD: 0 PB:12100 10/02/89 (6) TD: 0 PB:12100 ND 4-1/2" TREE MW: 8.5 FSW FINISHED RU. WORKED ON CONTROLS FOR #2 PUMP. PRESS TBG TO 2000 PSI, NO COMMUNICATION. PUMP DOWN 9-5/8" X 4-1/2" ANNUL AND CIRC TBG. REV CIRC OIL FROM ANNUL AND TBG UNTIL CLEAN RETURNS OBTAINED. SET BPV. BEGIN ND TREE. POH W/ 4-1/2" TBG MW: 8.5 FSW ND TREE, NU BOP AND TESTED. PU HANGER, FREE WITH 215,000#. LD HANGER AND REVERSE CIRC TUBING VOLUME. POH AND LD 4-1/2" TUBING. MU KELLY MW: 8.5 FSW FINISHED LD 4-1/2" TUBING. LAST 300' FULL OF SAND, SCALE, AND TRAPPED GAS. LET GAS BLEED OFF BEFORE BREAKING OUT TUBING. CLEAN RIG FLOOR, CELLAR, AND BOP. CHANGE TO 5" RAMS. REPAIR AIR LEAK ON HIGH DRUM CLUTCH. MU KELLY, KELLY HOSE, SPINNER HOSES, TIW, AND SAVER SUB. POH WITH PACKER MW: 8.5 FSW RU AND TEST RAMS AND KELLY. PU BAKER CJ MILLING ASSEMBLY. PU 5" DP AND RIH. TAGGED PACKER AT 10,345', MILLED ON PACKER TO 10,352'. POH WITH PACKER WITH 20,000# DRAG. CHECK DRAWWORKS MOTOR MW: 8.5 FSW LD PACKER AND MILLING ASSEMBLY. MU 8-1/2" BIT AND 9-5/8" CASING SCRAPERS. RIH, TIGHT SPOT AT 10,419'. PU KELLY AND WASH THROUGH TIGHT SPOT FROM 10,415' TO 10,457', TOP OF LINER AT 10,457'. REVERSE CIRC HOLE CLEAN. ATTEMPT TO POH WHEN LOST RIG POWER. CHANGE OUT DRAWWORKS MOTOR. POH MW: 8.5 FSW FINISHED INSTALLING AND TESTED DRAWWORKS MOTOR. POH WITH BIT AND 9-5/8" CASING SCRAPER. HELD BOP DRILL. MU 5-7/8" BIT AND 7" SCRAPER AND RIH. TAGGED SCALE AT 10,899', COULD NOT WORK THROUGH. LD 34 JOINTS OF 3-1/2" DP. MU KELLY AND WASH FROM 10,899' TO 11,871'. BIT PLUGGED, WOULD NOT UNPLUG. POH WET. WELL : K-15RD W OPERATION: RIG : ARCO RIG 58 PAGE: 2 10/03/89 (7) TD: 0 PB:12100 10/04/89 ( 8) TD: 0 PB:12100 10/05/89 (9) TD: 0 PB:12100 10/06/89 (10) TD: 0 PB:12100 10/07/89 (11) TD: 0 PB:12170 10/'08/89 ( 12) TD: 0 PB:12170 10/09/89 (13) TD: 0 PB:12170 POH WITH BIT & SCRAPER MW: 8.5 FSW POH WITH BIT AND SCRAPER, DP PLUGGED WITH SAND AND SCALE. UNPLUG BIT AND DP. RIH WITH 5-7/8" BIT AND SCRAPER TO 10, 974' HIT TIGHT SPOT. PU KELLY AND WASH AND REAM FROM 10, 974' TO 12,100'. REV CIRC WELL, RECOVERED A LOT OF SAND. POH. POH W/BRIDGE PLUG MW: 8.5 FSW FINISH POH WITH 5-7/8" BIT AND 7" SCRAPER. WORK ON KOOMEY REMOTE CONTROL. MU BAKER RET BRIDGE PLUG AND RIH, SET @ 11, 563' AND TEST. MU BAKER 9-5/8" STORM PACKER, SET AND TEST. REMOVE 7" AND 9-5/8" LOCK DOWN SCREWS AND REPLACE. REPLACE AND TEST 9-5/8" PACKOFF. PULLED STORM PACKER AND LD. PRESSURED CASING TO 2500 PSI, LOST 40 PSI IN 30 MIN. RELEASED BP AND CIRC BOTTOMS UP. POH. RUNNING HLS' CIT MW: 8.5 FSW FINISHED POH. RU ATLAS WIRELINE. RAN VERTILOG FROM 10, 450' TO 50'. PIPE APPEARS TO BE GOOD. RD ATLAS. RU HLS AND RAN CIT FROM 10,450' TO 50'. FIRST TOOL FAILED ON BOTTOM. POH, CHANGED OUT TOOL AND TESTED. TESTING BOPE MW: 8.5 FSW ATTEMPT TO RUN CBL. COULDN'T GET PAST 11,663' DUE TO SUSPECTED SCALE. POH FOR CLEANOUT RUN. TEST BOPE & SERVICE CHOKE MANIFOLD. POH W/MILL MW: 8.5 FSW FINISHED TESTING BOP. MU 5-7/8" MILL & BHA. SLIP AND CUT 1700' OF DRLG LINE, WENT ALL THE WAY TO KINKED SPOT. RIH. REPAIR IRON ROUGHNECK. RIH, ROTATE THROUGH TIGHT SPOTS @ 10, 555', 11,685', & 12,010' . WASH AND REAM TO BOTTOM @ 12, 101'. DRILLED FC AND CEMENT FROM 12,101' TO 12,170'. CBU. POH. REV CIRC @ 12,170' MW: 8.5 FSW POH W/MILL, TIGHT SPOT @ 12,136'__ WORK ON IRON ROUGHNECK. FINISH POH. PU BIT & CASING scRAPER, RIH. WASH & REAM 25' TO BOTTOM, 3-1/2' OF FILL. ATTEMPT TO REV CIRC, RETURNS AT 50%. CIRC DOWN DP. POH, TIGHT SPOT AT 11,854' POH ABOVE LINER AND LET SOLIDS SETTLE. RIH TO PBTD AND CIRC HI VIS SWEEP. RIH W/TBG CONV GUNS MW: 8.5 FSW FINISHED REV OUT @ 12,170'. POH, NO TIGHT SPOTS. RU HLS, AND RUN CBL/GR/CCL FROM 12,170' TO 10,400' FAX LOG TO ANCH, BOND OK. PU BAKER TUBING CONVEYED G6NS. RIH FILLING DP TO 2350' WELL : K-15RD W OPERATION: RIG : ARCO RIG 58 PAGE: 3 10/10/89 (14) TD: 0 PB:12170 10/11/89 (15) TD: 0 PB:12170 10/12/89 (16) TD: 0 PB:12170 10/13/89 (17) TD: 0 PB:12170 10/14)89 (18) TD: 0 PB:12170 10/15/89 (19) TD: 0 PB:12170 10/16/89 (20) TD: 0 PB:12170 RIH W/BIT & SCRAPER MW: 8.5 FSW FINISHED RIH WITH PERF GUNS, LEFT 2350' DRY. TIE IN AND POSITION GUNS. RU TEST MANIFOLD AND TIE IN TO PROD SEPARATOR. WOULD NOT TEST. REPLACE NIPPLE IN MANIFOLD AND TEST TO 3000 PSI. SET PACKER AT 11,762', DROPPED BAR AND FIRED GUNS. FLOWED WELL FOR 15 MIN. REV CIRC 1-1/2 DP VOLUMES. RELEASED PACKER AND POH. ALL SHOTS FIRED. PU BIT AND 7" SCRAPER AND RIH. SETTING PACKER MW: 8.4 FSW MADE TRIP W/ BIT AND SCRAPERS. GIH W/ RBP AND RETRIEVABLE PKR. SET RBP @ 11,935' SET PACKER @ 11,925'. RU HLS. GIH W/ TEMP TOOL. PACKER TOO HIGH ON WLM. UNSEAT PACKER AND RESEAT @ 11,856'. BATCH MIXING CEMENT MW: 8.4 FSW GIH W/ TEMP SURVEY. ATTEMPT TO EST INJECTION W/UP TO 3,500 PSI. NO SUCCESS. POH W/WL. POH. SET BP AT 11,856' W/WL. GIH AND SET SQUEEZE PKR @ 11,856', (TAGGED BP @ 11,860'.) EST INJ @ 1-1/2 BPM W/3,000 PSI. BATCH MIX 100 SX 'G' CEMENT. DRILLING CEMENT MW: 8.4 FSW SPOTTED BALANCED CMT PLUG F/11,856'-11,250' PU ABOVE CMT, SET PKR AND SQZ CMT INTO FORMATION. FINAL ~NJ PRESSURE=4, 000 PSI. TFB. TESTED CSG TO 2,500 PSI, OK. TAGGED CMT @ 11,285'. DRLD CMT F/11,285'-11,745'. POH MW: 8.4 FSW DRLD CMT TO 11,806'. REPAIRED ROTARY MOTOR. DRLD CMT TO BP @ 11,855'. TEST SQZ TO 2,500 PSI. BLED TO 2,000 PSI IN 20 M_MIN. DRLD BP AND PUSH SAME TO BOTTOM. PUMP AROUND SWEEP. POH. REVERSE CIRCULATE MW: 8.4 FSW TESTED BOPE TO 500 AND 3,000 PSI. GIH W/ BIT, SCRAPER, & JUNK BASKETS. TAG @ 12,170'. ATT TO PU JUNK. REVERSE CIRCULATE. GIH MW: 8.4 FSW POH. PU BP AND GIH. COULD NOT GET BP TO SET IN PROPER PLACE. POH. SET BP @ 11,930' ON WL. GIH W/PKR. 10/17/89 (21) TD: 0 PB:12170 REVERSE CIRCULATE MW: 8.4 FSW TAG RETAINER @ 11,932'. TEST BACKSIDE TO 3000 PSI. OK. RESET PKR @ 11,850'. EST INJ RATES AND PERFORM MINI-FRAC. GEL TANKS AND DESIGN FRAC. FRAC BENCH 4 W/ +/- 9,000# PROPPANT. AVG PRESSURE = +/- 6,000 PSI @ 15 BPM. WO GEL TO BREAK. REVERSE CIRCULATE OUT GEL/WTR. W~L~ : K-15RD W OPERATION: RIG : ARCO RIG 58 PAGE: 4 10/18/89 (22) TD: 0 PB:12170 10/19/89 (23) TD: 0 PB:12170 10/20/89 (24) TD: 0 PB:12170 10/21/89 (25) TD: 0 PB:12170 10/22/89 (26) TD: 0 PB:12170 10/23/89 (27) TD: 0 PB:12170 POOH W/BIT & JB MW: 8.4 FSW REVERSE CIRC GEL/WATER, ONLY +-2 BBLS OF SAND BACK. POOH WITH BAKER PACKER M/U BHA, TIH, TAG SAND @ 11845. L/D 13 JTS DP. WASH DOWN TO 11932 RETAINER DRILL RETAINER AND PUSH TO BOTTOM. DRILL ON RETAINER 2' TO 12170 PBTD. REVERSE CIRC. ATTEMPT TO POOH. TIGHT ON BOTTOM. WORK PIPE AND MIX 50 BBL HI-VIS SWEEP. REVERSE HI-VIS SWEEP AROUND (2-3 BBLS SAND RETURN). POOH WITH BIT & JUNK BASKETS. POH W/PERF GUN #9 MW: 8.4 FSW PERF BENCHES 1-3 WITH 4-1/2" CASING GUNS, 36 GM CHARGE @ 5 SPF, 70 DEG PHASE. FIRST GUN RUN HAD 33 SHOTS THAT DID NOT FIRE, RECHECKED ALL GUNS. HAD 3 SINGLE MISFIRES ON INDIVIDUAL RUNS. PERFORATED THE FOLLOWING INTERVALS, CORRELATED TO CBL - 8/6/79. BENCH 1: 11,596' TO 11,630'; BENCH 2: 11,660' TO 11,700'; BENCH 3: 11,764' TO 11,840'. RD DOWE;; MW: 8.4 FSW FINISHED POH W/PERF GUNS. RAN 5.75" GR/JB TO 12,618'. RAN BAKER CIBP AND SET AT 11,640', POH. RD HLS. RIH W/BAKER RETRIEVAMATIC AND TAG CIBP AT 11,639'. PU AND SET PACKER AND TESTED CIBP TO 2500 PSI. RU BJ AND TESTED LINES TO 6000 PSI. DID INJECTION TEST W/FIW ON BENCH 1. INITIAL PRESS: 3800 PSI, FINAL: 2800 PSI,PUMPED A TOTAL OF 71 BBLS @ 14 BPM. RU DS. DID STEP RATE TEST AND MINI DATA FRAC. FRAC BENCH 1 WITH 12,942# 16/20 CARBOLITE. RD DS. POH MW: 8.4 FSW WO GEL TO BREAK. POH W/ PKR. GIH AND TAG SAND @ 11,483'. WASH SAND, DRLD BP AND PUSH TO BOTTOM. DRLD TO 12,170'. POH. POH MW: 8.4 FSW FPOH. MADE GR JB RUN TO 12,170'. GIH W/ PKR ON WL. STUCK SAME @ 10,840'. WORKED PKR FREE. POH AND LD SAME. MAKE BIT AND SCRAPER RUN. RUNNING COMPLETION ASS'Y MW: 8.4 FSW MADE GR JB RUN TO 12,170'. SET PKR W/ DP. INSTALLED 4-1/2" RAMS AND TEST. RUN 3-1/2" X 4" COMPLETION. 