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Home My WebLink About197-235 al 3 �- rr - To O OA U 6' _( Q „ a l" W�uJ 0 v 3 (z o a fl y n O w CU a) o Q Y O C r e- e- r• e- e- e- e- e- Q) cotD, ~ cc O co p a r . V 0. U v) > E •r% .2 F 0 ro r9 0- Q Q W O O CO t0 CO CO CO no O -D N �] (J e- e- O . . . . . f0 L U O L J ..J �' C C C C C C 7_ N O '-' 41/3 -+ N H - f. 7 5 7 7 7 3 7 7 v, C C rq CO co co ON Z''' I-, N e- e- N N CU Q CU ZQ G O 'D E O >- U V F•- 4J > L 'D fa i' Ca) 4-. co O 000000010 , v u 'c 0- a J J J J J J J J J ..J >, WW bi) c (13O .-+ F- LL LL LL LL LL LL LL LL LL a1 E -O N O Q J J J J J J J J J a 0 C CU tO F Q Q Q Q Q Q Q Q Q C Z o) <c Z Z Z Z Z Z Z Z Z T v p� vY�. am. LL LL LL LL LL LL LL LL LL cu 0 O W K a1 0 O C `- y E al O O O p c o _Q c a - 1-, i.•- r� a) a) C C K O 'Cu O ~ c `>° c a) •- v LL Q a, C U > I- /me O 0 a C Q n ce LL a wp d 10 J Baaaaoapm \ to . K CO U 4. U U ix U j g H p ,) .2 a ` N U w T s a) n. 1i (4 '" C' z R! ay W O ` I W U a. 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Supervisor ~ ~% 6 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 D-109 FROM: Bob Noble KUPARUK RIV U WSAK 1D-109 Petroleum Inspector Src: Inspector N(lN_~(1NFi>nF.I~TTi AL Reviewed By: P.I. Suprv ~I~- Comm Well Name: KUPARUK RIV U WSAK 1D-109 mitRCN100718135215 Insp Num: Rel Insp Num: API Well Number: 50-029-22842-00-00 Permit Number: 197-23s-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ID-IO9 ~ Type Inj. N' TVD 3sso IA Io lobo - Ibso I6~o P.T.D 19723s0 I TypeTest SPT Test psi I76o OA Interval aYRTST p/F P Tubing i Iozs Io2s Iozs lots ~ _ Notes: l,4;~ r~ r~~ G~ -{~~-- rS~P ~" _ ~~ar Thursday, July 22, 2010 Page 1 of 1 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 23, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Shut-in Bottom Hole Pressure: 1D-109 Run Date: 7/30/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wire line Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D-109 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22842-00 NE-.L;NO 2 7 200s PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wire line Perforating Attn: Rafael Barreto 6900 Arctic Blvd. 9q '433— Anchorage, Alaska 99518 U Office: 907-273-3527 J` Fax: 907-273-3535 rafael.barretoela440 NOV o 5 7009 Date: Signed: ,ut leer To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 10D Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MTTJ The technical data listed below +s being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal let~er to the following : ProActive Diagnostic Services, lnc. Attn: Robert A. Richey 130 Wes~ Iriternational Airport Road Suite C Anchorage, AK 9951$ Fax: (907j 245-8952 'i j Caliper Report 27~1un-09 7 D-107 1 Report / EDE 50-029-22983-00 2) Caliper Repor~ 29-Jun-09 1 D~109 ~.r Ca ~c~ - 1'3~'~- U~ ~ l~~ l ~35~- ,~ Signed : l °~~~~ Print Name: 1 Rsport / E~ 50-029-22842-00 ~~~'~~#'~'~~~ ,;~:if .: ~~ ~G(1~ Date _ PROACTIVE DIAGNOSTIC SERVICES, )NC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 F,vc: (907)245-88952 ~-MAIL : _ - ~UEBSITE : ~ C:~Doctm~en)s and Settings\Ownef~Desk[op\Transcnit_Conoco.docx 1 ~ ' ~ i ~ Memory 11~utti-Fing~r Gatiper 5 Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1D-109 Log Date: June 29, 2009 Field: West Sak Log No. : 7338 State: Alaska Run No.: 2 API No.: 50-029-22842-00 Pipe1 Desc.: 3.5° 9.3 Ib. L-80 ABM-~UE Top Log Intvi1.: Sut'face ~I Pipe1 Use: Tubing and Production Casing Bot. Log Intvl1.: 4,228 Ft. (MD) ' Inspection Type : Corrosive & Mechanical Dama~e inspection ' COMMENTS : This caliper data is tied into the W-1 Nipple @ 4,080' (Ori/ler's Depth). This log was run to assess the condition of the tubing and productian casing with respect to corrosive and ' mechanical damage. The caliper recordings indicate the 3.5" tubing and production casing logged are in good to poor condition, with a maximum recorded wali penetration of 59°k recorded in a line of corrosion in joint 79 (2,503'). Wall penetrations from 20°~ to 58°~ wall thickness are recorded in 96 of the 140 joints ' logged. Reeorded damage appears as a line of pits from -954' to ~1,940' and a line of corrosion from -1,940' to 4,228' (EOL). No significant areas of crass-sectional wall loss or I.D. restrictions are recorded throughout the tubing and production casing logged. ' The caliper recordings indicate slight buckting from --2,800' to --3,950'. This is the second time a PD5 caliper has been run in this well, and the 3.5" tubing and production casing have been logged. A compari5on of the current and previous lag (August 15, 2005) indicates an increase in , corrosive damage, appearing as isolated pitting from -700' to -950' and a line of pits from ~950' to ~1,750' during the time between logs. A graph illustrating the diffe~ence in maximum recorded penetrations on a joint-by jaint basis between th~e current and previous log is included in this report. The decrease in maximum ' recorded penetrations from -1,750' to 4,228' (EOL) in the included comparison graph appears to be due to the caliper fingers not tracking the same magnitude of damage in the current log as the previous log. 3.5" TUBING ~ CASING - MAXIMUM RECORDED WALL PENETRATIONS: ' ~ine corrosion { 59%) Jt. 79 ~ 2,503 Ft. (MD) Line corrosion ( 56%) Jt. 130 @ 4,164 Ft. (MD) Line corrosion ( 56%) Jt. 96 ~ 3,023 Ft. (MD) 1 Line corrosion ( 53%) Jt. 107 (~D 3,379 Ft. (MD) Line corrosion ( 51°r6} Jt. 128 ~ 4,058 Ft. (MD) 3.5" TUBING ~ CASING - MAXIMUM RECORDED CROSS-SECTfONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 6°~) are recorded throughout the tubing and production casing 1o99ed- 3.5" TUBING 8~ CASiNG - MAXIMUM RECORDED ID RESTRICTIO(dS: No significant L D_ restrictions are recorded throughout the tubing and produetion casing logged. ',' Field Engineer: Wm_ McCrossan Analyst: C. Wa/drop Witness: C. Fitzpatrick ProRctive Diagnostic Services, Inc. / P.O. Box i:i69, Stafford, TX 7749? Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDSlamemoryiog.com I Prudhoe Bay Field Office Phone: (907) 659-2307 Fax; (907) 659-2314 ' 1 -~ ~ ,~~.- a~s- ~_ • Correlation of Recorded Damag pe 1 3.5 n(36.6' - 4210.2') Well: F eld: Company: Country: Survey Date: • ;e to Borehole Profile 1 D-109 West Sak Conoco h Ilps Alaska, Inc. USA June 29, 2009 ^ A pprox. Toot Dev at on ^ A pprox. Borehol e rof l e 1 39 10 341 2(1 - _~-~ 656 3t) 965 q0 ~, - 1277 50 \~~' 1589 ~ ~ 6(1 " ~ 1903 ~ a, ~ ~ ~ c Z 70 ~ 2212 y c a- w o . ~ t30 ~ 2520 9t) 2828 100 .. 3138 11U 3452 12l) ~ 3762 GLM 1 130 4147 132 4210 0 5 0 1 00 Da mage rof le ( % wall) /Tool D ev at o n (c~gr ees) Bottom of Survey = 132 • • Maximum Recorded Penetration 1. ~., Comparison To Previous Well: 7D-109 Survey Date: June 29, 2009 Field: West Sak Prev. Date: August 15, 2005 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 No. 218370 CounVy. USA Tubing: 3S 9.3 Ib L-80 ABM~UE Overlay 0 5 Max. R 0 1 ec. Pen. (mils) 00 150 2 00 25 0 0.1 7 17 27 37 _ 47 - 57 ~ i ~ Z 67 e ' S _ ~~ 87 97 107 117 127 129.4 ^June 29, 2009 ^August 15, 2005 Difference Di ff. in Max . Pen. (mil s) -100 -5 0 0 5 0 100 ' T-_, 17 I i , 27 37 '; 47 ~ ~ ; I ---- Z j 67 - -- ' s , -- ~ i 77 i ~ i 87 97 107 1}7 127 129.4 i -26 -1 3 0 1 3 26 Appro ~c. Corrosi on Rate (m py) • • _ __ _ PDS Report Overview 1 ~. Body Region Analysis Well: 1 a109 Survey Date: June 29, 2009 Field: West Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. o( Fingers: 24 Anal sh C. Waldro - P - ---- Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 ABM-EUE 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°~ wall) ~ penetration body p~ metal loss body 150 100 50 ~ 0 to 1 io 10 to 20 ro 40 to over 1% 10% 20% 40"/0 85% 85% Number of ~oints anal sed total = 140 pene. 0 23 17 63 37 0 loss 39 101 0 0 0 0 Damage Configuration ( body ) 80 60 40 ZO U isolated general line ring hole / poss pitting cormsion corrosion corrosion ible hole Number of'oints dama ed total = 107 33 0 74 0 0 Damage Profile (% wall) ~ penetra6on body ~ rrietal loss body 0 50 100 0 47 97 GLM 1 Bottom of Survey = 132 Analysis Overview page 2 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEET 1 D-109 West Sak ConocoPhillips Alaska, Inc. USA June 29, 2009 Joint No. Jt Depth (Ft.) I'~~n. UE~se~t Iln~.) Pen. Body (Ins.) Pen. % Metal I~~ss "~~ Min. I.D. (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 37 U 0.02 ~) 2.90 PUP 1 39 ~~ 0.04 1 S 5 2.92 1.1 69 ~! 