10/24/89 (28) TD: 0 PB:12170 RIG RELEASED MW: 8.4 FSW FIN RUNNING COPMP ASS'Y. CIRC IN PKR FLUID. SPACE OUT & TEST SSSV. ND BOPS & NU TREE. TEST SAME TO 250 & 5000 PSI. OK. RELEASED RIG @ 0200 HRS 10-24-89. JUL 2'0 Alast(a Oil & Gas Co~s. Commissio~'~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown ~ Stimulate Plugging ~ Perforate __ Pull tubing ~ Alter casing __ Repair well __ Pull tubing ~ Other X MIT Z. Name of Operator UNOCAL Corporation (ARCO Alaska, Inc, is sub-operator) 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory Stratigraphic __ Service X 4. Location of well at surface Leg 2, Conductor 9; 611' FSL, 1 21' FEL, Sec. 1 7, T9N, R13W, SM At top of productive interval 6. Datum elevation (DF or KB) RKB 100' 7. Unit or Property name Trading Bay Unit 8. Well number feet proval number 2283' FNL, 4' FWL, Sec. 22, T9N, R13W, SM At effective depth 2526' FNL, 125' FWL, Sec. 22, T9N, R13W, SM At total depth 2577' FNL~ 147' FWL~ Sec. 22~ T9N~ R13W~ SM 12. Present well condition summary Total Depth: measured 1 2200' true vertical 981 9' feet Plugs (measured) feet 10. APl numbe~' 50'133-20171-01 11. Field/Pool McArthur River McArthur River (Hemlock;) feet Effective depth: measured 1 21 66' true vertical 9801' feet Junk (measured) feet feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 284' 24" 2301' 13-3/8" 10690' 9-5/8" 1720' 7" measured See Attached true vertical See Attached Cemented Measured depth 11 Pile Driven 384' 50 sx CIG W/10% 2401' GEL & 400sx CL G 1000 sx Class G 10709' 382 sx Class G 10457'-1 21 77' Tubing (size, grade, and measured depth) 4-1/2", 12.6#/ft,L-80 @ 10080'MD, 3-1/2", 9.3#/ft, L-80 from 10080'-11496' MD 13. True vertical depth 384' 2293' 8631' 8374'-981 O' RECEIVED Packers and SSSV (type and measured depth) Baker FB-1 packer @ 11451' MD~ Camco TRDP-1A SSSV @ 295' MD Stimulation or cement squeeze summary J UN 2 1992 Alaska 0il & Gas Cons. o0mmissi0~ Anchorage Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure MIT was Cancelled Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service __X_ 17. I hereby certify that the foregoing is true and correct to' the best of my knowledge. Signed (~~ ~,. (~,~--~ Title Date SUBMIT IN DUPLICATE Trading Bay Unit Well K-ISRD Exintin_~ Perforations _ 11596-11630' 11660-11700' 11764-11840' 11880-11920' 11940-12030' 12066-12126' 12146-12166' 9322-9351' 9377-9411' 9465-9530' 9563-9597' 9613-9688' 9718-9768' 9784-9801' RECEIVED JUN 2 2 1992. Alaska Oil & 6as Cor~s. Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Alter casing Su_~_~end_ Operation Shutdown __ Re-enter suspended well Repair well _ Plugging_ Time extension _ Stimulate_ Pull tubing __ Variance _ Perforate ~ Change approved program __ .. MIT 2. Name of Operator UNOCAL Corporation (ARCO Alaska. Inc. is sub-operator1 '3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface *Location calculations based on 8/6/79 gyro. Leg 2, Conductor 9; 611' FSL, 121' FEL, Sec. 17, TgN, R13W 6. Datum elevation (DF or KB) RKB 100' 7. Unit or Property name Trading Bay Unit 8. Well number K-15RD .feet At top of productive interval 2283' FNL, 4' FWL, Sec. 22, T9N, R13W* At effective depth 2526' FNL, 125' FWL, Sec. 22, TgN, R13W* At total depth 2577' FNL, 147' FWL~ Sec. 22~ TgN~ R13W* 12. Present well condition summary Total Depth: measured 12,200 true vertical 9,81 9 Effective depth: measured 12,166 true vertical 9,8 01 feet Plugs (measured) feet feet Junk (measured) feet 9. Permit number 10. APl number so-133-~g171 11. Field/Pool McArthur River (Hemlock) Casing Structural Conductor Surface Intermediate Production Uner Perforation depth: Length Size 284' 24" 2301' 13-3/8" 10690' 9-5/8" 1720' 7" measured See Attached Sheet true vertical See Attached Sheet Cemented Measured depth True vertical depth Pile Driven 384' 1150 sx CIG w/10% 2401' GEL & 400 sx CIG 1000 sx Cl G 10790' 382 sx Cl G 10457'-12177' 384' 2293' 8631 ' 8374'-9810' i [C [VED Tubing (size, grade, and measured depth 4-1/2", 12.6#/ft, L-80 @ 10080' MD; 3-1/2", 9.3#/ft, L-80 from 10080' - 11496' Packers and SSSV (type and measured depth) ~ch0rage Baker FB-1 packer ~ 11451' MD~ Camco $SSV TRDP-1A ~ 295' MD 13. Attachments Description summary of proposal · 14. Estimated date for commencing operation January. 1991 16. If proposal was verbally approved Name of approver Date approved Detailed operation program X BOP sketch 15. Status of well classification as: Oil __ Gas Suspended . Service X 17. I hereby~.~rtifY that the foregoing is true and correct to the best of my knowledge. Signe ~1[ 0"~ .~ ) · ~.) ~::~ v",~ ' . [ ' ' d T~tle Re§z. onal Dr]_J_l].ng lvla~a§er I Conditions of a]~roval: Notify Commission so representative may witness Date IApprov_al No. _ Plug integrity BOP Test_ Location clearance ~ ! ~/~' ~..).,~'~ Test '/ Mechanical Integrity ~ Subsequent form require 10- ~ ~ ~'' ' /~o~roved CoPY -' 2etuf ~ed LONNIE O. S,IT" ~ssioner '-~~Date fl- ¢" ¢ / .Approved by the order of the Commission Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Trading Bay Unit Well K-15RD Existin~ Perforations -- 11596-11630' 11660-11700' 11764-11840' 11880-11920' 11940-12030' 12066-12126' 12146-12166' 9322-9351' 9377-9411' 9465-9530' 9563-9597' 9613-9688' 9718-9768' 9784-9801' Mechanical Integrity Test Procedures TBU Well K-15RD King Salmon Platform Preoarafion 1. Connect 2-pen recorder to 9-5/8" production casing and tubing. 2. Ensure that accurate pressure gauges are installed to monitor pressures in tubing, 9-5/8" production casing, and 13-3/8" casing. Procedures - Part I 1. Bleed down 9-5/8" production casing to 0.0 psig while maintaining injection at +2800 psig injection pressure. 2. Monitor pressures in the tubing (injection pressure), 9-5/8" production casing, and 13- 3/8" casing. 3. Record tubing and caring pressures at the start of the test, and at 15 minute intervals for one hour (i.e. 15, 30, 45, and 60 minutes). Procedures - Part II 1. While maintaining injection at +2800 psig, pressure up 9-5/8" production casing to 2000 psig using FIW and a high pressure hose. 2. Shut-in 9-5/8" production casing. 3. Monitor pressures in the tubing (injection pressure), 9-5/8" production casing, and 13- 3/8" casing. 4. Record tubing and casing pressures at the start of the test, and at 15 minute intervals for · one hour (i.e. 15, 30, 45, and 60 minutes). 5. Bleed down 9-5/8" production casing to 0.0 psig. 6. Fax 2-pen recorder chart and all test results to Murray Hamilton in Anchorage. .:--~.',::,,,./--' I"/,~,z. o,,,,..? ;:;~: ~,/,,.~ ~"~' ,~'~w,,'~ ~,~'~ Memorandum UNOCAL TO: 'BLAIR WONDZELL FROM:, KIRK KILOH Transmitting one (1) Blueline and Sepia copy of Cement Bond/Evaluation Logs of each of the following wells: G-22 6-22-75/'/~c~6T-F/ G-40 ~¢ T' 3-16-90, 3-24-90 5 -- t b-~ o /kC6 7 K-15RD~:~t.8-6-79;' 10-8-89 ¢~L- D-45 5-28-89 t,,,.,,~.~l" ~'-2.~-~'~ (..,~ 7' '"' RECEIVED DEC 1 B 1990 Alaska 011 & 6as Cons. Commission FORM 1-0C03 (REV, 8.85) PRINTED IN U.S,A. Unocal North Amel~" Oil & Gas Division [ Unocnl Cor~or~[~on P.O. Box 1S02~7 Ancnoraa. e, Alaska 99519-02~7 Teiepnone {90~ 27~-7600 Alasxa Recj~on April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey loCations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your.needs. Yours very truly, . GSB/lew KING SALMON PLATFORM FROM SE CORNER SEC. 17, TgN, R13W CONDUCTOR LEG #1: LEG #2: 9 l0 ll 12 13 14 15 16 _~.G #3 17 18 19 20 21 22 23 24 Leg ~4' 25 26 27 28 29 30 31 32 "Y" COOR. "X" COOR. WELL #' FNL 2,511,762 2,511,761 2,511,764 2,511,768 2,511,772 2,511,773 2,511,770 2,511,766 2,511,690 2,511,686 2,511,684 2,511,687 2,511,691 2,511,695 2,511,696 2,511,694 2,511,689 2,511,723 2,511,721 2,511,724 2,511,728 2,511,732 2,511,733 2,511,731 2,511,726 2,511,799 2,511,798 2,511,801 2,511,805 2,511,809 2,511,810 2,511,807 2,511,803 213,819 K-21 & RD 688 213,815 K-30 687 213,811 K-lB 690 213,810 K-17 694 213,812 K-23 (23-19) 698 213,817 K-19 699 213,821 K-22 & RD 696 213,822 K-20 692 213,768 213,772 K-15 & RD 611 213,768 K-9 610 213,763 K-4 & RD 613 213,762 K-11 617 213,765 K-13 & RD 621 213,769 K-2 & RD 622 21 3,776 K-7 & RD 619 213,774 K-5 615 213,712 213,708 ~.21 3,703 213,702 213,705 213,709 213,713 213,714 213,760 213,756 213,752 213,751 213,753 213,758 213,762 213,763 K-8 K-1 & RD K-lO &'RD K-16 K-12 & RD K-6 & 24 K-3 & RD 725 724 727 731 735 736 729 FWL 74 78 82 83 81 76 72 71 121 126 130 131 128 124 120 l!9 133 135 141 142 140 135 130 C 0 APPLICATION FOR SUNDRY APPHOVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well X Plugging _ Change approved program_ Pull tubing X 2. Name of Operator ~5. Type of Well' ! Development X Unocal Corp (ARCO Alaska Inc is suboperato ) Exploratory _ 3. Address I Stratigraphic _ P. O. Box 190247, Anchorage, AK 99519I Service _ 4. Location of well at surface *Location calculations based on 8/6/79 gyro. Leg 2, Conductor 9; 611' FSL, 121' FEL, Sec 17, TgN, R13W Operation Shutdown _ Re-enter suspended well_ Time extension _ Stimulate X Variance_ Perforate X Other_ 6. Datum elevation (DF or KB) RKB lOO' 7. Unit or Property name Trading Bay Unit 8. Well number K-15RD [eet At top of productive interval 2283' FNL, 4' FWL, Sec 22, T9N, R13W* At effective depth 2526' FNL, 125' FWL, Sec 22, T9N, R13W* At total depth 2577' FNL~ 147' FWL~ Sec.22~ T9N, R13W* 12. Present well condition summary Total Depth: 9. Permit number 79-34 10. APl number 50-133-201 71 11. Field/Pool McArthur River (Hemlock) measured 12,200 feet Plugs (measured) true vertical 9,81 9' feet Effective depth: measured true vertical 12,1 00'feet Junk (measured) 9,736' feet Casing Length Structural Conductor 284' Surface 2301 ' Intermediate Production 1 0,690' Liner 1 720' Size Cemented Measured depth 24" 384' 13-3/8" 1150sx CL G w/10%GEL 2401' 400sx CIG 9-5/8" 1000sx CIG 7" 382sx CIG 10,790, 10,457'-12,177' True vertical depth 384' 2293' 8,631 ' 8,374'-9,810' Perforation depth' measured See attached sheet RECEIVED true vertical Tubing (size, grade, and measured depth 4-1/2", 12.6#, N-80, BTC @ 10,429' MD Packers and SSSV (type and measured depth) Baker F-1 packer @ 10,356' MD Camco SSSV TRB-6 @ 277' MD SEP o 7 ]989 Alaska 0ii & Gas Cons. Commissi0 Anchorage 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch 15. 