0.01 6 1 .94 PUP 1.2 79 ~~ 0.02 £3 tl 2.92 PUP 1.3 82 t~ 0.02 ~) I 2.88 PUP 90 i~ 0.02 I 2.95 3 1 1 i~ 0.02 t3 I 2.93 4 153 ~~ 0.03 1,? I 2.94 5 184 ~~ 0.02 ~? 2 93 6 215 U 0.02 ~i .! 2.91 7 246 U 0.01 E~ I 2.94 8 278 ~~ OA2 9 1 .93 9 309 ~~ 0.02 9 ~ 2.94 10 341 (~ 0.01 (; 1 2.94 11 372 ~~ 0.02 ~~ ~' 2.93 12 404 ~~ 0.02 ~ 1 2.94 13 435 U 0.03 1_' 2.93 14 467 O 0.03 1O ,_' 2.94 1 S 498 ~ 1 0 02 8 ' .93 16 530 t~ 0.02 8 i 1 2.93 17 561 t~ 0.02 ~~ 2.92 18 593 t~ 0.02 7 I 2.93 19 624 u 0.02 9 u 2.91 20 656 ~l 0.04 1 ~ 1 2.91 21 687 t) 007 _'- I 2.94 Isolated ittin . 22 718 U 0.02 ~) I 2.93 23 749 U 0.04 15 1 2.93 24 780 t~ 0.05 19 ,' 2.92 Isolated ittin . 25 812 U 0.06 22 1 2.93 Isolated ittin . 26 843 il 0.07 2(i I 2.90 Isolated ittin . 27 872 ~~ 0.03 10 ~1 2.92 28 903 ~~ 0.06 24 1 2.93 Isolated ittin . 29 934 U 0.07 Zti ' 2.93 Line of its. 30 965 (1 0.05 _' 1 ' 2.91 Line of its. 31 996 l) 0.07 2t3 I 2.91 Line of its. 32 1026 l~ 0.04 17 1 2.92 33 1058 (~ 0.07 26 ~ 2.91 Line of its. 34 1089 (~ 0.07 1F3 1 2.91 Line of its. 35 1120 ~~ 0.07 Z~) _' 2.92 Line of iis. 36 1152 ~~ 0.07 Z7 1 2.91 Line of its. 37 11 3 i~ 0.06 ~~Z _' 29 Line of its. 38 1214 ~~ 0.07 '~~ ' 2.93 Line of its. 39 1246 U 0_05 I~) 2_95 Line of its. 40 1277 U 0.07 ~Ei 2.94 Line of its. 41 1309 t~ 0.05 <' 1 ~' 2.92 Line of its. 42 1340 l1 0.06 22 1 2.93 Line of its. 43 1372 ~~ 0.05 21 I 2.93 Line of i. 44 1403 i~ 0.07 ~'8 1 2.92 Line of its. 45 1434 ~~ 0.06 15 ? 2.91 Line of ~its. 46 1466 u 0.07 2' ? 2.92 I ine of its. ~ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: Body Wall: 0.254 i~ Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • i LATI O N S H EET 1 D-109 West Sak ConocoPhillips Alaska, Inc. USA June 29, 2009 Joint No. Jt. Depth (Ft.) f'en. UF~sc~1 (Ins.) Pen. Body (Ins.) N~~n. %~ vtc~t.~l I~~ss ,~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 47 1497 U 0.05 I~I I 2.93 ine of its. 152 u 0.05 1~) .93 Line its. 49 1559 U 0.08 31 2.92 ine of its. 50 1589 ~t 0.05 ?U 1 2.93 li of its. 51 1621 U 0.06 2~ 1 2.91 Lin of its. 52 1652 l1 0.10 4l1 ? 2.9 i of its. 53 1683 ~! OA lb I 2.93 ~ e of its. 54 1715 ~1 U.07 ~£f ~' .92 Lin of its. 55 17 6 u 0.05 19 I 92 ine of its. 56 1778 ~~ 0.05 1(3 1 2.93 ine of i. 57 1809 ~~ 0.0 17 1 2.93 58 1841 U 0.06 24 I 2.93 i of its. 59 1872 ~) 0.03 11 t) 2.90 60 1903 ~~ 0.04 I; I 2. 1 61 1935 O.(~ti 0.1 ~+ 2 2.93 Line corrosion. 62 196 U 0.08 31 2 2.93 Line rrosion. 63 19 S l) 0.08 i 1 ~ 2.9 Lin corrosion. 64 2024 ll 0.08 3O ~_' 9 ine corrosion. 65 2 SS l1 0 08 ~; ' .92 Line corrosion. 66 087 t~ 0.07 <(, 2.93 Line rrosion. 67 2118 t~ 0.09 ~; .92 Line corrosio~. 68 2149 t 1 0.0 3 ~ 2.94 Line c rro i n. 69 2180 ~~ 0.11 ~-1 _' 2.93 Line c rrosion. 70 2212 ~1 0.10 al~ 4 2.92 Line wrrosion. 71 4 ~~ 0.1 47 2.9 ine rr sion. 72 2271 U 0.12 4~) _' 2.92 Line corrosion. 7 303 ~) 0.11 4Z i 2.94 in corrosion. 74 2334 t1 0.11 43 ' 2.89 Line corrosion. 75 2364 l? 0.11 44 f .9 Line corrosion. 76 2396 (~ 0.10 ~1O 3 2.92 Line corrosion. 77 2427 ~~ 0. 9 ~4 2 2.92 ine corro ion 78 2458 ~~ 0.11 -14 2 2.92 Line corrosion. 79 2489 (~ 0.75 i~> 3 2.92 Line corrosion. SO 2520 U 0.09 3(~ _' 2.92 Line corrosion. 81 2550 U 0.10 4U ~~ 2.91 line corrosion. - 82 2581 ~ 1 0.12 48 ~ 2.93 Line corrosion. 83 2613 U .09 35 ~ 2.92 ine corro ion. 84 2643 (l 0.10 ~1 3 2.94 Line corrosion. 85 2675 U 0.08 s0 ~~ 2.93 Line corrosion. 86 2705 U 0.08 t, 2.93 Line corrosion. 87 27 7 O 0.08 ~ I ~3 2.93 Line corr sion. 88 2768 t~ 0.09 34 ~ 2.92 Line corrosion. 89 2797 U 0.09 3 i ~ 2.92 I..ine c.orrosion. Sli ht Buc in . 90 2828 U 0.12 47 s 2.93 Line corrosion. 91 2860 ~) O10 i9 3 2.9 i e rrosion. 92 289i ~~ 0.10 ~t3 t 2.92 Line corrosion. 93 2922 U 0.10 ~~) _' 2.93 Line rrosion. 94 2954 i ~ 0.08 ~~ a 2.93 Line corrosion. - 95 2985 ~~ 0.1 1 -l i 2.93 ine corrosion. Sli ht Bucklin . 96 3017 U 0.14 56 -1 2.92 Line corrosion. PeneUaUon Body Metal Loss Body Page 2 ~ PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEET 1 D-109 West Sak ConocoPhillips Alaska, Inc. U5A June 29, 2009 Joint No. Jt. Depth (Ft) f'~~n. t1F~.c~t ~In. ;~ Pen. Body (Ins.) Pen. °~ ~1ct,al Los, °~~~ Min. I.D. Qns.) Comments Damage Profile (%wa{I) 0 50 100 97 3047 i~ 0.10 3t~ (i 2.92 Line corrosion. 98 3078 ~~ 0.10 ~1 3 2.91 ine corros'on. 99 3107 ~~ 0.11 41 -1 92 Line r sion. 100 3138 u 0.11 41 ~3 2.91 I.ine co rosion. 101 3 V0 ~? 0.11 ~ i ~ 2.92 Line corrosion. 02 201 l1 0.12 4~? 4 2.94 Line co rosion. Sli t Bucklin . 103 3233 n 0.10 41 2.93 Line corrosion. 104 3264 ~~ 0.10 ~~ 2.93 Line corrosion. 105 3296 ~~ 0.10 ~I 2.92 Line corrosion. 106 3326 i~ 0.0 37 -1 2.92 Line corrosion. 107 3358 l~ 0.13 5 3 -l .93 Line corrosion. 108 3389 l) 0.11 44 ! 2.93 Li e corrosion. Sli ht BucMin . 109 3420 l) 0.10 41 ~3 2.93 Line corrosion. 110 3452 ~~ 0. 0 41 -~ 2.92 Line corrosion. 111 3483 t~ 0.1 ?U Z .91 ine corrosion. 112 3514 ~~ 0.1 ~~4 ~ 2.9 Line corro ion. 113 3546 (~ 0.11 ~ s 2.92 Line corrosion. Sli ht Bucklin . 114 3576 U 0.11 4.i S 2.92 I.ine cor osion. 115 3607 ~~ 0.09 i 7 -1 .92 Li e corrosion. 116 3639 ~1 0.12 46 -1 2.92 Line rosion. 1 7 3670 ~) 0.12 46 .92 L'ne corrosion. 118 3702 U 0.10 4(1 _' 2.93 Line corrosion. 119 3732 l~.t~(~ 0.12 4t3 ~ 2.93 in corrosion. 120 376Z U 0.07 29 3 2.93 Line corrosion. Sli ht Bucklin . 121 3793 U 0.10 41 ~ .91 Line rrosi n. 122 3825 U 0.12 4£~ ~~ 2.93 Line corrosion. 123 3856 U 0.08 3~? 3 2.93 ine corrosi n. 124 3887 u 0.08 > 3 s 2.92 Line corrosion. 1 5 3919 U 0.09 34 _' .92 Line c.orrosion. Sli ht Buc,klin . 126 3950 t) 0.09 37 ? 2.92 Line corrosion. 127 3982 t 1 0 1 4~ ; 2.91 ine co rosion. 127.1 4012 ~~ 0.04 3' 4 2.93 PUP Line corrosion. 127 2 4027 O 0 l1 U N A GLM 1 Latch @ 1130 1273 4D33 u 0.08 iO -1 2.95 PUP Line corrosion. 128 4049 ~~ 0.13 ~il i 2.91 Line corrosion. 128.1 4080 U 0 t) ~) 2.81 W-1 Ni le 1 9 4082 t~ 0.11 -~:i 3 2.91 Li e corrosi n. 129.1 4113 ~1 0.04 1~ 5 2.94 PUP 129.2 4119 l1 0 U t) 3.00 Baker G H-22 Seal Assembl 129.3 4132 c) 0 t) I) 3.00 Baker Seal Bore Extension 129.4 4141 ~~ 0.02 ~) Z 2 92 PUP To f 3. " Production C sin . 130 4147 I) 0.15 it3 ~ 2.92 Line corrosion. 131 4179 c) 0. 0 ~~) t .92 Line corrosion 132 4210 ~~ 0.08 i I ~' 2.94 Line corrosion. ~ Penetration Body Metal Loss Body Page 3 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~c~ PDS Report Cross Sections Well: 1 D-109 5urvey Date: )une 29, 2009 Field: West Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin : 3.5 ins 9.3 f L-80 AB~~t-EUE Anal st C. Waldro Cross Section for Joint 79 at depth 2503.11 ft Tool speed = 42 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wail area = 98 % Tool deviation = 40 ° Finger 21 Penetration = 0.15 ins Line corrosion 0.15 ins = 59% Watl Penetration HIGH SIDE = UP ~ ~ Cross Sections page 1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ! ~c;~ PDS Report Cross Sections Well: 1D-109 Survey Date: June 29, 2009 Fie-d: 4Nest Sak Tool Type: UW MFC Z4 No. 218370 Company: ConocoPhiliips Alaska, Inc. Tool 5ize: 1.69 Country: USA No. of Fingers; 24 Tubin : 3.5 ins 9.3 f L-80 AB~b1•EUE Analyst: C. Waldrop Cross Section for Joint 130 at depth 4164.07 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 98 % Tool deviation = 21 ° Finger 4 Penetration = 0.148 ins Line corrosion 0.15 ins = 58°~ Wall Penetration HIGH SIDE = UP • II ~ Cross Sections page 2 . ConocoPhillips ~~.~,... , ~ GAS LIFf. 4.028 NIPP~E. 4.080 S~xlace nlie~il C DP orieni ~n~ae., NI_I)G 4 565 8l4/1 pfJB PLVG, ~ 4.761 SHOE. 4,831 ~ RoUwtion TD, 4 835 06/08/07 Schlumbel'gep NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SCANNED JUN 1 4 2007 Company: Alaska Oil & Gas Cons Comm Atln: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ], 200l ~v '" ,-...._~..;.~........~. ....., Field: Kuparuk Ù:CC- tq-g--~~ Well Job# Color Log Description Date CD BL 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROF/LDL 05/10/07 1 2G-11 11638863 PRODUCTION PROFILE 05/05/07 1 1 C-125 N/A MEM INJECTION PROFILE 05/05/07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05/04/07 1 2G-09 11638864 PRODUCTION PROFILE 05/06/07 1 2N-349A 11629004 RST/ WFL 05/04/07 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 1Q-10 11628771 MEM PRODUCTION PROFILE 05/03/07 1 11:;-11 ~ _. 11629012 INJECTION PROFILE 05/14/07 1 lito. vr \J \. 11665439 US IT OS/25107 1 i\l!08A 11629013 PMIT 05/15/07 1 1J-160 11632704 PRODUCTION PROFILE 03/19/07 1 1H-07 11665436 SBHP SURVEY OS/20/07 1 2F-11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1B-01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05/15/07 1 2Z-29 11665438 PRODUCTION PROFILE OS/22/07 1 1 H-22 11637339 INJECTION PROFILE 05/16/07 1 1 Y -11 11632708 INJECTION PROFILE OS/23/07 1 1G-03 11637336 INJECTION PROFILE 05/14/07 . 