14. Estimated date for commencing operation September 15. 1989 16. If proposal was verbally approved Name of approver Date approved Status of well classification as: Oil X Gas _ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~--~,~,~. /'~.~.~/ Title Environmeni;al Enaineer / ~ Ro,¥ D. Roberts FOR COMMISSION USE ONLY Date 9/7/89 Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance m Mechanical Integrity Test_ Subsequent form require ORIGINAL SIGNED BY Approved~ by the order of the Commission LONNIE, C. SMITH Commissioner IIAppr°val No.¢.._ Approved Copy Returned .. Date K-15RD APPLICATION FOR SUNDRY APPROVALS PERFORATION DEPTHS MD TVD 11,596'-11,617' 11,660'-11,702' 11,774'- 11,836' 11,884'-11,914' 11,940'-11,971' 9,322'-9,340' 9,376'-9,412' 9,474'-9,526' 9,567'-9,592' 9,613'-9,639' TBU K-15RD WORKOVER GENERAL PROCEDURE Completion fluid is filtered water at 8.4 to 8.5 ppg. PRE RIG 1. Fill well with filtered inlet water. Pump kill pills as neccesarry. 2. Remove grating etc. from around tree in preparation for rig arrival. RIG OPERATIONS 1. Skid rig over TBU K-15RD, leg #2, slot 9. 2. Ensure well is standing full of FIW. Pump kill pills as required. Set BPV. 3. ND tree. NU BOP and test same. 4. POH with tubing (special handling procedures will be necessary due to the possible presence of LSA scale). RIH, mill over and retrieve 9-5/8" Baker F-1 packer @ 10358'. 5. Make a tandem scraper run with 9-5/8" scraper spaced out above 7" scraper and bit. Wash out fill to PBD, do not rotate unless absolutely required. 6. RIH w/7"retr. BP to 11550'_+. Test casing to 2500 psi for 30 minutes. If communication exists to 13-3/8", do not exceed 500 psi. 7. If casing does not test, leave BP set, POH and PU a 9-5/8" pkr. Isolate leak. 8. LD pkr. Run a vertilog in 9-5/8". Repair leak with either a csg patch, squeeze or both, depending on it's depth. 9. Replace the 9-5/8" x 13-3/8" packoff. 10. RIH and retr. the BP. 11. Drill out shoe joints to 12170' (the 7" shoe is at 12177'). Circ hole clean. 12. Make a bit and scraper run to the new PBTD. 13. RU WL and run a CET from PBD to TOC or the minimum depth for the log, whichever is higher. 14. GIH w/tbg conveyed perf guns and perf Benches 4 - 7 with 200 psi underbalance. 15. GIH w/WL set BP and set same @ 11935'_+. 16. GIH w/a pkr and perform an injectivity test on Bench 4 to see if the zone needs to be frac'd. POH. NOTE: This procedure assumes that it needs a frac job. 17. Squeeze off Benches 1 - 3. Test the squeeze to 2500 psi and clean out to BP at 11935'_+. 18. Perform a 50M# frac job on the Bench 4 only. 19. Pull frac string. 20. Perf remaining Benches 1- 3 w/WL casing guns (+/-100'). 21. Set a WL set BP at 11560_+. GIH w/a pkr and perform an injectivity test on Bench 1 to see if it needs a frac. NOTE: This procedure assumes that it needs a frac job. 22. Set a BP between Benches 1 and 2. Perform a 15M# frac on Bench 1. 23. Pull BP. Make a cleanout run to PBTD. POH and LDDP. 24. Run a WL set perm pkr. Run a 3-1/2" x 4-1/2" HD LOCKIT completion. 25. ND BOPS. NU tree. Release rig. Pressure is 3720 psi at 9450'. £p o ? 198,9 Anchorage 'CO D r' u~ ~'5000 PSI DIAPHRAGM F CHOKE LINE A E (3 ADJ. CHOKE (N HYDRIL PIPE RAMS ,> < BLIND RAMS Z .I ,.I ,.11 CHECK VALVE CHOKE MANIFOLD & KILL LINE W/B.O.P. ON KING PLATFORM 10-3-77 13-5/8" 3000 PSI BOP STA K ANNULAR PREVENTER 6 PIPE RAMS 5 BLIND RAMS 4 1. FMC TYPE !11 UNIHEAD 2.13-5/8" 5000 PSI HUB X 3000 PSI FLANGE ADAPTER 3.13-5/8' - 3000 PSI DRILLING SPOOL 4. 13-5/8' - 3000 PSI BLIND RAMS 5.13-5/8' - 3000 PSI PIPE RAMS 6.13-5/8" '- 3000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FIE. ACCUMULATOR RESERVOIR TO PROPER LEVEL wrrH HYDRA~ FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOFL 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURF_ BOP STACK TEST 1. FlU, BOP STACK AND MANIFOLD WITH ARCTIC DIESEl_ 2. CHECK THAT ALL HCXJ:)q:X~WN SCREWS ARE FULLY RETP~CTED, PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD, RUN IN LOCK-DOWN SCREWS IN HEAD, 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI, 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH zERo PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULLOUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSi. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL yALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI.WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JG NOVEMBER 9, 1987 (FOR TBU WELLS) SUBMIT IN DUI' .... CATE* STATE OF ALASKA ,,s,,,, th,,r r t'v~'l'st~ OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. TYPE 0F WELL: on, WELl. WELL ~ DRY Other b. TYPE OF COMPLE~ON: - ..... NAME OF OPERATOR Union 0il Company of California * 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501 4. l,ocA'rlox OF WEI,L (Report location clearltt and in accordance witt, any State requirements)* At surface keg 2, Conductor 9; 6]]' N & ]2]' W from SE corner, Sec 17, At top prod. interval reported below 2309' S & 18' E from NW corner Sec 2,2, T9N- T9N, R 13 W At total depth R13W 2608' S & 164' E from NW corner, Sec 22, T9N-R13W 1;3. DATE ~.'c'U£)DED I14. 7/7/79 18. TOTAL DEPTH, MD & 12,200' MD, 9819, .C. 5. APl NU~LP_AR~CAL CODE 50-1 33- 20171 6.LEASE DESIGNATION A.ND SERLA. L NO. ADL 18772 /~/ IF INDIA~N.N0ne ~,.o.=~ oR 8. UNIT,FA.I~I OR LF~-kSE NAME .~...~ ~ Trading Bay Unit/ 9 WE,LL NO ..... K-15' (12-22) 10. FIE~ ~D POOL, OR %VILDCkT McArthur R~ver (Hemlock) ~1. SEC., T., ~., ~., (BOTTOM O~E~IVE) Sec 22, T9N, R13W, SM 12. P~/R2VIIT N'O. 79-34 8/2/79 {'1 8/13/79/' lO0' RKB .. ~ TVD[19. PLUG, ]3,P~C'~,, MD & TVDI20..i1;' 1VI~ULTIi~LE COIVI~L., ] 21. INTERVALS DRrLL};D BY · ..... / I-IOW iViANY, ROTARY TOOL8 CABI,E TOOLS TVD[12,'100' MD'"9736TvD~ Single All 1 22. PI{ODUCINC. !NTEI~VAL(S), OF TH. IS CO,1VIPLETIO~--TO,P, BOTTOM, NAME (MD AND TV'D)* Hemlock Bench l' 11,588' MD (9315' TVD) 1'1,636' MD (9345' 'TVD) 24. TYPE ELE. CTiIIC AND OTt'IEt% LOGS RUN None 23. WAS DIRECTtONA. L SURVEY MADE Yes _ BHC Soni..c, FDC/CNL/GR,. ., CBL and Gyro Survey 25. CASING I~,EC:ORD (Report all strings set in well) CASLNG S1ZE WEIGI-IT, LB/FT,~ GRADE ! DEPTI~ISET (IV~D)I PIOLESIZI~-] 24" 13 3/8" 61~t '/ J-5.5 I ?4ill'.~, IFXT~TTNrJ 9 ~/gll 47~ I p.l~nl ]2.a?]! \ I - · " &IN-80;-i '-"-' 3,1 26, LIN EiR. lq. EC O l-{J) SIZE] TOP (A~ID~ BOTTOIVI (i\~[D) SA. CIteS CEMENT* 7I' 10,457 17.177' 382 sx I , , 28, PER, FORATIONS OPEN T'O ~RODLTC ON (In%crval, size and number) 30. SC]~[E~ (MD) SIZE ' DEPTH SET (MD) [ PACIfiER SET (~D) 29. ACID, SiiOT, F;I~CTUflE,C~%ENT SQUeeZe, ETC. 11,596' - 11,617' @ 4 SPF ! DEPT][i iN'I'EI~VAL (MD) !/I AMOUNi' 2'~ND I.iLND OF IViATEFLIAL USED 11,596'-11,.617 78 bbls acid '(18-HCL MSR lO0 60-HCL MSR 1 26) DATE FIRST PIIOD UCTI. ON 1/7/80 DATE OF TEST, 1/7/80 ~E~. 80 31.-DIsPOS,TiON , PI%OD UCTION I P~%ODUCT1ON' 5/It',IFIO'D (Flow(PR, U:a3 lif[:, purnping---size and type of pump) [VFELL GT'ATUS (Producing or I Gas L5ft I Produc~ nq ~[OURS TES.T~ :[CI1OXE SiZE IPIIOD'~ FO.t{ OI~BBL. ~ G. AS~I~CF. W/Ji'E~BBL. ! GAS-OIL IL%TIC i ...12 i 3" I ~. [ ~.-,~-o I 56 I 594 297 CASI. NG PE.ESSURE ICALC~T~ OII~BBL. GAS--ZaCF. WA.