1 1A-23 11665443 MEM PRODUCTION PROFILE OS/29/07 1 1F-08 11665435 SBHP SURVEY OS/20/07 1 1J-170 11632709 INJECTION PROFILE OS/24/07 1 1D-109 N/A INJECTION PROFILE 05/13/07 1 2M-24 11665440 SBHP SURVEY OS/28/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . y ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 A 1:: CEil V 'ED J.A tV (Ì ~ÞDo7 December 29, 2006 SCANNED JAN 1 6 2007 l\IIr. Tom Maunder Alaska Oil & Gas Commission 333 \-Vest 7th Avenue, Suite 100 Anchorage, AK 99501 6 '"'''ð--~ \C\ ' Dear l\IIr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were fIrst fIlled with cement to a level of approximately 1.0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG2401 that was engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on December 16, 2006 and the sealant top was completed on December 27,2006 for 1H-Pad and December 28, 2006 for 1D-Pad. Schlumberger Well Services mixed 15.7 ppg Expando cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The 2401 sealant was pumped in a similar manner. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or M.l Loveland at 907-659-7043, if you have any questions. Sincerely, ~-/cD~ Jerry Dethlefs ConocoPhillips Problem \-Vells Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 12/29/2006 Initial Top Cement Final Top Sealant Well Name PTD# of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date 1 H-01 193-006 12" na 12" na 7.4 12/27/2006 1 H-02 193-008 21'4" 2.9 14'6" 12/16/2006 na na 1H-10 193-030 4' na 4' na 29 12/27/2006 1 H-11 193-036 Surface na Surface na 1 12/28/2006 1 H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1 H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1 H-18 193-020 14'4" 2.7 12" 12/16/2006 7.4 12/27/2006 1 H-21 193-046 4" na 4" na 2.4 12/27/2006 1 H-401 198-101 45' 4.4 18" 12/16/2006 20.1 12/27/2006 10-109 197-235 10'9" 2.1 12" 12/16/2006 10.8 12/28/2006 1 0-11 0 200-039 8'6" 1.4 10" 12/16/2006 9 12/28/2006 1 0-111 198-166 17'7" 3.4 25" 12/16/2006 21 12/28/2006 1 0-120 197-221 13'6" 2.9 18" 12/16/2006 16 12/28/2006 10-121 197-181 13' 2.2 20" 12/16/2006 16.2 12/28/2006 10-132 198-121 10'8" 2.0 14" 12/16/2006 11 12/28/2006 10-133 197-206 6' 1.0 6" 12/16/2006 4.6 12/28/2006 10-136 200-046 10' 2" 2.0 10" 12/16/2006 6.4 12/28/2006 10-137 200-047 11 ' 2.00 24" 12/16/2006 13.2 12/28/2006 1 0-138 200-048 11' 7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 10-139 200-049 11' 2" 2.2 18" 12/16/2006 9.9 12/28/2006 1 0-140 200-136 29'9" 3.4 12" 12/16/2006 na na (j JJ--------- 01/02/07 Schlumbepgep NO. 4092 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ......JiÇANNED JAN 082007 ,( J \, "'; ~ ;~:i ~ !,~ >"<":;. ':J : - U]::CL lC\-q~éß5 Field: Kuparuk Well Log Description Date Color CD BL Job# 2N-304 11416232 FBHP SURVEY 10/30/06 1 2N-304 11296737 FBHP SURVEY 11/04/06 1 10-109 N/A INJECTION PROFILE 11/27/06 1 1J-136 (REDO) 11534188 USIT 12/10/06 1 1R-18 N/A SBHP/DD 12/18/06 1 1G-16 11551836 INJECTION PROFILE 12/19/06 1 1D-103 11548555 INJECTION PROFILE 12/20/06 1 3K-09A N/A SBHP SURVEY 12/22/06 1 3K-26 N/A SBHP SURVEY 12/22/06 1 3K-18 11551838 SBHP SURVEY 12/23/06 1 2N-326 11551840 SBHP SURVEY 12/24/06 1 3S-19 11548564 PRODUCTION PROFILE 12/25/06 1 2M-10 11551841 PRODUCTION PROFILE 12/25/06 1 2M-16 11551842 INJECTION PROFILE 12/26/06 1 2A-20 11548565 INJECTION PROFILE 12/26/06 1 2M-15 11551843 PRODUCTION PROFILE 12/27/06 1 2M-22 11538773 PRODUCTION PROFILE 12/28/06 1 1J-184 11538775 PRODUCTION PROFILE 12/30/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . e e «MIT KRU 1D 10-22-06.xls» «MIT KRU 1J 10-22-06.xls» All, One thing to note regarding the 1 J data is that all three wells are currently on a vacuum thus the tubing pressure is listed as zero. If you have any questions let me know Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com KRU ID Content-Description: MIT KRU ID lO-22-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 KRU IJ Content-Description: MIT KRU 1J lO-22-06.xls Content- Type: applicationlvnd.ms-excel Content-Encoding: base64 K.:'r,,,~&.'C[J) \;}\J6'~ ~,f¡1!J~ o 7 2005 . of 1 10/30/20069:14 AM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk / KRU /10 1 0/22/06 Greenwood 1 Noble Jeff Jones , (,)'1",&35 /, \\) ~ \ 0 q L Packer Depth Pretest Initial 15 Min. 30 Min. Well1D-109 I Type Inj. I W TVD I 3,550' Tubing 1000 950 950 950 Inlerval 0 P.T.D.!1972350 I Type test I P Test psi! 1500 Casing 750 1900 1875 1875 P/F P Notes: Post csg repair under sundry approval 306-094 OA NA NA NA NA Weill 1 0-120 I Type Inj. I W TVD 3,591' Tubing 925 925 925 925 Interval I 0 PT.D.!1972210 I Type lest I P Test ps; 1500 Casing 0 2240 2155 2150 P/F P Notes: Posl csg repair under sundry approval 305-227 OA NA NA NA NA Weill I Type Inj. I TVD I Tubing Interval p.T.D.1 I Type lest I Test psi I Casing P/F Notes: OA Weld Type Inj. TVD Tubing Interval I P.T.D.! I Type test I Test ps; Casing P/F Notes: OA Well! I Type Inj. I TVD ! TUbing Interval I P.T.D.! I Type test I Test psi! Casing P/F Notes: OA . Weill I Type Inj. I TVD I Tubing Interval I p.T.D.1 I Type test I Testps; Casing P/FI Notes: OA Weill I Type Inj. I TVD I Tubing Interval I P.T.D, I I Type test I Test psi! Casing P/F Notes: OA Weill I Type Inj. I TVD I Tubing Interval P.T.D.I I Type test I Test ps; Casing P/F Notes: OA Weill I Type Inj. I TVD I Tubing Interval p.T.D.1 I Type test I Test psi! Casing P/F Notes: OA D = Drilling Waste G = Gas = Industrial Wastewater N = Nollnjecting W = Water MIT Report Form BFl 9/1/05 M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT KRU 10 10-22-06.xls . ~illips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED August 12, 2006 AUG 1 5 ¡[JUb Alaska Oil & Gas COO" C '. ...., omm!SSlon Anchorage Mr, Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 i11,.,::f~ ".\) ,,,",,j \_1 Dear Mr. Maunder: Enclosed please find a 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. welllD-109 (PTD 197-235). The report is regarding surface casing repairs. Please call me at 659-7043 or Marie McConnell or Perry Klein at 659-7224 if you have any questions. Sincerely, ~~s~ Problem Well Supervisor Attachments . . RECEIVED AUG 1 5 2006 0"1 a I & G!.I. ('"ft. " 1. Operations Performed: Abandon 0 Repair Well 0' Plug Perforations 0 Stimulate 0 OtherAnCho~e Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension Change Approved Program 0 Ope rat. ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 197-2351 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22842-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 111' 10-109 8. Property Designation: ~» 8, /(".0(. 10. Field/Pool(s): Kuparuk River Unit AþL .J$""S-i> Kuparuk River Field 1 West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 4850' feet true vertical 4240' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' PRODUCTION-tapered 4009' 5-1/2" 4120' 3550' PRODUCTION-tapered 715' 3-1/2" 4835' 4335' Perforation depth: Measured depth: 4238 true vertical depth: 3661 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 4120' MD. Packers & SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubina Pressure Prior to well operation NA Subsequent to operation NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilO GasO WAG 0 GINJO WINJ0 . WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 306-094 Contact MJ Loveland / Marie McConnell Printed Name drry Dethlef~ Title Problem Well Supervisor ~0¿ Signature ---- ~~ C- ./-/ Phone ~ 5? -? 0 f?.3 Date /' I" C-/ ·~r· STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TION& Form 10-404 Revised 04/2004 OR \ G \ N A ~ BfL AUG 1610116 ~ll'.' ~D 8' ~ sUb~~)'~d . 1 D-1 09 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 7/28/2006 Conductor Removal - Initial T/I= SilO Rigged up N2 and purged the IA. Cut and removed a 12"x24" window into the conductor @ 5 ' 6" down from the top of the mandrel hanger. The welders then removed 10' 9" of the conductor from the top of the mandrel hanger. Final T/I= SilO. Put vac truck on 24 hr till conductor installed. 7/29/2006 Find leak @ 1'. Welders cut 13" more off conductor (11' 10" total conductor removed) to expose better SC for patch. Buff + mark areas for UT. Install 2" hose in conductor for vac trucks (fluid seepina up in conductor). AOGCC inspector John Crisp witnessed damage. 8/8/2006 Install SC Patch, Initial T/I= SilO, Purged the IA with N2, while Cooper heat brought mandrel hanger up to temp. Continued the purge as the welders installed wedding bands and seal welded mandrel hanger to mandrel hanger pup. UT top sealweld and bottom wedding band weld with good results. Install and weld 126" SC patch made from 6" .280 wall thickness 5L- X65 pipe. 8/9/2006 MITIA (passed) post IA weld patch job. Installed VR plug re-installed annular jewlery. T/I=SIIO. Pumped a total of 1 bbl diesel down IA. Started with 1000 psi monitor for 10 min. Pressured to 2000 psi monitor 10 min. Pumped to 3010 psi. Start MITIA, initial psi 3010 psi, 15 min psi 2960, 30 min psi 2950, 45 min pressure 2950, 60 minute psi 2950. Patch had no leaks. Bled down IA to 0 psi, secured well. Final TII=SI/O. Wrap new SC patch with Denso wrap tape from 12" below bottom weld of patch up to mandrel hanger. 8/10/2006 Weld new 16" 0 x 129" L conductor in place. Conductor now has a 4" cement circulating nipple located 12" down from top of conductor. New conductor was fabricated using 62.5# API 5L Gr B conductor casing with a machined groove. MECHANICALlrEGRITY TEST (MIT) FORM. WELL NO.: 110-109 I DATE: 18-9-06 WELL TYPE: IIN J I i,e,: Prod, Prod AIL, MI, SWI, PWI MIT TEST TYPE: IIA I i.e., Tbg, IA /9-5/8", OA 113-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE: 13000 1 psi. Note: Please consult the PWS if there's any question @ 7224, pager 909. FLUID TYPE(S) USED TO PRESSURE TEST: IDIESEL R d II W IIh d P b f d d . T t ecor a e ea ressures e ore an unnq es. STARTTIME:110:00 PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** (PSI)* (PSI)** FAIL S TUBING SI 81 SI SI SI SI T IA 0 3010 2960 2950 2950 2950 Pass OA NIA NIA NIA NIA NIA NIA 1 COMMENTS: START TIME: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** (PSI)* (PSI)** FAIL 5 TUBING T IA OA 2 COMMENTS: START TIME:I PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI) (PSI) (PSI)* (PSI)** FAIL S TUBING T IA OA 3 COMMENTS: rSC COMMENTS * Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min 45 and 60 minute readings for extended tests only FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! m·· FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION m -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. m -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. W"t IROGERS/FERREIRA I ness: . cc: PWS 6/3/00 ConocoPhiHips Alaska, Inc. ID-I09 Surface Casing Repair e e WELL LOG TRANSMITTAL PRoActiVE DiAGNOStic SERvices, INC. To: AOGCC. Attn: Ceresa Tolley 333 West 7th Avenue Suite 1 00 Anchorage. Alaska 99501-3539 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to : ProActive Diagnositc Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 - 8952 1 ] 1C-119 MTT Report 16-May-06 2] 1 C - 121 MTT Report 16-May-06 3J 1C-131 MTT Report 14-Jun-06 4J 10 - 127 MTT Report 14-Jun-06 5J 10- 121 MTT Report 14-Jun-06 J Cf7- ,23)6] 1 0 - 1 09 MTT Report 1 5-Jun-06 7J 1 0 - 120 MTT Report 1 5-Jun-06 8J 10-111 MTT Report 15-Jun-06 Signed: U öiJJ Print Name: µ ö ~ o..-V'À/ OklC\.~¿ UL '1 .~ .J ",- Date: ? I J u lj ~ ~ ~ PRoACTÌVE DiAGNOSTic SERViCES, INC., 1 ~O W. INTERNATioNAl AiRpoRT Rd SUiTE C, ANd'¡OAAGE, AK 99~ 18 PliONE: (907)24~~89~ 1 FAX: {(07)24~~89~2 E~MAil: pd,Aí\j(HoRM;E@riIErt1CIW[OCj.CGM WEI>siTE: MEMORyloG.COM c:\My Documents\ W ork\ DistributionLablesNew\ Transmit _ Original.doc I I I I I I I I I I I I I I I I I I I e e ,. Memory Magnetic Thickness Tool Log Results Summary \<\1/'J-'3S Company: ConocoPhillips Alaska, Inc. Well: 1D-109 Log Date: June 15, 2006 Field: Kuparuk Log No. : 8034 State: Alaska Run No.: 2 API No.: 50-029-22842-00 Pipe1 Desc.: 3.5" 9.3 Ib EUE Top Log InM.: Surface Pipe1 Use: Tubing Bot. Log InM.: 199 Ft. (MD) Pipe2 Desc.: 5.5" 15.51b BTC Top Log InM.: Surface Pipe2 Use: Production Casing Bot. Log InM.: 199 Ft. (MD) Pipe3 Desc.: 16" 62.6 lb. Welded Top Log InM.: Surface Pipe3 Use: Conductor Pipe Bot. Log InM.: 121 Ft. (MD) Inspection Type: Assess External Corrosive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Tubing Hanger @ 0' Depth. This is the first log ofthis well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal ofthe 3.5" tubing, 5.5" production casing, and 16" conductor pipe within the logged interval. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (60'), where the readings are assumed to represent undamaged tubing, casing and conductor pipe. All other readings are relative to this reference point, which include influences from the 3.5"" tubing, 5.5" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval 0' - 199'. A log plot of the entire log interval, plus detailed sections of intervals showing metal loss are included in this report. The Delta Metal Loss (%) curve in these plots refers to total metal surrounding the MTT tool and the results show four intervals of metal loss. A maximum of (-15%) circumferencial metal loss is recorded in the interval between 32' and 37'. A maximum of (-13%) circumferencial metal loss is recorded in the interval between 20' and 32'. A maximum of (-8%) circumferencial metal loss is recorded in the interval between 3' and 10'. A maximum of (-2% to 5%) circumferencial metal loss is recorded in the interval between 44' and 76'. A maximum of (-5%) circumferencial isolated metal loss is recorded at 14'. The percent circumferencial metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5", 5.5" and 16" pipe. If all of the metal loss is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. I Field Engineer: R. Richey & N. Kesseru Analyst: M. T ahtouh & J. Burton Witness: T. Sendon I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Jq7~ J3Ç U{e, I I I I I I I I I I I I I I I I I I I cSs. IIJI . 0 n .\ IVI..n H I~I U IIIL-fí.llv.¡;;).¡;;) I fQ.1:J..:JJ J g P'~M DW:¡-.'iè S"""lè3, 1_. Database File: d:\warríor\data\1 d-1 09\1 d-1 09. db Dataset Pathname: -,.- ,J IVlt1 Presentation Format: mtt10hz Dataset Creation: Fri Jun 16 10:25:352006 Calc Sondex Warrior V7. 0 Charted in Feet scaled 1:150 -50 Delta Meta! Thickness (%) 2.2 MTTP01 (rad) 12.2 0 Line Speed \f~¡¡""J - -6.6 MTTP12 (rad) 3.4 I \ - Tree Ha í Metal Loss- 35" Jt 1 5% Isolated Metal Loss -'"' I I I ±±= 20 ~ % Metal :3 5" Colia % Metal Loss I I I Ji. \ 40 3.5" Colla - , ¡ Pup Jt "::I 'i"Coliar I I 5% ~eœl Lg Jt. < -3.5" Col " I'Î 3% Metal Loss 60 -LineSpœd 3.5" ;-..- Jt 2 f---- ;-..- ;-..- ,.-- - 2% Metal Loss - -,...,.u . of 16" Conductor ( R 80 _3.5" Colia - + =+=1 - , ... rð , . " - I I I I I I I I I I I I I I I I I I I ~-:I~' I~ ! lê I I I ¡ I -R=j ¡- 100 - ]1 - .5" Colla :-5.5" Col!ar 120 3.5" .1 EE Jt. 4 i '--- '--- . 140 f- . I '-- 3 5" Colla . ¡ m .7 I $ - < 160 -. 35" 55" lJaSlf ;¡ Collar . $= ~.5 -3.5 --.. 180 .! "- 3.5" Jt. 6 ~.. ;. --- r I "I ! ? T -50 Delta Metal Thickness (%~ 2.2 MTTP01 (rad) 12.2 0 Line Speed (ft/mín) -6.6 MTTP12 (rad) 3.4 I I I I I I I I I I I I I I I I I I I c!rk n Å ~I U_A._I I n~~ r__A.·m:~~ 1 - ---.. IVlvU;;U I ~'IfE DiAq.........c s,,""'''..... ¡""'. Database File: d\warrior\data\1 d-1 09\1 d-1 09. db Dataset Pathname IJnl "IU! 1 1 , Presentation Format mtt10hz Dataset Creation: Fri Jun 16 10:25:35 2006 Calc Sondex Warrior V7. 0 Charted in Feet scaled 1 :50 ~ 2.2 MTTP01 (rad) 12.2 -6.6 MTTP12 (rad) 3.4 Ha Jt. ~.;2èl~ 8% Metal Loss_ - H 1'·' í ~ i 3.5" <:J. '< . ...~. \ ¿ ;1 Jt. 111 ± - _5% isolated Metal Loss -rn <c k: <;::; j: ) < : ';> ~) >... { 20 II 17 ( J/ / l .. ~.. :; ~fr I 1 \ ~ '\ , . (%) 50 22 MTTP01 (rad) 12.2 0 Line Speed (ftll IIII!) -200 -6.6 MTTP12 (rad) 3.4 I I I I I I I I I I I I I I I I I I I cIas. n" .., Ii MIl .... .. I I n~~ f"'" __J. - ç~ - - ,.. I Þm:>Acvhre OiAqmøriC SERvicES, INC. File: . ..J ,~~. '''^ ,,,"',,;,,, "..- 'V"'\ ¡ U- I V;::1.' ¡<:It<:l'" OT r au " 1011 ''''. W, '~4rv-.l_ ~ " - - . ~ujJ"" ",m ,,,. I un. 1 , V""at rmn unz Dataset Frì Jun 16 ~ 2006 Caic Sondex . . V70 C:h;:¡rtPrl in Feet scaled 150 ~ Metal ('Yo) ~ 2.2 IV! I I r"Ul (rad) 12.2 Line Speed (ft/i,¡i¡ IJ -200 -6.6 IV! I ¡ r"lL (rad) 3.4 < I . : ' J >- : ~m ~ .( ;:. 3 V1 20 . ( f'{ if! i ,i 1/ > .It , ; ~ :i' -< "... " i i r-- 13% Meta! Loss sf \ ,.1 I \ il. -; - h « .: ) :, ß'j ¡ 35"( I W I : ;> 15% Metal Loss " .. : t-- \ ) '" ! Lf\ ,- Jt ..... ~ - 40 3.5" Collar Jt. 3.5" Collar -50 Delta Metal Ill!vKI!I::'~:; (%) 50 2.2 M', I r"Ul (rad) 12.2 0 L ^ .. -200 -6.6 MTTP12 (rad) 3.4 Ine V¡.JCcu "t¡ ¡'!II 'J I I I I I I I I I I I I I I I I I I I cJrk n.L :1 P . ' O~~ r__.a.1IrA~ - -~~-. I _ PROAcrive D~rlc SEm1ÌCß... UNC. Database Fiie: U.