~BBL. IOI. L GRAVITY-~I (CORR.) 1 'oas (~old, uaed lot ]ue~, yen ed, e c.)' ,TEST WITNESSED BY I lAST OF ATTACHMENTS Gyro Sur)qey ' r~ ' [ ~ Dist. Drlg. Supt. DATE 4/7/80 *(See Instructions and Spaces for Additional Data on Reverse Side) * Atlantic RichfieTd Company is sub-operator. INSTRUCTION5 - · General: This form is designed for submitting a complete and correct ~,','e!l completion repe.~l and Io9 ga al! types of lands and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shovvn) for depth measure- rnents given in ether spaces on this form and in any a~tacF;mer;ts Items 20, and 22:: If this ',,,veil is completed for separate r~rcduction fror.'n. ,more than one interval zone (multiple completion), so state in item 20, and in ite-:~ 22 show the p~cduci?.9 intcrva!, or i~tervals, top(s), bottom(s) and name (s) (if any) for only the intervdl fei)or;ed in item 30. S',~bmit a separate report (page) on this form, adequately identified, for each additional integra! to be seperately produced, show- ing the additional.data pertinent to such interval. It~m2~: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMAHY OF FOI~VIATION TESTS IN('LUDIN(i INTERVAL TFlX;TED. PI:~ESSUHE DATA A-NrD ~LECOVEFiIES OF OIL. GAS. 35. GEOI~OG lC WATER AND MUD NAME MI~AS Dt~P'I"I:[ T'RU~ VERT. Dlr2wrlt , Hem! 0ck: Bench 1 11,588' 931 5' Bench 2 11,636' 9358' Bench 3 11,730' 9440' Bench 4 11,816' 9512' Bench 5 11,935' 9611' Bench 6 1 2,040' 9696' Bench 7 12,138' 9769' 3ti_.(qOI1E DATA, Aq'I'ACII -BRIEF ~DF_,S.C[t~P. ITrI.(9~S :OF 'LITI1OLOGY, POROSITY, FRACTURF~. At~PA.R.EN-T ~,~,~.~.,, ~,,ows o~ o,~,.~A~ o~ ,,,,~. West Foreland 12,175' 9808' AtlanticRichfieldCom pany Daily Well History-initial Report Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field McArthur River Auth. or W.O. no. 396303 County or Parish Lease or Unit Title Cook Inlet - Kenai ADL #18772 Redrill, Perforate & Acidize IState Alaska Well no. K-15RD Operator ARCO Alaska, Inc. Date 07/10/79 IA.R.Co's W.I. I ~Prior status if a W.O. IHour /~.6'~d,~I-{.~s ,~, / -[ ¢ Well Spudded or W.O. begun 12.9% Redrill Date and depth as of 8:00 a.m. 07/09/79 07/10/79 07/11/79 07/12/79 07/13/79 07/14/79 07/15/79 Complete record for each day reported 12,005' General RU. 12,005', Circ to kill well 8.7 ppg gas cut /2" Ts choke RU BOPE & chg rams to 4-1 . Tst rams to 3000 psi. t manifold. RU & unlnd tbg, remove hgr. RU to circ out prod seperator. Mx 9.0 ppg mud. Circ mud vol & raise mud wt. 12,005', Pulling compl string Wt. 9.6, Vis 37, PV 19, YP 8, PH 10.5, Sol 9, Oil 0 Pmp'g acid. Well dead. Pull compl string. 12,005', PU DP & GIH Wt. 9.6, Vis 38, PV 19, YP 7, PH 10.5, Sol 9, Oil 0 Fin pulling compl string. Instl 5" rams & tst to 3000 psi. PU 5" DP, RIH w/8-1/2" bit & 9-5/8" csg scrpr. 12,005', Rn gyro Wt. 9.6, Vis 38, PV 18, YP 8, PH 10.5, Sol 9, Oil 0 Fin RIH, tag pkr @ 11,536', circ, POH. RU DA & log 12,000'-11,400'. Rn gyro f/surf-Il,500' in 100' increments. 12,005', Drlg EZSV Wt. 9.7, Vis 50, PV 19, YP 9, PH 11, Sol 9, Oil 0 Fin rn'g gyro, RD DA. RIH w/EZSV & stinger on DP, set @ 11,500'. Pull stinger out of retnr, tst csg to 2500 psi. Press pushed EZSV dnhole. Tag on EZSV, would not hold wt. Psh'd EZSV dn on top of F-1 pkr @ 11,540', held wt. While stung in, att to PU on formation. EZSV retnr set. Mud circ @ surf, POH. 11,400', Prep to perf Wt. 9.7, Vis 58, PV 19, YP 14, PH 10.5, Sol 9, Oil 0 Drlg on EZSV & F-1 pkr, pkr came loose. RIH w/5 stds & psh pkr to btm° Tag btm @ 12,021', C&C, POH. RIH w/EZSV #2, set @ 11,510'. Press to 1000 psi below EZSV, PU on ann to 1500 psi, tst surf ins to 5000 psi. Est IR @ 3000 psi & 4 BPM. M&P 300 sx C1 G w/.75% D-31, .2% D-19 & .1% D-61. Sqz 260 sx below EZSV. Pull out & dump 40 sx on top of EZSV, POH 5 stds, rev out cmt, POH. RU DA, RIH to 10,870', shoot 2 SPF f/10,870'-10,872'. The abov~i_~--c_n rrect /'~ ~ ~ Signatu~ez'''- ~), D( ,"~- ~ ' ( n~ For form ~pa~atio~nd distrib~o , JDate 1 Title 11/17/82 Drilling Superi~tende~ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. INumber all daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil and Gas Company Daily Well History--Interim instructions: This form is used d~ring- driliing or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number a;I drill stem tests sequentially_ Attach description of alt cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. __ District ................. c66k Inlet i--Kena-i---" [ ~ease or Unit ~. Field McArthur --~i-~r---' ADL 18772 Date and depth Complete record for each day while drilling or workover in progress .... .as o! 8:~ a.m ....... 07/~6'/7~ .......... i0-,'~65~ ;-Pre~r~' ~-pe~f K-2 Wt. 9.6, Vis 65, PV'21, YP 16, PH 11.5, Sol 9, Oi~ 0 ....................... ~%H~/DA, sh6t 6 'holes @ 10,870'-10,872', POH. RU RTTS & RIH, s~-~ @ 10,665'. Est~IR @ 3750 psi @ 2 BPM M&P 300 sx C1 G w/.75% D-31, ................ .'1% D-19'~'~%% D-6%,. Displ w/106 b~l mud. Set RTTS, sqz cmt by displ'g 96 bbl mud. Held press on formation to let cmt set up. POH, rev out, no cmt. POH w/RTTS tl. RR to Production for K-2 perforating. 07/18/79 10,947' Perf' , gK-2 Wt. 9.7, Vis 110, PV 29, YP 18, PH 10.5, Sol 9, 0il 0 Drl solid cmt f/10,898'-10,947'. Circ hole cln, TOH. MU section mill. Suspend well @ 1400 hfs, 07/17/79. (Orders to move to K-2) 07/20/79 10,947', TOH w/#1 section mill Wt. 9.8, Vis 195, PV 45, YP 42, PH 10.5, Sol 9, Oil 0 . Resume operations @ 0600 hrs, 07/19/79. PU 2 colrs, TIH w/#1 section mill, cut out @ 10,790'. Mill 9-5/8" csg f/10,790'-10,80-~.~ Circ & cln hole, TOH. -~- 07/21/79 10,947', MU #3 section mill - Wt. 9.8, Vis 210, PV 52, YP 54, PH 11.5, Sol 9, 0il 0 Fin TOH w/#1 mill. TIH w/#2 section mill, mill 9-5/8", 47# csg f/ 10,809'-10,837'. Circ & cln hole. TOH w/#2 mill. 07/22/79 10,947', Milling section @ 10,853' Wt. 9.9, Vis 155, PV 39, YP 35, PH 11.5, Sol 9, Oil 0 TIH w/Mill #3, tl plugged @ 5000', TOH wet & unplug. TIH w/mill #3, mill 9-5/8" f/10,837'-10,853'. 07/23/79 10,947', TOH aft cmt plug job Wt. 9.8, Vis 62, PV 31, YP 17, PH 11, Sol 9, Oil 0 Mill 9-5/8" csg f/10,853'-10,866'. Circ & cln hole, TOH. TIH w/ open end DP to 10,890'. Circ & cln hole. Cmt plug job & dn sqz. TOH w/open end DP. 07/24/79 10,790', Repair mouse hole/out of hole Wt. 9.7, Vis 49, PV 21, YP 12, PH 12.5, Sol 9, Oil 0 Tst BOPE. Rn bit & csg scrpr, locate cmt @ 10,523'. Drl solid- firm cmt f/10,523'-10,790', CO to 10,767'. Tst 9-5/8" csg to 2500 psi, C&C mud. Pul~ mouse hole & repair. The above is correct S~gnat For form preparat~on"'~nd d~st.buhon - see Procedures Manual Section 10, Drilling, Pages 86 and 87 _. Date ITitle 11/17/82 Drilling Superintendent AR3B-459-2-B I Number all daily well history forms consecutively as they are prepared for each well. IPag~ no. ARCO Oil and. Gas Company '~'.,. Daily Well History--lnt Instructions: This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work oerformed. NumUer aH drill stem tests sequentiaiiv..Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final comptenon. Report official or 'representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until compleUon. District County or Parish Alaska Cook Inlet - Kenai Field Lease or Unit McArthur River ADL //18772 Date and dep~n IComplete record for each day while drilling or workover in progress as of 8:00 a.m. ! State Alaska Well no. K-15R? 07/25/79 07/26/79 07/27/79 07/28/79 07/29/79 07/30/79 07/31/79 08/01/79 10,831' (41' , ), RIH w/open ended to rev out steel cuttings Wt. 9.7, Vis 55, PV 18, YP 10, PH 12, Sol 9, Oil 0 Fin welding on mouse hole & side platform. RIH & DD f/10,790'- 10,831'. POH w/DD. 10,866', (35'), DD Wt. 9.7, Vis 60, PV 22, YP 10, PH 11.5, Sol 9, Oil 0 Rev out, wsh to btm. Pmp 50 bbl hi-vis pill, POH. RIH & DD f/ 10,831'-10,866t. 10,877', (11'), RU DiaLog Wt. 9.7, Vis 55, PV 17, YP 8, PH 12.5, Sol 9, Oil 0 DD 10,866'-10,790' [csg shoe]; stuck pipe @ 10,857'. Wrk'g pipe dn thru DD rn. 10,877', POH w/fsh Wt. 9.7, Vis 56, PV 17, YP 9, PH 12, Sol 9, Oil 30 bbl Biack Magic Manual back off @ 2000'. b~ Black Magic pill, wrk'g pipe. Pmp & spot 30 bbl B.M. pill around BHA, wrk pipe. RU DiaLog, made 2 rns, att to freepoint. Wrk dn torque in DP, free string shot & backed off RD DiaLog & POH. RIH w/fsh'g tls, tag fsh @ 10,756', screwed into fa 11,170', Drlg Wt. 9.7, Vis 54, PV 15, YP 6, PH 12, Sol 9, Oil 0 POH w/fsh. RIH, rm 10,790'-10,877'. Drlg f/10,877'-11,170'. 