\\I\II:III IU-"""""""'" 1 Dataset Pathname t(', .~~'." 1 ,....1-''''' u'" ,~ , I VII. Presentation Format mtt10hz Dataset Creation: Frí Jun 16 10:25:352006 Calc Sondex Warrior V70 Charted in Feet scaled 1 :75 ~ MTTP01 (rad) 12.2 o Line Speed (ft/mín) -200 MTTP12 (rad) 3.4 I I Id 40 3.5" Collar j 1 \ I I Jt _3.5" CoHar I 5% Metal Loss W-t- Jt ~5" Colla - ~ /1 - 3% Metal Loss - - 60 Í'- -Line 3.5" ¡,,- Jt 2 [, - ¡.. - [ - If - c- - - - - - U t- - ~ - 1Et ....... 2%1 Metal Loss It I I J I I } > !~ _omm Conductor " /' } 80 \ .(\: !'.\... -50 Delta Metal Thickness (%) 50 2.2 MTTP01 (rad) 12.2 0 Line Speed (ft/min) -200 -6.6 MTTP12 (rad) 3.4 I I I I NIPPLE (4080-4081. 00:3.500) 'RODUCTION -_. I I 'RODUCTION -~ I (4120-4835, 00:3.500. Wt:9.30) I I I 1 4305 - 4340 3724 - 3757 WSB 35 4 9/8/1998 4350 - 4370 3766 - 3785 WSM 20 4 9/8/1998 4394 - 4402 3808 - 3815 WSA3 8 4 9/8/1998 4412 - 4448 3825 - 3859 36 4 9/8/1998 4470 - 4481 3880 - 3800 WSA2 11 4 8/4/1998 4491 - 4528 3899 3934 WSA2 37 4 8/4/1998 4548 4562 3953 - 3967 WS A2. 14 4 9/8/1998 I Perf (4238-4272) Perf (4305-4340) PLUG (4345-4345. 00:3.500) Perf (4350-4370) .0.000 0.000 0.000 I I 3.000 I I Perf (4412-4448) I PLUG I I PLUG ~~ (4761-4752. OD: 3. 500) I SHOE (4834-4835. OD:4.000) '~---~~'----~~-~"-~---"~-----'-"'- - -~---~--~~._.._~-~.- --~ -~.._-'----~._-~-----------~--~ LJ. vvu. ,--"VIIV,""V.L II111It.lo·]I .I...J^,'-'UY«".U.JVJJ '-"'- ~,-......t"""'.lJ. ..L .lVJ""''''''''''J '~ "--- Subject: [Fwd: ConocoPhillips Excavation & Repair Project] From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 20 Jun 2006 07:00:24 -0800 rro: Lou Grimaldi <lou-.:.grima1di@admin.state.ak.us>~John Spaulding· ;<john_spaulding@admin.state.ak.us>~ John Crisp <john_crisp@admin.state.ak.us>~ Jeff Jones fjef(jones@admin.state.ak.us>, Chuck Scheve" <chuck _ scheve@admin.state.ak.us>, Jim Regg <jim _regg@admin.state.ak.us> All, Enclosed, FYI and scheduling, is a message from Problem Wells regarding the "big dig" project they will be starting soon. Jerry has also included a copy of the SPE paper he/they prepared regarding causes and repairs. Torn Subject: Date: From: To: CC: -------- Original Message -------- ConocoPhillips Excavation & Repair Project Mon, 19 Jun 2006 14:06:18 -0800 NSK Well Integrity proj <NI878@conocophillips.com> tom maunder@admin.state.ak.us NSK-Wel-l:Integrity proj <N1878@conocophillips.com>, aogcc prudhoe bay@admín.state.ak.us \\)-\C)\ \~'''d-S ~ Torn: I don't remember how much of our plans we have shared with you on excavating and repairing wells at lC & ID pads. We have been submitting a lot of 10-403s for the work and there is a reason for that. Starting in the next two weeks we will focus on this project, which is pretty ambitious. The attached spreadsheet lists the wells we intend to excavate. Some of these were determined this last year to have surface casing leaks. Others we have chosen to "pro-actively" excavate and inspect to get a better understanding of the level of damage to be expected for the other single casing wells. At any point in time we will have two wells in progress, and hope to continue for the bulk of the summer. A couple of them we will intentionally target late in the year when the ground has less water encroachment problems. We have submitted Sundry requests for all but one well, three of which are in the mail to you today. Like the others, we expect that you agree inspections and repairs on these wells are important and will approve those as well. As we go through the project we will keep the Inspectors notified of our progress so they can see these casings exposed. However, we will be under a tight timeline and will not hold excavations open longer than is necessary. Hopefully they can arrange to inspect them in the several day period that each of them is exposed. If you have any questions about our project please let us know. The SPE paper we wrote on the subject is a good primer on the mechanism involved. I have attached a copy in case there is interest in your shop. Talk to you soon. «IC and ID Casing Repair List AOGCC.xls» «SPE-100432-PP SC Corrosion West Region 2006 Final.doc» Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 SCANNED JUN 2 ~, 2005 IC and ID Casing Repair List Content-Type: application/vnd.ms-excel Content-Encoding: base64 SPE-I00432-PP SC Corrosion West Region 2006 Final.doc Content-Type: application/msword lof2 6/26/20067:51 AM ConocoPhillips Alaska, Inc. 1 C and 1 D Suñace Casing Corrosion Repair Candidates \ ~"\- ;).<,1) PRIORITY NAME TYPE PTD# LEAK DEPTH (ft) --.. -'.'-'-.-",,--,.-,,-----,-,-,.- --~ 1 1 C-121 INJ 201-080 4 --_._._",..-,_._-,....~-- 2 1 C-131 INJ 201-185 7 - ...- -- ~ 3 -----,.. 1 0-109 INJ 197 -235 5* - 4 1 0-111 INJ 198-166 5* 5 10-120 INJ 197-221 7 . -. 6 10-121 Gas Lift 197-181 None . - . ..........._._~._--~._. 7 1 D·12.7 Gas Lift 198-109 None . "____' ·.4'" ...... .. - 8 1 0-132 INJ 198-121 5 9 10-136 INJ 200-046 None 10 1 D~ 137 INJ 200-047 None ~ 11 1 0-138 INJ 200-048 8 12 1 D-139 INJ 200-049 None 13 1 C-119 INJ 201-139 16 14 _._-------------_._----~----,.. ----) Jet Pump 201-220 None 1C·t35 ""¡ 15 ,........ ..,_..... .h..._...,.,__...... .....:......_.. .;.... .'.h'_"1 ESP 197-184 None 1D-135 ! I 16 ... ..,~ hO· .... ..-., ".,-~ ".,-..----- _m~'_" ............1 Gas Lift 200-112 None to-141 I Notes: COMMENTS I STATUS l Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig ) Proactive dig Proactive dig, backup candidate (has 500' casing) Proactive dig backup candidate. 1. Repairs will be performed in the priority order as listed, two repairs in progress simultaneously. 2.10-135 and 10-141 are backup options in case excavations cannot be made on other wells. 3. List is a combination of wells with known leaks (8) and proactive inspections (2 injectors and 3 producers). 4. Proactive inspections are scheduled for wells that are currently shut-in and should not have rate impacts except 1C-135 Jet Pump producer. 5. Rate impacts may be encountered if neighboring wells are shut-in during excavator activities or if additional flowlines need removal. 6. If excavations cannot be completed prior to rig arrival then SIMOPS operations will be considered or delays will be encountered. NSK Problem Well Supervisor 6/26/2006 e e \ C\ 'l - d-~5' tŒCRÞ~ICAL INTEGRITY REPORT ........ \ ~, ._C' Cy ~ ~ U D D -~. :-.:: : 1~-=:1~ :. .:: G 2. .s ;.. .:;. ::.:: : \'k~ ~ ~ ~ OPER & FIELD C.:V~ \ \N<è'S.-\-~ \<.. ~~ll NUH:BER \ \) -- \G ~ "5 \/;) '2 \{.,",\ J J.- P 2.cke::- ì'"1/& TD: l-\~OMDH~~Ù TVD; :?BTD: 4'\"'\) HD Shoe: l.\\ d. \ MD TVD ¡ DV: Shoe: l.\'b·>~ÇKD TV-U; :CP: l.\\'d \ HD ~ \(, (p TVD ',.¡!:.LL DATÞ. Cë.sir:g: - ~\'~ _::..:¡e:::-; 5\/':) MD ·I'vu ;:~;D _·.JD~:;g : MD rVD; Set ë.C :-:ole Size a.na Pe:r-£.s \.\ 9- ~ 1S to l..\ ~~~ (/ ,', ~4~CL \"> :'SC?..Þ.lEC;'..L INTEGRITY - ? ART I: Annulus Press Test: IE : 15 ffiln ; 30 min Corraents: \?ú-YSe~ ~ \ \" ç. /;)C4:J~ ' ,.,- ~CHÞ~ICÞ~ INTEGRITY - PART /2 ~ 4\:)5'4 \.~d~ ~~\ ') ~ 'ì.-\ 'is-.; 'foe ( Q£>\, ~ \ ') Ce~enc Volumes:' .A..mt. Liner Csg \ ; DV C~c -,¡01 to cove::- ùe:r-=$ SL-\S~\~ C\-.. ~\\ "S~\ù£~\·~ Q::Ñ{S'" 3\6 ',\ 'l"heorecical TOC ~Q.M.~.,,-\ ~~\~ 1'\rt."\Cl.-\-e I \.:,~ 'g:>\' \'t~~ Cement Bond Log (Yes or No) '-l<t~ ~ c.\~ '\ "\/6-c;ß' i In AOGCC File y~,> CEL :::valuation, zone a.bove perfs 'b:>~c(ð~0'I.~~";¡ç.~~\\\<;~ \f'J...l:~L~\. "-.ÌI ~~~~~ ~ ~'">~~ ~ù\>~~.~~ (\e:\MÇ> ~ 'E> c---o~~~ Ck,,~~\\t:.'> O-.~'ð~~ "\'(:I -\('....~ . > Proaue-tion Log; !ype ; Evaluation " ~:2,~,-~~,i~~,,~' '~;X~~'-·,~~< ,- c .. "', '¡Pile, CONCLUSIONS: ?art #1: k~~~~\(~~~ . ?ar:: fl: \V\I' '\., \>~~~\<t ~. ~1t'~\I\:-\-~:). ~ ~~~ ~''i ~~~ \(;)? Þ<r~ ~.~C{)~ @lTJ:/K\lfrE ® ¡Ü\1U Lb e 0n" ~!' , ~ j H,', . ,~ ! ¡" ¡ lWlf e AIfASIiA. ORAND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR MJ Loveland Problem Wells Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 'Anchorage, AK 99510 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~ Re: Kuparuk River Field, West Sak Oil Pool, 1D-109 Sundry Nu:tnber: 306-094 / \ 0... ~' 'if -~l' Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause .shown, a person affected by it may file with the Commission an application . for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working , day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisE day of March, 2006 Encl. · STATE OF ALASKA ú'lW'/1, I ALASKA OIL AND GAS CONSERVATION COMMISSION .}\ MAR 2 0 2006 APPLICATION FOR SUNDRY APPROV ALAlasks Oil & Gas Cons. Commission 20 MC 25.280 Ahara Operational Shutdown 0 Perforate 0 Waiver 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Perforate New Pool 0 1. Type of Request: o o o Suspend 0 o o Abandon Alter casing Repair well Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 111' Pull Tubing 8. Property Designation: Kuparuk River Unit 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 4850' 4240' Casing Length Size CONDUCTOR 121' 16" SURFACE 4009' 5-1/2" , ~l RECEIVED Other 0 Re-enter Suspended Well o 4. Current Well Class: Development 0 Stratigraphic 0 5. Permit to Drill Number: 197-235 6. API Number: 50-029-22842-00 9. Well Name and Number: 10-109 Exploratory 0 Service 0 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): MD 121' TVD 121 3550 ,-\)'J cç1 Perforation Depth MD (ft): 4238 Packers and SSSV Type: no packer no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name MJ Loveland Perforation Depth TVD (ft): Date: Signature 3661 Packers and SSSV MD (ft) Tubing Size: 3-1/2" no SSSV 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Contact: Title: Phone 659-7224 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Burst Collapse Tubing Grade: L-80 Tubing MD (ft): 4120' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 MJ Loveland 1 Marie McConnell Problem Wells Supervisor Date Sundry NUDb& ... m4J Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: ~<'.\a..~\- r~S\,IZ..C-~' ~'-~\-~ð~ \0 ~\~<tS.':::. Ç'(L~\ Ð~ \<tc.\c\~c..G.\-\ð~~~~~\ ,- Approved by: Form 10-403 Revised 7/2005 Date:c3 .. -IJÞ ~ :5. ~i" »ubmit in Duplicate ~ ,?f2P/a e e ConocoPhillips Alaska, Inc. Kuparuk We1l1D-109 (PTD 197-235) SUNDRY NOTICE 10-403 APPROVAL REQUEST February 27,2006 This application for Sundry approval for Kuparuk welllD-l 09 is for the repair of a production casing leak. This well is a single casing injector; it has no surface casing. It was completed in January 1998. On July 22,2005, the well failed an MITIA that was prompted by an investigation into near-surface corrosion on single casing injectors. After the MITIA failure, diagnostics to locate and quantify the leak did not produce consistent results. An attempt to locate the leak depth with nitrogen could not be completed due to the high pressure required to create the leak. As such, a leak rate could not be established and the leak depth has not been determined. Since the mode of failure is suspected to be the same as other wells with similar construction, it is requested to inspect and repair the production casing near surface on this welL With approval, repair of the production casing will require the following general steps: 1. Notify AOGCC Field Inspector of repair operation so they may witness the event. 2. Safe-out the well with plugs and load the tubing and IA with seawater and diesel freeze protection cap. 3. Remove the floor grate and equipment from around the wellhead. 4. Install nitrogen purge equipment for the IA and conductor so that hot work may be conducted in a safe manner. 5. Cut away the conductor casing and remove cement around surface casing for inspection. Approximately the top ten feet of conductor will be removed to provide access to the production casing. 6. CP AI Mechanical Engineers will determine appropriate patch and/or repair to return the casing to operational integrity. 7. QA/QC the repair and MIT -IA for a final integrity check. 8. Install anti-corrosion coating as specified by CP AI Corrosion Engineer. 9. Replace the conductor and fill the void with cement and top off with sealant. 10. Backfill as needed with gravel around the wellhead. 11. Remove plugs and return the well to production. 12. File 10-404 with the AOGCC post repair. NSK Problem Well Supervisor 05/07/05 I,Œ: Sunqry for lD-I09 e e Subject: RE: Sundry for I D-1 09 From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Mon, 20 Mar 2006 16:04:34 -0900 To: Thomas Maunder <tol11_maunder@admin.statc.ak.us> CC: "Reilly, Evan Mil <Evan.Rcilly(g)conocophil1ips.com> Tom, I attached the historic data for 1D-109. Please let me know if you need any more data or a 10-404 for the perfs. Thanks for the help MJ -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday I March 2 O"~-"'-'-2'-OO"6-"'-3-;-'34i?M - .....---.-.-................-..............-. To: NSK Problem Well Supv Subject: Sundry for 1D-109 MJ or Marie, Please have a look at the document you sent in for repairing the casing near surface on 1D-109. The PTD and API numbers are correct, however the depths and casing descriptions do not agree with what I see in the file. This is one of those tapered casing strings (5-1/2" x 3-1/2") like the others. Thanks. Call or message with any questions. Tom Maunder, PE AOGCC ID-I09 historic Content-Description: 1D-I09 historic data.xls Content- Type: application/vnd.ms-exceI Content-Encoding: base64 it,. 1 of 1 3/21/2006 9:43 AM Page 1/2 1 D-1 09 Report Printed: 3/20/2006 www.peloton.com Well History API/Bottom Hole UWI Well Type Well Services Daily Operations Report Date Field Name Legal WellName 5002922842 WEST SAK 1 D-1 09 Original KB Elevation Well Status 111.4 INJ Legal Well Name 8/16/200515:001D-109 8/15/20056:001D-109 7/25/2005 14:00 1 D-1 09 7/23/2005 9:00 1 D-1 09 7/22/2005 14:45 1 D-1 09 7/22/2005 11 :00 1 D-1 09 7/22/200510:301D-109 7/21/200513:001D-109 2/23/20030:00 1 D-1 09 1/26/20030:00 1 D-1 09 12/27/20020:001D-109 11/26/20020:00 1 D-1 09 10/18/20020:001D-109 9/4/20020:001D-109 7/20/20027:151D-109 \ ~ "'\ - J~ S- e Last 24hr Sum MITIA- failed, Purge N2 down IA for leak detection TAG TOP OF PLUG @ 4166' RKB, CALIPER TUBING FROM 4166' RKB TO SURFACE. JOB COMPLETE. MITIA - Failed MITT - passed, MITIA/LLR - passed PULLED MA-2 PLUG FROM 4080' RKB. SET WRP @ 4187' RKB TO SECURE WELL. IN PROGRESS. MIT'd TBG 2000 PSI, PASSED. MIT'd CSG 2500 PSI, FAILED. BLED TBG & CSG TO 0 PSI. MIT-T passed, MITIA failed. BRUSHED TBG. SET 3" M-A2 PLUG AT 4080' RKB; BLED TBG TO 0 PSI, CONFIRMED SET. IN PROGRESS. FEB '03 PLUG RENTAL JAN '03 PLUG RENTAL DECEMBER PLUG RENTAL MONTHLY WRP TOOL RENTAL. MONTHLY WEATHERFORD WRP RENTAL CHARGES MONTHLY WRP TOOL RENTAL. SET WEATHERFORD 3.5"" RETRIEVABLE BRIDGE PLUG @ 4345' ELM (TOP OF ELEMENT), POOH, RDMO, LEFT WELL SHUT IN, NOTIFIED DSO OF STATUS. e 6/22/200215:001D-109 \~'\-d-'?~ c; 4/11/2002 13:00 1 D-1 09 12/12/200015:301D-109 9/8/2000 15:30 1D-109 7/16/200011:001D-109 4/14/200010:001D-109 3/25/19997:001D-109 3/23/199913:001D-109 9/8/19988:001D-109 9/6/199810:101D-109 9/3/199823:001D-109 8/5/1998 13:45 1 D-1 09 DRIFTED TBG 2.78"" & TAGGED @4709' RKB, EST. 147' RATHOLE, EST. 364' BELOW BP TARGET DEPTH 4345' RKB. SAMPLE OBTAINED. [Tag] PERFORMED SBHP AT 4065' MD MANO/THERMO DEPTH. PERFORMED STOP COUNTS AT 4280',4345',4480 PFCS DEPTH. SPINNER WAS COVERED IN MUNG WHICH WAS FIRST POSITIVELY ENCOUNTERED AT 3885'. UNABLE TO DETERMINE IF THERE IS CROSSFLOW. INJ PROFILE: ZONE D=12.7% / B=18.6% / A=68.7%. UNABLE TO DETERMINE TD - SET DOWN SOFT IN PERFS AT 4520 - SHUT SPINNER DOWN. CONDUCTED SBHP W/ PANEX GAUGE @ 4275' RKB. OBTAINED BHP @4380' RKB(1897 PSI). e PERFORMED SBHP SURVEY @ 4275' RKB (1874 PSI) & 3975' RKB (1761 PSI). INJECTION PROFILE COMPLETED & PWI SPLITS AS FOLLOWS; 29% IN THE ""D"" SAND PERFS (4238'-4272')--> 4% IN THE ""B"" SAND PERFS (4305'-4340') -> 9% IN THE ""A4"" SAND PERFS (4350'-4370')--> 19% IN THE ""A3"" SAND PERF'S (4412'-4448')--> 39% IN THE ""A2"" SAND PERF'S (4470'-4481') TAGGED @4732' RKB, EST. 170' RATHOLE. PERFORATED 3-1/2"" TUBING W/ 2-1/2"" HC, DP, 4 SPF, 180 DEG PHASNG, ORIENTED 90 DEG FROM LOW SIDE, ""A2"" 4562' - 4548' RKB, ""A3"" 4448'- 4412', ""A4"" 4402' - 4394',4370' - 4350' AND ""D"" 4272' - 4238'. DRIFTED TO 4591' RKB w/ 2.75'''' X 23' DUMMY GUN. TAG BRIDGE PLUG @ 4404' CTM - ADJUST DEPTH TO 4440' RKB - MILL BRIDGE PLUG - PUSH PLUG TO 4765' RKB - FREEZE PROTECT WELL FROM SURFACE MEASURED BHP @ 4322' RKB: 1977 PSI. e 1O-109 (PTS 1972350) MIT Data e e Subject: ID-109 (PTS 1972350) MIT Data From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Sat, 23 Jul2005 15:33:09 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us>, James Regg <jim Jegg@admin.state.ak.us>, bob _ fleckenstein@admin.state.ak.us Tom, Bob, & Jim, Attached is the Failed MITIA data for 10-109 as reported yesterday. The well has been SI with a plug. Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 «MIT KRU 10-10907 -22-05.xls» Content-Description: MIT KRU ID-I09 07-22-05.xls MIT KRU ID-I09 07-22-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 · .' \C;'ì -if"'- lD-120 (PTD 197-221) & lD-I09 (~)_ort off ailed MITIA... \~")-)S ç Subject: 1D-120 (PTD 197-221) & 1D-109 ~Report of failed MITIA - IAxAtmos comm From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Fri, 22 Ju12005 14:48:37 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us>, James Regg <jim _regg@admin.state.ak.us>, bob_ fleckenstein@admin.state.ak.us e Tom, Jim & Bob, Attached is MITT & MITIA data for 10-120. This test was performed to check the wellbore integrity of this mono-annulus injector. A plug was set in the tbg and an MITT passed, but an MITIA failed with diesel breaching the conductor top on 7/21/05. No diesel was spilled to the cellar. The diesel was contained in liner wrapped around the top of the conductor and the leak stopped as soon as the IA pressure was bleed down. The well has been left SI with a tbg plug. Prior to setting the TTP, 10-120 was on injection at 485 BWPO and T/I = 1120/5. Additional diagnostics will be performed to determine the liquid leak rate and estimated depth of the leak to evaluate if an excavation repair is feasible. A 10-403 will be submitted for repair once a repair plan has been determined. Integrity verification is progressing at 10. Today, 10-109 passed an MITT with a TIP, but failed an MITIA with diesel to surface at the conductor top. The fluids were contained similar to 10-120 and no diesel was spilled to the cellar. 10-109 was on injection at 300 BWPO and T/I = 1040/35. Only preliminary data is available at this time. I will send the MIT form for 10-1 09's failure tomorrow. There are nine more mono-annulus injectors at 10 that will be tested to verify integrity over the next few weeks at a rate of about one per day. Please let me know if you have any questions. Thanks, Marie McConnell. Problem Well Supervisor 659-7224 «MIT KRU 10-120 07-21-05.xls» «10-120.pdf» «10-109.pdf» Content-Description: MIT KRU 1D-120 07-21-05.xls MIT KRU ID-120 07-21-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: 1D-120.pdf ID-120.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: 1D-109.pdf ID-I09.pdf Content-Type: application/octet-stream Content-Encoding: base64 ., i'\ ",n'" 1 - - n-' e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConoeoPhillips Alaska Inc. West SakI KRU/1D-109 07/22/05 Arend I Brake - AES o P o F Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= other (describe in notes) MIT Report Form Revised: 06/19/02 MIT KRU 10-109 07-22-05.xls e .PHlllIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY J~ I.,,!I'I" - ;: I~'~ NIPPLE (~œo ~081. OD.3.5GO) TUBING (0-4120, OD3.500. iD.2.9'J2) SURFACE (04120, OD:5.500, Wt:15.50) - 1D-109 API' 500292284200 SSSV Type. NONE Annular Fluid: Reference Loa' Last Tao: 4709 Last Tao Date 6/22/2002 Casina Strina - CONDUCTOR Description I CONDUCTOR I Casino Strino - SURFACE Description I SURFACE 1 SURFACE I Tubina Strina - TUBING Size I Top 1 3 500 I 0 1 Perforations Summary Interyal TVD 4238 - 4272 3661 - 3693 4305 - 4340 3724 - 3757 -- 4350 - 4370 3766 - 3785 4394 - 4402 3808 - 3815 4412 - 4448 3825 - 3859 SURFACE 4470 - 4481 3880 - 3890 (4120-4835, - OD:3.500, 4491 - 4528 3899 - 3934 Wt:9,3Q) -- 4548 - 4562 3953 - 3967 - - Perf - - (42364272) = - - - - Perf - - - - - (43054340) - - - ... ¡- PLUG (43454346, OD:3.500) . .--".- - Perf (4412-4448) ... ...... - - ----. - PLUG (44404441, OD:3.500) - X I .---------. - -.-.....--.-,.,. - ..................... - PLUG -- (4761-4762, OD:3.500) J~~~ SHOE (4834-4835, OD:4,ooo) 'Gâs Lift MandrelsNalves St I MD I TVD I ~~; 1 1 40281 34651 BST Other luos eauip. etc. Depth TVD TYDe 4080 3513 NIPPLE 4120 3550 SBE 4345 4440 4761 3762 3851 4155 PLUG PLUG PLUG 4834 4224 SHOE e KRU 1 D-1 09 Well Tvpe: INJ Orig 1/13/1998 Completion: Last WIO Angle @ TS dea tã) Angle @ TD: 18 deg @ 4850 Rev Reason. Tag. set RBP by ImO Last Update. 7/20/2002 Ref Loa Date' TD. 4850llKB Max Hole Anole' 42 deg @ 1962 Size Top 1 Bottom I TVD 1 Wt 1 Grade Thread 16.000 0 1 121 1 121 I 62.58 1 H-40 1 Welded Size Top 1 Bottom 1 TVD I Wt 1 Grade I Thread 5.500 0 I 4120 I 3550 1 15 50 I L-80 I MBTC 3.500 1 4120 1 4835 1 4225 I 9.30 1 L-80 I ABM-EUE Bottom I TVD 1 Wt 1 Grade 1 Thread 4120 1 3550 1 930 1 L-80 I ABM-EUE Zone Status Ft SPF Date Type Comment WSD 34 4 9/8/1998 IPERF 2112" HC, DP, 180 deg. I phasing, 90 deg. orient WSB 35 4 9/8/1998 IPERF 21/2" HC, DP, 180 deg. 1 phasing, 90 dea. orient WSA4 20 4 9/8/1998 IPERF 21/2" HC, DP, 180 deg. 1 phasing, 90 deo. orient WSA3 8 4 9/8/1998 IPERF 21/2" HC, DP, 180 deg. I phasing, 90 deg. orient WSA3 36 4 9/8/1998 IPERF 21/2" HC, DP, 180 deg. I phasing, 90 dea. orient WSA2 11 4 8/4/1998 IPERF 21/2" HC, DP, 180 deg. I phasing, 90 deo. orient WSA2 37 4 8/4/1998 IPERF 21/2" HC, DP, 180 deg. I phasing, 90 deg. orient WSA2 14 4 9/8/1998 IPERF 21/2" HC, DP, 180 deg. 1 phasing, 90 dea. orient :. !S .. . ::,:;./.~\<;: .. .::~>.~: ." ~~: I V Mfr I V Type I V OD I latch I Port I TRO I ~:t~ I C~~t AXT I BST I DMY 1 3.5 I T-1 1 0.000 I 0 16/15/19981 .. JEWELRY Description ID 2.812 3.000 W-1 niPple. selective profile Baker GB~t-22 Locator Seal Assembly w/Baker 1 Seal Bore Extension, 11.80' Seal Assv. RETIEVABLE BRIDGE PLUG SET 7/20/2002 Set Fast Drill 3.5" bridge plug and tested to 2200 psi. Tested tubing and bridge plug to 3000 psi - good. EZ-Drill Bridge Plug Set @4761. 0.000 0.000 0.000 3.000 Date I Note 7/12/19981 PUSHED TUBING OBSTRUCTION DOWN TO PBTD @4772' RKB. MEMORANDUM TO: Randy Ruedrich v ~-'-~ Chair THRU' Jim Regg State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 20, 2003 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska Inc. P.I. Supervisor ~"~'~ ' ) . 06, 09, 106, 109, 111 FROM: John H. Spaulding Kuparuk River Unit Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Welll 1D-06 I P.T.D. I 1700060 Notes: Well J 1D-09 P.T.D. I 1980650 Notes: ' P.T.D.I 1972400 Notes: P.T.D. I 1972350 Notes: P.T.D. I 1981660 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Inj.I S I T.V.D. I 6265 I Tubing 11795 [1790 11790 11790 I lntervall 4 I ITypetestlType P ,TestpsiI 1566 ICasingI 1360 , 2500I 2500I 2490I P/F I PI I Type,nj.Is I T.V.D. 16150 I Tubi.g J1792 117e0 J17e0 I~ I,nterva, I 4 I TypetestIP ITestpsil 1536 I Casin91 390 I 2535 I 2520 I 25101 P/F I -P I Typelnj.I S I T.V.D. 13630 I T~,b,,gl 1310 I 1310 I 1310 11310 I lntervall 4 I Type testI P I Testpsil 908 I CasingI 460 I 26201 26201 26101 P/F I P I Type,nj.IS I T.V.D.I 355O I Tubir~gl 1320 I 1320 I 1320 I 1320 I,nterva, I 4 Type testI P I Testpsil 888 I Casingl POS. I 25501 25501 255°1 P/F I P Type testI P I Testpsil 893 I Casingl POS. I 2500 I 400 I I P/F I E Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A-- Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) .l~had a positive pressure (basically 0 psi) when checked prior to rig up of the pump. The IA was pressured ap to 2500 psi as noted and immediately started to bleed down. After 15 min. pressure was at 400 psi. Ultimately the IA went clear to 0 psi on the guage. As I was checking the IA the last time I noticed that diesel was coming up through the the hanger flutes. Approxiamtely 5 gals. over flowed into the cellar area. This was cleaned up. I contacted Tom Maunder and he suggested that the well be shut-in until CPAI offered a repair program to the AOGCC. Jerry Dethlefs Dethlefs CPAI rep. concurred with the shut-in advice. M.I.T.'s performed: _5 Number of Failures: 1_ Attachments: Total Time during tests: 3 hours cc: MIT report form 5/12/00 L.G. mit kru ld 6-20-03 jsl.xls 7/17/2003 Well Report (_~offip. 01 / 13 /1998 KUPARUK RIV U WSAK 1D-109 Completion Status: lWlNJ Current Status 029-22842-00 197-235-0 ARCO MD 0485OTVD 04240 Name Interval Sent Received BO 8237 ~ SPERRY MPT/GR/EWR4 2/11/98 2/11/98 CBL-SLIM ~-"~INAL 39904750 7/24/98 7/24/98 DGR/EWR4-MD t,~/~INAL 1234850 2/11/98 2/11/98 D DGR/EWR4-TVD bJ~/~INAL 1214240 2/11/98 2/11/98 n INJP-SPIN/TEM/ ~AL PRES 41304640 4/22/99 5/13/99 MWD SRVY ~ ~E'~y 0-4850 2/13/98 2/18/98 SRVY CALC .R/' 61~378.664850. 7/27198 7/30/98 Daily Well Ops /,/7/.c/~ -- ]73 / ~ Was the well cored? yes ~ Are Dry Ditch Samples Required? yes (~r And Received-?