11,444', (274'), Drlg Wt. 9.8, Vis 63, PV 18, YP 7, PH 12, Sol 9, Oil 0 Drl & surv 11,170'-11,444'. Survey: 11,193', 31-1/2°, S33E 11,766', (322'), RIH w/bit #7 Wt. 9.7, Vis 46, PV 17, YP 7, PH 12, Sol 9, Oil 0 Drl & surv f/11,444'-11,766'. Survey: 11,693' 31° S27E 12,126', (360'), Drlg 8-1/2" hole Wt. 9.8, Vis 45, PV 16, YP 6, PH 11, Sol 10, Oil 0 Drl & surv 11,766'-12,126'. Survey: 11,855', 30-1/2°, S26E The above is correct see Procedures Manual Section 10, Drilling, Pages 86 and 87 jOate JTitle 11/17/82 Drilling Superintendent AR3B-459-2-B INumber all dally well history forms conseculively as they are prepared for each well. JPage no. 3 ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used curing drilling or workover operations. If testing, coring, or perforating, show formation name in describinq work performed. Number all drill stem tests sequentiady. Attach description of ali cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or represenlative test on "Final" form. 1',, Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of [he week in which od string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish Alaska I Cook Inlet - Kenai '[Lease or u.it # 187 Field McArthur River ADL 72 Date and depth IComplete record for each day while driiling or workover in progress as of 8:00 a.m. IState Alaska Well no. K-15RD 08/02/79 08/03/79 08/04/79 08/05/79 08/06/79 08/07/79 08/08/79 12,200', (74'), Logging Wt. 9.6, Vis 46, PV 17, YP 8, PH 11.5, Sol 10, Oil 0 Drl & surv f/12,126'-12,200'. C&C f/logs. RU Schl, rn DIL/BHC/ Sonic; bad rn, repair ti. Re-rn BHC/Sonic; bad rn. Repair ti. 12,200', (0'), TIH Wt. 9.7, Vis 47, PV 15, YP 7, PH 11.5, Sol 10, Oil 0 Re-rn BHC/Sonic log. Rn FDC/CNL/GR, ti failed. Re-rn logs & RD Schl. TIH, rm 30' to btm, C&C f/RFT ti. RU & rn RFT tl. ~ bit. 12,200', (0'), Prep to cmt 7" lnr Wt. 9.7, Vis 48, PV 15, YP 6, PH 11.5, Sol 10, Oil 0 C&C mud f/lnr. RU & rn 1720', 7" lnr w/FS @ 12,173'. RU cmt head, circ, wrk pipe; lnr stuck @ 12,173'. RU head, drop ball, set hgr; tst no good. Shear seat @ 3000 psi, circ OK. Rel f/hgr, free. 10,457', (0'), TIH w/5-5/8" bit & scrDr Wt. 9.7, Vis 40, PV 12, YP 3, PH 11.5~ Sol 10, Oil 0 Cmt 7" lnr w/top @ 10,457' FS @ 12 177' Rev out @ 10,247' , ' · · RIH, locate TOL, C&C mud. Trip out, tst csg & lnr to 3000 psi. 12,100' PBD, Trip out w/WSO tls Wt. 9.7, Vis 50, PV 17, YP 11, PH 12, Sol 10, Oil 0 Trip in w/bit #9, locate cmt @ 11,635' in 7" lnr. Drl firm-solid cmt f/11,635'-12,100', tst csg to 3000 psi. C&C mud' f/WSO tst. MU Howco WSO tls trip in w/1600' wtr cushion, set pkr @ 10,415' tail ¢ 10,424' , ' - · Tk 15 min IF weak blow to dead. TOH w/WSO tl. 12,100' PBD, Rn'g gyro Wt. 9.7, Vis 49, PV 16, YP 10, PH 12, Sol 10, Oil 0 RU DA, tst lub to 1000 psi. Rn CBL/CCL/GR w/VDL f/12,100'-10,157'. Made 3 rns. Rn spectral log f/12,100'-ll,000'. Rn'g gyro. 12,100' PBTD, RIH w/stinger on DP to tst pkr Wt. 8.4 Filtered inlet wtr Fin rn'g gyro, RD DA. RIH to 12,100', displ mud w/filtered inlet wtr, POH. RU DA, rn GR on EEL in 9-5/8". Rn 9-5/8" F-1 pkr on WL & set @ 10,345'. The above is correct Signature ~ ~.~ For form preparation and distribution see Procedures Manual Section 10, [Drilling, Pages 86 and 87 IOate ITM 11/17/82 Drilling Superintendent RE[EJVED DEC .!. 6 198Z 0il & Gas Cons. AR3B-459-2-B Number ali daily well history forms consecutively as they are prepared for each well. IPage no. 4 ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Preeare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sotd. "Final Report" should be submitteo aiso when ooerations are suspended for an indefinite or appreciable length of time. On worY, overs when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Fin,~l Report" form may be used i'or reporting the entire operation if space is availabie. Accounting cost center code District Field Alaska McArthur River 396303 County or Parish State Cook Inlet - Kenai Alaska 'Lease or Unit iWell no. ADL #18772 I K-15RD Auth. or W.O. no. Title Redrill, Perforate, Acidize Operator ARCO Alaska, Inc. IA.R.Co.W.I. Irotal number of wells (active or inactive) on this cost center prior to plugging and 12.9% / abandonment of this well IDate Hour 07/10/79 0600 Hrs. Spudded or W.O. begun Redrill Date and depth as of 8:00 a.m. 08/09/79 08/10/79 08/11/79 08/12/79 08/13/79 Complete record for each day reported Old TD 12,005 ' IPrior status if a W.O. Oil Well 12,100' PBTD, Rn'g 4-1/2" completion string Wt. 8.4 Filtered inlet wtr RIH w/stinger on DP, sting into-pkr @ 10,341', press to 2000 psi. POH, LD DP. Chg to 4-1/2" rams, tst BOPE to 3000 psi. RU & begin rn'g 4-1/2" compl string. 12,100' PBTD, Re-rn'g 4-i/2" compl string Wt. 8.4 Filtered inlet wtr Fin rn'g 4-1/2" compl string, tst ball vlv & lnd tbg. Press to 3000 psi; would not hold, getting ret f/4-.1/2" x 9-5/8" ann. POH w/tbg. Redress & press tst seal-assy. Press tst GLM; several large leaks bet GLM's & pup jts. Remake pup jts. RIH w/tbg, break'g ea jt & steam cln'g. Instl X nipple bet last 2 jts of tailpipe. 12,100' PBTD, NU wellhead Rn 4-1/2" compl string, lnd tbg. & instl wellhead. Press tst tbg to 3000 psi. ND BOPE 12,100' PBTD, Unloading well to tst NU & tst wellhead, alt vlvs & flanges to 5000 psi, 9-5/8" x'4-1/2" ann to 3000 psi. Turned well over to production for perf'g @ 1100 hrs, 08/11/79. [Perf #1, 11-596'-11,617'] 12,100' PBTD, RR 8.4 Filtered inlet wtr Tst'g Perf 11,596'-11,617'. Suspend perf'g. RR @ 1400 hrs, 08/13/79. New TD . Date Released rig 1400 Hours Classifications (oil, gas, etc.) Oil Producing method I PB Depth 12,200' 12,100' Kind of rig 08/13/79 Rotary Type completion (single, dual, etc.) Sing 1 e Official reservoir name(s) ' McArthur River - King Salmon Potential test oa[a Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day / Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected 11/2.9/82 ITM Drilling Superintendent For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well. iPage no. 5 Division of AtlanticRIchlleldCompanY / Eastman / ',, Whipstock l),~ A PETROLANE COMPANY REPORT of SUB-SURF,4CE D IREC Ti ONA L SURVEY ATLANTIC RICHFIELD COMPANY COMPANY KiSRD WELL NAME · COOK INLET,~.ALA~ ,S~ . ........... LOCATION JOB NUiVIBE R A879 G0393 TYPE OF SURVEY Gyroscopic Survey DATE 8-6-79 SURVEY BY Mickey Gray OFFICE ARCO K Pi_Al'FORM KING SALMON GYROSCOPZC SURVEY ........ C VERTICAL SECTION CALCULATED IN PLANE (iF ?ROPOSAL . '] ..... 40 .~ E: BIRECTt~]~; 5 DEG+ 0 N]:?~ REC(~RD OF SURVf:.'Y' RADIL1S OF CURVATURE METHOD A R C 0 K 15 RD cLA]rORM KING SALMON GYROSCOPIC SURVEY , COMPUTATION TIME DATE 01~ 48 ~'~'.q .,~. 00---00 PA:GE Nd, TRLiE NEASURE:D n-', ,.-_-'::,.,:CAL SUBSEA R E C -r A N G U L A R C L 0 S U R E !)OG[ ._,~'.iKT I)F~tFT '."nURSE VERi"![::AL. '::'":'""'~' . . 'qiF_F"i-H ANGLE 'OiRECTZ3N LENGTH r;~-c,-r,~ ON -"UTM ~' .,.. ,_,, ,-,SECT :( .. ~ . . - :_, C O O ~-< B :I: N A T E S DISTANCE B]:RECTION SEVEF F E E T B M rl F E E T F E E T !-:' E E T F E E T F E E T F E E T I] M D G / 1 ( O~ 0 0 0 O, 0~00 5~83 -100.00 4,56 S S,64 E 100+ 0 0 n 100~ 100~0 s ,E~-~ 0 uO a~56. F; S~6a E 300,. 0. 0 0 100. SO0 ~ ~,0 ~'. ...: ":' · 83 ,_ "~0'~ .,~ ~0 .. ,a . ,.. ~i 6 S ~64 ~' E 400, i 0 S :;4 W 100, 399 ~ '~" L:~ .~., ~ ~:, 77 299,99 5,07 S c, 93 E '= 00 .... ~, · ~ 0 S 27 E 100, 499~9.-_: Y~6U - ...... · 19 E 600 " 0 $ 45 E 100. 599 ~ 74 !3:. 74 499 '" .... :~; .53 ' · -~ . ·.,-~.~ 1 ._., 11 5., 76 E 700, 4 0 S 58 E 100, 699,50 20+56 599.::50 17044 S 11~21 E' 80()+ 4 0 S 76 E 100, 799~05 26~:'s ::~>~-' ">::' 70,16 .53 17 '"' ..... ' .. 900 · = ooo "' 21 25 ..~ SO S 90 E 100, ~'000, 6 SO S 83 E 1100~ I0 0 S 83 E 1200+ 12 0 S 82 E 1300, 14 SO S 81 E 1400, t5 0 S 81 E 100, 998.36 100, 1097.3! 100, t195~47 100, 1292,80 100~ 1~89.50 S9~99 898~.So 50~48 9970$i 64~55 ~095~47 81~/1-' 1192o-b~ .... 100~9~ 1289~5© 21.80 ~ S6."~ · - ~ E 23~55 S .50,47 E 26°04 S 69~S8 E 29o4S S 92,05 E ~41 S 117~20 E 5+85 S 38 36 E 0.( 5~87.. S 38 S6 E 0.( ,.:.,8.3 SSt-; 36 E 0.( · _,,u.~ .58 ~6 E 0..( 5i,."-'i6 S S0 2 E ~,-~ 0( 8 48 S .1.4 · .-,.-, E 14..:.2 .c; 2,: ~, IE 1 20.73. S ,_,,..:'? '~A 7,-S e 41 8 E 1 33.37 S 50 ,¥8 E: 1o 42.28 S 58 58 E 1o; 55.69 S 64 59 E .....S,E 74.11 S 69 26 E 2°( 96~64 S 72 t6 E 2~ 121~87 S 74 5 E OoE i500, 17 0 $ 80 E 1600, 19 O' $ 80 E !700, 20 15 S 79 E 1800, 24 0 S 74 E 1900, 2:4 DO S 83 g i00. 1485~62 100, 1580,72 100, 1674,91 100, 1767,53 100~ 1.858,7t il. 21 "'-" -" ,, bo 1585 · 62 'N % , . 14~-..6 1480 72 171,47 1574,91 201 +7~ 1667,5S 23S~84 1758~71 2000'*' 27 0 S 89 E 100, 1948,77 264, O0 1848,77 2100~ 28 2~0 S 88 E 100~ 20S7,27 294~85 19Z:7~27 22"00, ~0 0 S 87 E 100~ ....'2124,~1 S27~86 .~.=~..~ 2S00~ S2 oO $ 82 E 100+ ~:~10,00 364,85 t0,00 2400, 36. 0 5 85 E. 100. ~.-,=°°°'~. 64 40~,, 66 2192,64 69.44 S 327~96 E 70.66 S $74.50 E 72.79 S 423.32 E 77°76 S 474o9S E 84,1S S 530,84 E 2500, 37 30 S 84 E 100, o=~ 77 448,34 22 .... . ~-.~.. /..,77 89,87 S .~600, ~8 0 $ 85 E 100, 2451,84 492.00 2351,84 95,7S S 2700. 38 SO '' = ......... S 80 E 100. 2550,37 boo,z8.. 2.430,57 iOl,1; S 2800+ S9 0 $ 80 E 100. 2608.S6 ~01,91~=~. ~.= 109o 2900, a9 SO S 80 E 100, 2.685+79 630.38 2585,79 120,2R $ · 590,.39 E 71S,()1E 775°04 E 837,55 E J35023 S 78 $ E 3°e S81.11 S 79 19 E !.~ 429.5$ S 80 15 E 1.E 481,26 S 80 42 E ~.~ 537,46 S 81 0 E ~,E 597.19 S 81 21 E 1o~. 6od..5S S 81 ,.~,.., E 0, 720.14 $ 81 56 E 0,,=. 782,71 S 8t 58 E 845.9~.'~ S 81 5-0 El 0.~ n R C 0 K 15 R ii~ F'LATFOR'H KiNG SALNON GYROSCOP ]: C~q~.t~-" ~- v' ,... t:. DEPTH ANGLE BIREC'FtGN F ~.::_' E T D Pi I) C13t., _,' ~.-,:q c-r,..._., ...... VERT T C': ii',' i... LENGTH DEF'TI--! c:, F' E E T F E E: T FEi: E T :5000, 40 ].5 S100~ 40 15 S200~ 4]. 0 ¥¥00~ 42 SO S400+ ~S SO S 80 E' 100, 2762,54 679.... 49 S 80 E 100., 2838, ..':_i6 728.~ 99 S 78 E ln0~ 29~a .... . . - ..... ·/6 77'9 ,, .> 78 E 1 C:. 0, 29. ~::: 7 · Z 6,_,.,.:.:::' :' ":' ~ 06 S 77 E 100 · .5062, D 0 :!i:',' E: 6.:. :I. 6 S 76 E t00, 51S4,,75 ?.41..75 S 76 E 100, 5206o 67 997,,95 S 77 E i00, ._'.~. x o ,'~'~'"'-'-'~", u 10":~,. ..... .~,_ + 66 S 75 E 100, .~'~:t 14 ].]07 S 75 E ].00~ 5423 ~ 85 :i. 165~ 73 ~5()0, 44 0 36()0~ 44 0 ~700~ 43 45 5800, 45 ~0 S900, 4S 15 4000~ 4S 0 4100~ 42 45 4200° 42 .0 4S00, 41 0 44()0~ 41 0 S 76 E I00, 3496..81 :2':"I.. ° .... ':<:',_, S 75 E 100. 3570,],0 :t276 S 76 E 100, S645,97 S 76 E - 100, $718,87 S 76 E '~00, ~794 450-0~ 4600~ 4700, 480()~ 4900° 41 0 S 76E 41 SO S 77 E 41 ~'0 S 77 E 42 0 $ 76 E 42 0 S 75 E 5000~ 4~ 15 S 74 E 5100, 44 0 S 74 E 52'00~ 44 0 S 74 E 5300, 44 SO S 74 E 5400~ 45 15 S 7~ E 100, ~869~8'i 100, S9~4,99 I00, 4019,89 100~ 4094+49 100~ 4168~81 I00~ 4242,S9 100~ 4S14~77 100o- 4S86,71 100, 4458/54 100, 4529,20 5500~ 45 15 $ 71 E 100, 4599~60 5600° 45 0 S 7S E 100+ 4670,16 5700~ 45 0 S 72 E -- 100, 4740~87 5800~ 44 ~0 S 7~ E 100, 4811~89 5900~ 44 15 S 7S E 100~ 488S~7 SUBSEA T V ',') t:: E .:.': T COMF:'UTAT ]: ON PAGE 'TINE DATE 01 ~48~¥8 O0 .... O0 R E C T A iH G U L A R C L 0 S U R E I)C,'GL C 0 0 R D I N .A T E S .OISTANCE .O]:RECTION SEVE:F. F'E E T F E E T D Pi D G / ]. '" '" "; :X 7 A 9 - R '~ : ~: , · <::; .,, c:: q': o :? E 9,2 0 ...... '"''" ~. ~-:: i, ~ 1 ,.,~.,6 ~ 06 ,.. 191 S 7Y 0 : .... 44,4 :J. .. ~., -, .-,. 'y ¥ S 8 ]. + 45S.. ! 948,08 E 1 ¥ c: ._,, r.,.. '7. S .... : / · 3 $:~ 919 + 89 3; 96 "' ::' ": - :' ~ n S ,~,., $ 2012,64 E:. ~'l:ui,... 7{3 52 E ~ ' = 0 F: Pi z, q~ 2 ! c:; '78 .~,._~.,., :399a atl,90 '9 2077.,S9 E 17,8:5 47 E: ]-,','-"~5 X~ 4068.>~::::I. ~..,..,..,65 c. 17 E: 84.~64 78 41 1761,1 ,.'5, 414,_., ,. ,:~ x o 446 · 7. 5 .... S 2207 ,42 E: ~.,~ .<.. · ,.~ 8 ._, i c:. 't" S :Jr ~ ,7~ '? X :::' .... ,.,.,.U · 4.~ t"'-,~ ~ ';;7 465,76 S 2275,74 E ~... ~_ ~'~,~ 96_ S 78. 25 I:_:' 0° ...... ' ........... >2 "" 78 ' i o-z :' ' ='"' S .... .'~._,.,.77 45:.,0,7.,4 504014 S ~':'407,60 E: 2'~59,81 /8 i0 E: ! 992060 4429, .... 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S 73 F' 100, ";¢.cc, -aS ":'.'~,* ..... u '/., ...... -, _:--,-. 43.; S 72 E !00, 5! 77; · ;':'*,.- -, '"='"' ~...:._,...: :. - :';4' S 7'2 E 100+ .S"~.'; ,.. ,,~.-,. 6., 77 ..... ?:-., ).. c.,..,., 8:.3 S 72 E 100, 5321 08 .-;z'-:,: .... S 73 E i00, 5395:.A9 '.'_:!6';'J S 71 E 100, 5470,59 27..":.~ S 71 E 100, ,.,,.,-,,,_,'~'"""~'~77 S 67 FZ 100, 5620 ~ 52 :,:: '.3 6 2. .. 5Z 651+26 S 2878.21 E: 2950.98 S 77 15 7 08 o"' ,: ,=' ;', i R :..I. 2 E: 30 ,,..74,.., _. _ 77 10 E 0 690,58 S 30i:3,96 E :5089 711.0~95 S 3075,55 E 3156,65 S 76 59 E 1,( X",R2 c:. X139 RO[: 3'?'-:'3 96 .':; 76 5;5 E: ~ o( 75.._ · ,..:::' =; O !3 3203 ,44 E ,.,..,74'::<::' 0 .... '~"" 52 ¢; ':;'-:'-':, ,'::' '= ' /'/,::. ..... ...... ,:.<:, .... 94 . 3;3. ,..,7<.04 S 76 --?""~._-. i::',... 0~ ~ 0 'X' :" r,c:,<::; 76 ~ 6 E' - ?93 00 S 33.;29 96 E 81.'; a6 S 3392 30 ~::' '~'4''''''° 70 S 76 30 E: 83,'3,,-_°,", ,._:':. 3454 · 50 E- '~":'=' '~ ....... c:.,., .... 7000,. 43 0 7100~ 43 i5 7200, 42 0 7300 ~ 4t 30 7400o 42 !5 S 65 E 100, 5694,10 2923.39 S 64 E t00° 5767+09 2985.60 S 64 E 100+ 5840,67 3047,46 S 60 E 100, 5915~27 3109~19 S 57 E 100o 5989,73 Si72.48 7600, 42 t5 S 54 E 7700, 42 0 S 50 E 7'800, 4t SO S 47 E 7900, 40 0 $ .46 E 8000, ~'8'30 S 45 E I00+ 8100~ $8 30 S 43 E 100, 8200~ ~8 0 S 43 E 100, 8300, 38 0 S 43 E 100, 8400° ~8 30 S 43 E 100, 8500, 38 30 S 39 E 100, 8600~ $8 0 S 41 E i00~ 8700+ 38 0 S 40 E 100, 8800° 37 0 S 41 E 100, 8900~ 37 0 S 42 E 100, 100+ 6063,31 ':'>Z'~ ":'* :,,' ,.'~ ~% ~., ~ ~,'~ ~, 100+ 6i36,89 3303,i3 100, 6211,06 3368+73 100, 6285~66 3434,57 100. 6361.42 3499~43 . .. 6438,85 6517°12 6595,65 6674.45 6752,98 6831o24 6909,77 6988,57 7067,91 7147,77 5963~31 1028,91 S 3810,55 6036~89 t068~24 S 3865~68 61tI~06 1109o52 S 3918o53 61.:~0.66 1156+64 S 396cd+%'''..V 626!,42 1!98~57 S 4015~74 3562~4! 6338~85 !242~92 S 4060,'87 3624~50 6417+12 1287~70 S 4104~11 3686~33 6495+65 1332~97 S 4146~33 3.;747,81 6574,45 1378+00 S 4188°32 3809,64 6652~98 1423~28 S '4230~54 3871,87 6731+24 1470,25 S 42'71,~8 S966,78 6809,77 1517~68 S 4311°17 .3995~34 6888+57 1564~49 S 4351~15 4056'~21 6967,91- 1610~78 S 4390+69 4116~37 704.7,77 1655~85 S 4430~57 E 394 7 ° 02 S "" E 4010°.57 S '7,, ..'~,. E 4072 ~'~' " E 4:[5,42+.68 S 73 47 E ~-~.( E: a .1. 90 A R C 0 K :£ '=' -'"' PLATFOF:M KING SALMON GYROSCOPIC SURVEY COMPUTATION PAGE TIME DATE 01 ~ .so ' :~:,q · -~,., ~ .. ,. 00 .... 00 TRUE FiiZASLiREB DRIF'T _r~F.'XFT COURSE VERTiC:':';L. VE.R-f'.~CAL SL,'BSEA R E [.'. T A ,N G LI L A R C L 0 S U R E DOGL OEP'TH Al,!:.B~...E DIRE.:.,¥.~.ON'-"""' '" LENGTH.. . DEPTH .:::,"'"~'""";r.:.:.,: .... :::.(..~",~' TV;B C 0 O R D ]: N A 'i' ~:' ..... .q BiSTANCE D]:RECT'rON SEVER FEET D H _ri FEET FLET FEE'!- F:'E ET FEE]" FEET fZI M I)G/10 9000. E, 5 45 S .59 E 9:LO0,, 755 :L5 S 39 E 9200+ 75A 0 ~ 759 ~:' -:'.--,r: S7 0 S S9 E 940(., .,. 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'-" 443,5. 6i u; 7 100, 6,663.,,58 3778 '=":,.;4 656"." 58 1399,,97 S 4..-0.;, 94 ~.:. , "' :J 36 E 0.,,' t00, 6741,85 58¢:..0,/0 6641,,,':..:o 1445,,.50 S 4252.~.40 E 4491,,,::., S /].."1.4 E 0.:.': 100, 6820.11' 3902,95. 6720,1,1 1493,88 S 429t ,'::;"",.. / E 4,.,4.4., ].5 S.. -70. . ..-:,,.,":":'-' E ,,::.," .', ~ '"' 34 , 100, 6898,91 75964,50 6798,9.1, 1.,,,4U+ S 43~1,,,~A .": :'*"' ':: . - · 100.,,. 6977.,.71 402';6,07 6873",71 1~""'"'~o./,.,...,,,,"='-0 S . 4571 ' ":' q 44'1 02 I00,, 7057'57 4086,.,24 ,..40=:..-,, 57 1,2,3.,,:., 92 1, 4703, :~:;--''' '" ~.. 100, 7157,,. 44 414,6,7.4;9 7037,44 1677, ..',,., ,:::,,. 4,., i ~:' ARCO K 1 ~ R u PLATFORM KING SALMON GYROSCOPIC SURVEY COMF'UTATI OW. TiME DATE 02;08~18 00--00 F'AGE TRUE ..t-AL V!L'RTiCAL SUBSEA R E C '¥ A N G U L A R C L 0 S U R E IUD,_ biEASURED DRIFT DRIFT COURSE VERTT''' ' ~o~ DEF'TH ANGLE DiRECTiON LENGTH DEPi"H SECTION TVD C 0 0 R D T N A T E S DiS~'~ ..... ~. , ~;'-~Ur_ DIRECTION SEVER FEET D M B FEET FEET FEET FEET FEET FEET' D M OG/IO 9000, 35 45 S ~9 E 9100, ~5 15 S ~9 E 9200, ~6 0 S ~9 E 9~00, ~7 0 S ~9 E 9400, ~6 ~0 S 42 E 9500, ~7 0 S 42 E 9600, ~7 0 S 42 E 9700, ~8 0 S.41 E 9800, ~9 0 S 40 E 9900, S9 SO S 41 E 10000, 40 0 S 41 E 10100, 40 0 S 40 E 10200, S9 S0 S 41E 10500, 40 0 S 40 E 10400, 40 0 S 41 E 100, 7218. ~59 4204,80 7118~5~. ,.,~'>~,O~ ~q 4488,06 E 4807,45 100, 7300,26 4262,51 7200,26 1767.90 S 4524,38 E 4857,52 S 68 39 E 0~5 100, 738~ 16 432i,28 ~R~ _ _, ~,.~16 1815,58 S 456~.57 E 4908,68 S 68 100, 7461 02 4581,45 736L~? 1860,~~ .... ~ ' ..... ~ S 4599,24 E 4961,2o S 67 59 100, 7541,41 4440,R5 7441.41 1905~R5 ~ 4639 _ ~ ~ ,8i .E 5015,25 ~,, * ,~ 506 ' - 100, 7621,27 4501,00 752! 27 1948 ~8 S 4680,08 E 9~55 S 67 24 E 100, 7701~14 4561,14 760i.~14 i995.50 S 4720,55 E 5123,96 S 67 6 E 0~( ~'~;.94 20..9,77 S 4760,74 E 51790~t S 66 ~= r- i,i 100, 7779.~4.. a6~2. ~ ,70 /~/.' ~'~ -'. 100, 7857,65 =~685,A~__ ~'~x~, ~65 2087,98 S 4801,19 E 52~5,~A_.~ ~_ S 66 S0 E' 1,1 100, 7954,81 4749,23 7854~81 2155~98 S 4842,92 E 5295~'~4 S 66 12 iS . 1'00, 8011,42 4813;50 7911~42 2184,49 S 4885,09 E 5351,28 S 65 54. E 100, 8088,02 4877,78 7988,02 22~S.75 S 4926,41 E 5409~17 S 65 S7 E '100, 8165,19 4'941,57 8065~1~9 2281,74 S' 4968~14 E 5467,06 S 65 20"E 100, 8241,'79 5005,65 8141,79 2350~98 S 5009,46 E 5525,25 S 65 100, 8~18,~9 5069,92 8218~9 2579,49 S 5051,65 E 5585~99 S 64 47 E ' '=" 0 ' S ' ' -' ~, ' :: ~: '~ ' ? oo o~-- 00 ::: A 4 o ..... 10600, 40 0 S 40 E '10700, 39 SO.- S 39 E 10800, 36 SO S S6 E 10850+ S2 0 S 40 E 100, 8471o60 .,1¥8,47 8371,60 .... '?a77,2~.i S 5125, 1~.:'~"'~:" -, ~.~ ~: -- -- 100+ - 8548,77 5262,07 8448.~7/ 2~:o+68 S 5175,10 .~' b759~0]. S 63 59 E 100, 8o~v,15 5221,40 .... 8 ~'~,15 2574+80 R 5210+11 E 50+ 8671 :;5 :q~"'~,~O : 8571 ~-:; '":;'~:,0.9 ' ~ 58~;=~ '- .A~: .... ·~ ~, ,.~ ~:~9~. S 5227,14 E 10900, 31 0 S'.SS E 50, 8714,41 ._~.~'.,46 8614,41 2616 69 S' 5241,1'7 E 5858,06 S ~::.:, 28 11000· $1 0 S SS E 100+ 8800~ 15 5424,58 8700 · 15 ~..'"~.4~:o,... + 89 S 5269 · -~_~'? E 5902,51 :;.. 65 1'11100~ ' 30 O-S 33 E -- 100, 8886,73.- 5474.,21-. 8786,73- 27.01· ~or' S ..,~°°z~,~,,a5. E.. 5945,77 .,° o,.'° 11200, 30 SO S 32 E 100, 8972,89 ~.~,,q~°~ 47 8872.89 2744+86. ..~ 5323,3~,~ E 5989+~'~:'~, S 62 43 E 0~' 11300, 30 30 S S1 E 100~ 9059~06 :~- o7oo ..... =~74~60 8959~06 ~.. ~,~,+$7 S 5~49,49 E 6052~58 S /,2 ~q~...- E 0~. - . ..... . 11400, S1 0 S S0 E 100~ 9144+77 :~ - :' ~.~.~, S2 9044+ 77 ~ ~ '" 62 · ~83~97 S 52;75~24 E 6076~09 ~ IS E 0 11500~ S1 0 S 29 E 100, 9250,49.~,~,88qA-'q 9150~49 ~-~m7:~02 ........ S 5400~21 E 6119~25 q 6:[ 11600, '51 0:- S 29-E ........ 100~ ....'9~t6+21 .~S~'~,..~,.~"~ .... ~.,16~21 ~,~.~,~°~'~06 S ~,,~,,~-~18_ E. 6:~2+54.._~ ~q 61 41 E 0 , 11700~ S1 0 S S1 E 100, 9401,92 5777,50 '9501,92 2967~-~1 S 5451~70 E. ~°-~88o~o S 61 27 ::'~._ 1~:. 11800+ 32 0 S 26 E 100+ 9486+75 5828~72 9586~75 ~014~84 S 5474~95 E 625'0~15 ,.:.c' A'.~': . -,. ARCO K15RD PLATFORM KING SALMON GYROSCOPIC SURVEY _,UMk'UTAi'ION TiME DATE 02;08;i8 00--00 TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGL DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TV~; C 0 0 R [~ I N A T E S ~£;iSTANCE DIRECTION SEVER FEET D M D FEET FEET FEET FEET FEET FEEt D M DG/10 11900~ ~ ~0 S 25 E 12000~ ~4 0 S 24 E 120&0~ ~4 0 S 23 E 12100~ ~4 0 S 2S E 100+ 9570~12 5882o0~ ~470~12 ~064~8& S 54~8~26 E 62~4+78 S 60 52 E 100. 9653,02 60. V702~76 5767~87 ~602~76 314&~83 S 5534.11 E 6~66~4 S 60 23 E 0~ 40. ~735.~2 5~8~.26 FINAL CLOSURE - DIRECTION; S 60 DEGS 15 MtNS :[6 SECS E '~ ~ OS DISTANCE; 6~.8~ FEET l~orm ~o. P--4 I~.gV. ~- I-?0 STATE O~ ALASKA OIL AND GAS CONSERVATION COMMIT-I'EE SUBMIT II'q DUP. LICATE MONTHLY RE'PORT OF DRILLING AND WORKOVER OPERATIONS 1. o~ ~ °" Fl W~LL WELL OTHER 2.NAME OF OPE~%ATOR Union Oil Company of California* 3.ADDRESS OF OPEP,.ATOR 909 West Ninth Avenue~ Anchora.qe, Alaska 99501 4.LOCATION OF WEL~ King Salmon Platform Leg 2, Conductor 9, 611' N & 121' W from SE Corner Sec 17, T9N-R13W. ~ API NUS. IERICAL CODE 50-1 33-201 71-O1 LEASE DESIGNATION AND SERIAL ADL 18772 IF INDiA],~ ALXDi'I-EE Ol~ TRIBE NAME N/A 8 L~.'IT FARA{ OR LEASE NA34E Tradinq BaS Unit g WELL K-15 (12-22) .. McArthur River (Hemlock) 11 S~-C , T.. R., 1%~, (BO'I~TOM HOI_~ oB,rm, c'q'~ Sec 22, T9N-R13W, SM PERlVl IT NO 79-34 13. REPORT TOTAL DEPTIq AT END OF MONT~, CHA~NG~ IN HOLE SIZE, CAS1NG AND C~MF2~TING JOBS INCLUDING DEPTH SET AD VOLUIVIES USED, PERFORATIOATS, T~I~TS ~ RESULTS FISHING JO~.~ JU/~K IN HOLE AND SIDE-~R.ACKED HOLE A.N'D A.~Y OTHER SIGNIFICA2CT C1-L~NGES ~ HOLE CONDITIONS Monthly Report for November 1979' No progress has been made in establishing production. Acidization & reperforation are pendi.ng for the first week of December. *Atlantic Richfield is sub-operator. SIG~ ~ ~' ~'E~~,-.~:~ Dist. Drl~. Supt. DA~ 12/5/79 ~E--Report on this form is required for each calendar ~nth% regardless of the status ~f operations, and must ~ flied ~n duplicate with the oil an4 gas conservation commiffee by the I~ of lhe succ~diflg month, u~l~ ~t~flrwise F~n-a No. P--4 I~EV. 5-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER SUBMIT IN DUPLICATE 2. NAME OF OPERATOR Union 0il Company, of California* 3. ADDRESS OF OPEI:~kTOR 909 West Ninth Avenue, Anchoraqe~ Alaska 99501 4.LOCATION OF WF-J~ King Salmon Platform Leg 2, Conductor 9, 611' N & 121' W from SE Corner Sec 17, T9N-R13W AP! NUA~ERICA_L CODE 5Q-] $3-2017]-0] LEASE DESIGNATION AXD SERIAL NO. ADL 18772 IF INDIAN. ALOT/-EE OR TRIBE NAME L.~IT F.~'iAI OR LEASE NAME Trading Bay Unit WELL NO K-15 (12-22) 10 FLF, I..D ,A_ND POOL. OH %VILDCAT McArthur River (Hemlock) 11 SEC, T.. R., 1%~. (i~.)~'TOM HOI~E O~rVE~ Sec 22, T9N-R13W, SM 79- 34 I--i"COM'M-- I '" /' J COMM',,?' J 13, REPORT TOTAL DE/~TH Al' END OF MONTH. CHA. NGES IN HOLE SIZE. CASING AND CKMF2,:T!NG .JOBS INCLUDING DEPTH SET ~ VOL~S USED. P~ORATIONS. ~STS ~ ~S,ULTS FISHING JO~ JI~K ~ HO~ AND SIDE-~ACKED HOLE _ , ~--j AND ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS J J RES EN Monthly Report for September 1979' Made various production tests. Unable to establish actual production. This repor~ has been delayed due to an oversight on our part. RECEIVED 0V 1976 An~horag~ *Atlantic Richfield Company is sub-operator. ! hereby ~ i/~a% the f~>~l~l~o]j&~g ~' { /. ' ///~.~ ~~ Dist. Drlg. Supt. D~T~, 11/26/79 ~-I~TE --Report on thie form il required for each calendar month% regardless of the ,tahl$ of operations, and must I~ filed In duplicate with the oil and goo conservation committee by the 15th of the &ucceeding month, uale~ otherwise ~recfed. J"°rm ~o. ~--4 R-~'V. 3-1-70 STATE q' ~dASKA OIL AND GAS CONSERVATION COMMIT[EE SUBMIT 12~ DU?LICA. TE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS NA-~E OF OPKRATOR Union 0ii Company of California* ADDRESS OF OPIKP. ATOR 909 West Ninth Avenue, Anchorage, Alaska 99501 4. LOCATION OF WF_J..J.. King Salmon Platform Leg 2, Conductor 9, 611' N & 121' W from SE Corner Sec 17, T9N-R13W f'" APl NUMER/CA.L CODE 50-133-201 71 -O1 LEASE DES:GNA%"ION AND SLqRIAI.. ~0 ADL 18772 IF I.NIDiA}~. ALO'ii-EE O1~ TRIBE 8 L.~IT FARAi OR LEASE Trading Bay Uni 9 W.EI&, .NO K-15 (12-22) l0 FIELD A_ND POOL. Otl WILDCAT McArthur River (Hemlock) Sec 22, T9N-R13W, SM Il. PEP~IIT 1X*O ~ 79-34 '13. REPORT TJTAL' DEPTH AT END OF MONT'H, CHA2qGI~S IN HOLE SIZE. CASING ANq) C~I~NT~;G JOBS INCLUDING D~t J'*/~"~:C' M ~ Monthly Report for October 1979' [~-~~ No progress has been made in establishi.ng production. Acidization and reperforation are pending for the early part of December 1979. This report has been delayed due to an oversight on our part. [CEIV!:'[) A~aska 011 Ancllo~ag~ *Atlantic Richfield Company is sub-operator. k ~ .... ' // /~-//- -~ - -_ Dist Drlg Supt ~ il 26/79 : sm~ _~ 't, ~~~~ ' =' ..... ~,- ' / N~ --Report on this form to ,equired for each calendar ~nthl regardless of tb~ flatus el operof~s, o,d must t~ filed in duplicate ~it~ the oil and gas conservofion commitlee by the 15th of the succeeding month. Document Transmittal Uni°n Oil C°mpan¥°f Cal~-~ DATE SUE~MITTED ITO H.W. KUGLER STATE DIV. OF O&G 'AT 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA TRANSMITTING THE: FOLLOWING: ~OM R.C. UNION OIL AT P.O. BOX 62z ANCHORAGE, TELEPHONE NO. STAT C( K TBU-15 RD 2" & 5" BHC-SONIC FDL - DENSITY CNL-FDL A~,~ska Oil LIBRARY TA?E FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. l'~rra No. P--4 I~'V. ~- 1-70 STATE C~.~ ALASKA / OIL AND GAS CONSERVATION CONkMI'Fi'EE SUBMVr I:N DI~. LICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. N~E OF OPERATOR Union Oil Compa,n¥ of California 3. ADDRESS OF OPE1R. ATOR 909 West Ninth Avenue, Anchorage, Alaska 99501 LOCATION OF WF_,LL King Salmon Platform Leg 2, Conductor 9, 611'N & 121'W from SE Corner Sec 17, TgN-R13W APl NL-k.'IERICA. L CODE 50-] 33-?0l 7]-0] 6 LF-~SE DESiGNA?ION AND SERIAL NO ADL 18772 7 IF INDI^)~¢. ^LO/'i-F.E O~ TRIBE 8, %,.~IT FARA{ OR LEASE NA.~E Tradin§ Bay Unit K-lB (12-22) 10 FIF. LD A_ND POOL. OI~ %VILDCA"T _ . McArthur River - Hemlock 11 SEC, T,. R.. I~l. (E~O'I"TOi~I HOL~g Sec 22, T9N-R13W, SM 12 PIgR.~IT IX'~O 79-34 13. RE/~ORT TOTAL DEPT'~ AT E.ND OF MON'i/-I, CI-I~XGES IN HOLE SIZE, CASING A~ C~TING JO~S INCLUDING DE~H SET A~ VOL~ USED, P~O~ATIONS. ~TS ~ ~SUL~ FISHING 30~S JL~K ~ HOLE AND SIDE-~ACK~ HO~ ~D ~Y O~R SIGNIFIC~T ~G~ '~ HO~ CO~ITIONS Drilled to 12,126'. Ran DIL, BHC Sonic & FDC-CNL-GR log. Finished running RFT w/16 pressure tests. Ran 7" liner and cemented w/382 sx "G" cement w/2.5% D-19, 0.3% A-2 & 1% D-31. Tested casing w/3000 psi - OK. Set RTTS tool @ 10,415' - OK. Ran CBL, spectral log & gyro. Set F-1 Baker packer in 9-5/8" casing '@ 10,345'o Changed rams & tested same - OK.. RIH w/completion assembly. Tested same & NU tree. Tested tree - OK & annulus to.3000 psi - OK.. Released rig and the well is in'process of completion. *Atlantic Richfield ComPany is the sub-operator. -' --////'/-f~;~.~-'~//~f//----~/-~ Disc Drlg Suot ~ 9/19 79 Form No. P---4 R.EV, ~- 1-70 ( STATE 01- ALAS~ OIL AND GAS CONSERVATION CON~AII-rEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2. NAME OF OP~LATOR Union Oil Company of California* 3. ADDRESS OF OPEI:~ATOR 909 W. 9th Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL King Salmon Platform Leg 2, Conductor 9, 611'N and 121'W from SE Corner Sec 17, T9N-R13W IF INDiART. ALOTT'~E O1~ APl NL'A~ER1CA.L CODE 50-] 33-20] 7] -0] LF_~SE DESIGIqATION AND ADL 18772 8. L.~IT FARM OR LEASE N.~ Trading Bay Unil g WF. LL NO K-15 (12-22) l0 FLELD .A_ND POOL. OR WIL McArthur River - Hemlock "' h SEC, T., R., M. (BOTTOM HOLE OBJECTrV~ Sec 22, T9N-R13W, SM SUBMIT IN DUPLICA~ 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA. NGES IN HOLE SIZE, CAS1NG ANT) CEI%/IF_.NTING JOBS INCLtYDING DEPTH SET A_N'D VOLT31V~S USED, PERFORATIONS, T~_..STS A/ND RESULTS FISHING JOB~ JU'ATK IN HOLE AND SIDE-T'R.ACKED HOLE AND A/~Y OTI-~R SIGNIFICANT CT:{A_N'G. ES IN HOL~ CONDITIONS Report of operations for the month of July. 1979: Commenced operation @ 0600 hrs, 7/07/79. Killed well with 9.6 ppg mud, installed BPV in tree and di"sconnected producti;on li'nes. ND tree and NU BOPE w/4-1/2" rams and tested to 3000 ps'il - OK. Retrieved existing completion stri'ng and changed to 5" rams. Squeezed 300 sx "G" cement through existing perfs with EZS¥ set @ 11,510'. Perforated from 10,870' to 10,872' @ 2 HPF and squeezed 300 sx class' "G" cement wi'th RTTS set @ 10,665' in order to obtain proper cement bond around proposed kick-off point. Section mi'lled 9-5/8', csg f/10,790' to 10,866'..(76') and spotted balanced kick-off plug w/150 sx class "G" cement. Directionally drilled 8-1/2" hole to 11,766' @ 0600 hrs, 8/01/79. *Atlantic Richfi'eld Company. is the sub-operator. -14. '1 hereby ~j~'~tt~ thaLthe I~l~ is ttue and correct DA~, --Report on fbi, form i, required for each calendar month, regardless of the -to,us of operati~'~"fil'd in' duplicote with the oil and ga. coneervotion committee by the lSth of the iucceeding month, unle~n otherwise dirocted. July 2, 1979 Re: Trading Bay Unit K-15 (12-22) RD Union Oil Company of California Permit ~o. 79-34 Sur. Loc.: King Salmon Platform Leg 2, Conductor 9, 611'N & 121'W f/SE corner Sec 17, T9N, R13W Bottomhole Loc.: 2500' S & 380' E f/5~ corner, Sec 22, T9N, R13W, SM Mr. Robert T. Anderson District Land Manager Union Oil Company of California 909 West 9th Avenue Anchorage., Alaska 99501 Dear Mr. Anderson~ Enclosed is the approved application for permit to drill the above referenced well. WelI samples, core chips and a mud log are not required. A direc- tional survey is required. If available, a tape 'containing the digitized log information on all logs shall be submitted for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject'to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal .Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification, so that we may have a witness present. Very truly yours, Hoyl~ fl. I{amilton Chairman of Alaska Oil & Gas Conservation Commission Enclosure ~ cc= Department of Fish & Game, Habitat. Section w/o encl. DePartment of Environmental Conservation w/o/encl. Department of Labor; Supervisor, Labor Law Compliance Division w/o encl. HHH/vk Union Oil and Gas Divison: Western Region Union Oil Compar~y of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unl, n Robert T. Anderson District Land Manager June 25, 1979 Mr. Hoyle Hamilton State of Alaska Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska Permit to Drill or Deepen TBUS K-15 (12-22), King Salmon Platform, McArthur River Field State Lease No. ADL-18772 Dear Mr. Hamilton: Enclosed for your approval are three (3) copies of the Permit to Drill TBUS K-15. We also enclose Arco Oil & Gas Company's check, number 078640, in the amount of $100.00 to cover the filing fees. Upon approval, we would appreciate a copy for our files. Very truly yours, sk Enclosures Form 10-401 ' REV. 1-1-71 " SUBMIT IN TR~" dATE (Other instructmns on reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK RE DRILL b. TYPE OF WELL OIL GAS DEEPEN E~] SINGLE MULTIPLE OTHER ZONE ~-] ZONE 2. NAME OF OPERATOR Union Oil Company of California* 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL King Salmon Platform At surface Leg 2, Conductor 9, 611'N f 121'W f/SE co.rner Sec 17, At proposed~'r~zene R1 3W 2500' S & 380' E f/NW corner, Sec 22,T9N, R13W, SM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approximately' 24 miles NW of Kenai API 50-133-20171-01 5. 50-133-20171 -o ~ 6. LEASE DESIGNATION AND SERIAL NO. ADL 18772 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. K-15 (12-22) /~/b 10. FIELD AND POOL, OR WILDCAT McArthur River - Hemlock 11.SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 22, T9N, R13W, SM 12. 14. BOND INFORMATION: TYPE Statewide Su,etyand/orNO. Federal 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 380' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 1900' f~,om K-17 21. ELEVATIONS (Show whether DF, RT, CR, etc.) PKB 100' MSL Insurance Co., #8011-34-40. 16. No. OF ACRES IN LEASE 1902 19. PROPOSED DEPTH 1 2 = 340 MB 23. PROPOSED CASING AND CEMENTING PROGRAM Amount $100,000 17. NO.ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR 'CABLE TOOLS 22. APPROX. DATE W6RK WILL START July 15~ 1979 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH ., Quantity of cement Existing 24" cond. Drive Pipe 384.' , Existinq 13-3/8" 61# J-55 2,401' Existing 9-5/8" 47# ~-110 & N-80. 12.421' 8-1/2" ~ 7" lin~.r ~ P-llO 12.3413 5013, SX Propose to move subsurface location. 'Mill wi'ndow i'n' 9-5/8" at 10,.790'- 10,86.0'. Lay kick-off plug and drill 8-1/2" directional hole to + 12,340' 'MD (+ 9390 TYD). Log. Run 7" liner. Set permanent packer. Run completion strin§ and complete as Hemlock producer. ,[) ','~ BOPEL 3000 psi' double gate shaffer & GH Hy.dril ~'~ ~i ~.,q E ! ~/~!'L) *ARCO Oi 1 and Gas Co'mpany i's sub-operator. IN ABO~ SPACE DESCRIBE PRO~SED PROGRAM: If propo~l is to deepen give data on present productive zone and proposed new Emductive zone. If E~0po~l is to dr~ or deeEen dkection~y, ~ve pertinent data on subi~face locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby certify that ~e and Cof~ect SIGNED "~"~~'~ '~~/~~)~// DATE (This space for State office use) _ ]~ F ~NDITIONS OF APPROVAL, IF ANY: SAMPLES AND CORE CHIPS REQUIRED [ MUD ~G OTHER REQUIREMENTS: I DYeS ~o ~ ~ES ~.o DIRECTIONAL SURLY REQUIRED. A.P.I. NUMERICAL CODE ~Y~S ~ NO TITLE District L~nd Mgr. PERMIT NO. APPOVED BY 7f'-S/V APPROVAL DATE July 2, 1979 ~ ~ TITLE ~ DATE P.:,¥ Cvs:: ~' ~,~, ..... i, .......... *See Instruction On Reverse Side Z O0~c o CHECI( LIST FOR NE~q ~]SLL PERMITS Is the permit fee attached .......................................... o J 101 11. O~npany Yes No Remarks Is well to ~e located in a defined pool ............................. ~ at . ' O~ 4. Is roll located proper distance rrm propor~ Ii.no ............. 6. Is sufficient underdicated acreage available in this pool ..... well to 1~ deviated ........................... , 8 Is operator the only affected party · ' ~~ permit be approved before ten-day mit ' ' ~_~ · · Does operator have a hond in force Is a conservation order need°d ...... , ............................... 12. administrative approval needed' Is eeoooooeooooooeoooooeoooo*o*,,oe*o- Is conductor string provided oooooooooooeoooeeooooooooooooooeoeoooooo Lease & Well-No. Item Approve 13. i4. Is enough cement used to circulate on conductor and surface ......... ~/gP '(2) Loc.~ (3) Admin./~.~ ":~~i,~ill cement tie in surface and fntermediate or production strings,... known productive horizons F~ 16. ~il 1 cement covor al. 1 ..................... 17' Will surface casing protect fresh ~ater zones .................... ,.. ~/1~ Additional Requirements: Will all casing give adequate safety in collapse, tension and burst.. DOes BOPE have sufficient pressure rating - Test to 3 ~ o psig .. Approval Recommended: Geology: Engineering: HWK ~/~-,3/c~ LCS BE%; ..... ~r~ Well Histow File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPEN. DIXi No special'effod has been made to chronologically organize this category of information. t!¸ i 1..11 llJi .l 1 11 11 11.11 .111.1 il 1! 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