--yes-~-- Analysis Description Received?_..y. es--4~~-~ Sample Set-# .......... Comments: Monday, January 10, 2000 Page 1 of 1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 27, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-109 (Permit No. 97-235) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-109. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Senior Drilling Engineer Kuparuk Development TWM/skad R CEi¥ D Gas Con~. Cornrniss~u'.' Anchora~Je STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL L--] GAS [] SUSPENDED [~ ABANDONED~ SERVICE [~] Injector 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 97-235 3 Address 8 APl Number q ~ 50-029-22842 P.O. Box 100360, Anchorage, AK 99510-0360 4 Location of well at surface "-~'-"'-"~--"'~'"'~, 9 Unit or Lease Name 59' FSL, 596' FEL, Sec. 14, T11N, R10E, UM~" --"~t't; t' Kuparuk River Unit J ~ West Sak 1D-109 1904' FSL, 1577' FEL, Sec. 14, T11 N, R10E, UM ........ "~'~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Sedal No. West Sak Oil Pool RKB 41', Pad 71' ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 08-Jan-98 10-Jan-98 13-Jan-98I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 4850' MD & 4240' TVD 4772' MD & 4166' TVD YES M NO U NA feet MD 1532' APPROX 22 Type Electric or Other Logs Run GR/Res 23 CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 62.58# H-40 SURF. 121' 24' 9 cu yds High Eady 5.5" x 15.5# L-80 SURF. 4121' 8.5" 412 sx AS III LW, 495 sx Class G, & 3.5" 9.3# L-80 4121' 4835' 8.5" 60 sx AS I 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4508'-4528' MD 3915'-3934' TVD 4491'-4508' MD 3899'-3915' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4470'-4481' MD 3880'-3890' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4 spT 27 PRODUCTION TEST OR!GiiWAL Date First Production Method of Operation (Flowing, gas lift, etc.) njector Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBl. CHOKE SIZE I GAS-OIL RATIO I TEST PERIOI: Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBl. OIL GRAVITY-APl (cord Press. 24-HOUR RATE: 20° 28 CORE DATA i Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 submit in c~l~tt~)~' (~ Bev. 7q-80 CONTINUED ON R~ERSE SIDE Date: 2/20/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-109 WELL_ID: AK8981 TYPE: AFC: AK8981 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:01/08/98 START COMP: RIG:PARKER 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22842-00 01/07/98 (D1) TD: 121'(121) SUPV:DEB MW: 9.0 VISC: 285 PV/YP: 36/44 APIWL: 7.0 DRILLING AT 616' Move rig 330' to 1D-109. Accept rig @ 1900 hrs. 1/7/98. NU diverter system. Function test diverter system. 01/08/98 (D2) TD: 3200' (3079) SUPV:DEB MW: 9.1 VISC: 295 PV/YP: 35/51 DRILLING AT 4172' Spud in at 121' and drill to 3200' MD. APIWL: 7.0 01/09/98 (D3) TD: 4703' (1503) SUPV:DEB MW: 9.1 VISC: 325 PV/YP: 39/53 APIWL: 7.0 PREP TO POH FOR CASING Drill from 3200' to 4703' Swabbing from 4200' to 3250', work pipe out. Wash & ream out from 3250' to 1260' 01/10/98 (D4) TD: 4850' (147) SUPV:DEB MW: 9.4 VISC: 284 PV/YP: 38/53 APIWL: 6.2 RE-RUN CASING Wash & ream thru bridges in spots from 2032' to 2966' Drill from 4703' to 4850' MD. Run 3.5" x 5.5" casing. Hit bridge at 1600' Work pipe. No go. Pull casing. 01/11/98 (D5) TD: 4850'( SUPV:DEB o) MW: 9.4 VISC: 94 PV/YP: 26/36 APIWL: 6.4 PREP TO RIH W/4.75" BIT Ream with hole opener from 1801' to 2052' Ream from 3764' to 3943' Run 5.5" x 3.5" string. Pump first and second stage cement. 01/12/98 (D6) TD: 4850'( SUPV:DEB o) MW: 8.9 VISC: 43 PV/YP: 10/ 7 APIWL: 20.0 PREP TO DISPLACE W/SW ND diverter system. NU BOPE and test. Drill out plug & stage collar at 1973' to 1975' Wash & ream to 2022' 01/13/98 (D7) TD: 4850'( SUPV:DEB o) MW: 6.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Run 3.5" tubing. Nil tree and test packoff to 5000 psi, OK. Test tree to 4900 psi, OK. Release rig @ 1500 hrs. 1/13/98. " ~,~__ ~ To Drilling WELL INFORMATION D.._QVV'NHOLE INFORMATION ~ITP O psi Drillers TD 4850' MD - Parker 245 §-1/2 Casing Pressure: 13 ps! PBTD/-rop of fill or Jun!e:4772' PBTD Date Tagged BPV Installed: Yes AX No DHP Downhole Plugs: ~Yes YvX No psi/depth Date Instrument Annulus fluid Dsl/3% KCI Weight 6,8/8,7 ppg Tubing fluid DsI/3% KC[/Mud 6,818.'7t9.4 ppg Size Wt. Cond. 16" 62.58# DIRECTIONAL INFORM.A_TION Surf. 5-1/2"× 15,§# RKB 38,78' Tbs Hgr. L.D; KOP 400' Surf, 3-1/2" 9.3~ Avg Hole Angle 39' Tubing: Max angle of 4i.8' ~ 1962' Tubing: 3-1/2" 9.3~ L-80 Hole Angle @ TD 18.4' Weft Head Vetc~ Gray~ 3-1/8" 5 Ksi .... Tree Cap Conn (Type/Pre.~sure Rating) Tbs Hgr Corm CASING/T.. U ,B, lNG DATA Grade Conn. Depth H-40 Welded 121' L-80 MBTC 4~20' L-BO ABM-F..UE 483.5' ABM-EUE 4i 20' OTIS Union Gray 3.725" MCA NEW, ADD. OR RE-PERFED INTERVALS Type Guns ,.S, PF From To (Well has NOT been Perforated) Rig released subsequent to full well completion as required on State Drilling permi' ?? Yes No If no, specify remaining operations: Perforat.~z_F, RAC COMPLETION INFORMATION Mfgr/Type/Sizeldummy or Orifice/Latch Tops GLM BST3-1/2"x I"ATX, DummyValve,.T.1 Latch NIPPLE CAMCO 3-1/2." W-I Selective Njpp.!e, 2.812" ID LSA Baker Locater Seal Assy 4028' 4080' 4120' SBE Seals sfa_bbed iq_to sBE at XO in 5-f/2.~ x $-1/2" Casin.q .... Baker 4" ID Seal Bom Extension 4'120' FC Genloco Float Collar PBTD -> 4773' FS Gemoco Float Shoe 4835' ENVlt~ONMENTAL SITE IN,SPECTION Location clean. * GENERAl. INFORMATION _Tubing & Annulus have Diesel freeze protection _dgwn to ~23§0', with Sea Water with 3% KCI from them to SBE at 4i20', There is 9..4 pp~l mud below the SBE to PBTD at --4773'. Annulus teated ,good to 3000 psi. Shoe of 3-i/2" casi.n, 9 is "wet", tes..t..s leak off to N650 psi shortly. Did NOT bump plug on 1st. St la,(]e of 5-1/2" x 3. t12" cement ~ob & overdisplaced shoe. Run CBL & cement squeeze shoe or set CIBP just above FC. (Attach Tubing & Casing Detail) Drilling Department Rep. Don E, Breed_en Title Drilling Supervisor Date Production/Oper Dept. Rep.-- ~ ~ Title "~- Date 1/15t98 ARCO Alaska, Inc. ~ 'PARUK RIVER UNIT ,~, WE.~L SERVICE REPORT ~' K1(D-109(W4-6)) WELL JOB SCOP[E' " JOB NUMBER ' ' 1 D-109 RESV DATA GATHERING 0624981142.2 DATE DAILY 'WORK ' UNiT NUMBER 08/04/98 RAN 3" EZ DRILL BRIDGE PLUG, PERFORATE -'DAY OPERATION COMPLETE I SU(~bESSFUL " KEY PERSON SUPERVISOR 9 {~) Yes O No! (~) Yes O No SWS-ELMORE SCHWENDERMAN FIELD AFC# CC# ' DAILY COST ACCUM COST ' Signed .... ESTIMATE AKB981 18WSTF7SC $18,160 $121,316 Initia'i Tbg Press F'inal Tbg Press Initial Inner Ann Final Inner Ann I Initial Outei' Ann ~ Fina, l'Outer Ann 700PSI 600..PSI oPSI OPSII .. OP811 0PSI . DALLY SUMMARY TUBING AND B. PLUG TO 2200 PSI,OK. PERFORATE 3-1/'2" LINER F/4340' - 4305' RKB. [Perf, PT Tub-Csg] RAN HALLIBURTON 3" FAST DRILL BRIDGE PLUG AND SET @ 4440' (30' ABOVE EXSISTING PERFORATIONS). PT TIME 08:30 13:30 14:30 15:30 16:30 17:30 18:30 LOG ENTRY MIRU SWS ( ELMORE AND CREW) TGSM PERFORATING. COMENCE RADIO SILENCE, NOTIFIED PERSONELL O LOCATION, MU ASSEMBLY ( 3"DBP,SETTING TOOL,CCL,W-r) TL.--22'. PT LUBRICATOR TO 3000 PS1. RIH. TIE IN USING SCHLUMBERGER CBL LOG DATED 7/6/98. SET DRILl_ABLE BRIDGE PLUG AT 4440' RKB COL TOP AT 4439' RKB. POH. PRESSURE TEST TUBING AND BRIDGE [PLUG TO 2.200 PSI, OK. AT SURFACE RD. MU #1 PERF ASSEMBLY USING SAVE GUN OPERATION. 2-1/2" HC, DP, 4 SPF, 180 DEC PHASING, 90 DEGi OREINT F/LOW SIDE (20' GUN, MPD,CCL, HEAD) TL-29' RIH. TIE IN AND PERFORATE 3-1/2" LINER F/4,340' - 4320' RKB, GOOD SURFACE INDICATIONS. POH. AT SURFACE RD. ALL SHOTS FIRED. MU #2 PERF GUN ASSEMBLY, 20' GUN LOADED 15', AND 5' BLANK TL--29' SAME AS ABOVE. RIH. TIE IN AND PERFORATE 3-1/2" LINER F/4320' - 4305' RKB, GOOD SURFACE INDICATIONS. POH. AT SURFACE RD. ALL SHOTS FIRED. LEAVE WELL SHUT IN FOR SLICK LiNE FOLLOW UP. RETURN WELL BACK TO DSO. ~ER¥1CE COMPANY - SERVICi= "' DAIL~ COST ACCUM TOTAL $o. oO $440.00 APC $200.00 :$9,680.00 DOWELL $0.00 $g,663.00 _H.ALLIBURTON" .. '~ ~5,120.0.0 ...$23,516.10 LI-I-I'LE RED ......... $0.00 $4;465,00 RADIUS,,, .. ..$0'00i _$7,695.00_ SC~'HLUMB. ERG'ER " ./- $12,840.55 $6..6,157.80 -'i'oTAL FlEEo ESTIMATE '...,-~ $18,.i60,55 $121,316.90 · ,, ARCO Alaska, Inc. KUPARUK RIVER UNIT ,k, WELL SERVICE REPORT '~, K1(1D-109(W4-6)) WELL JOB SCOPE JOB NUMBER 1D-109 RESV DATA GATHERING 0624981142.2 DATE DAILY WORK UNIT NUMBER 07/17/98 SET BRIDGE PLUG / PT / PERFORATE DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 6 YES YES SWS-STE P HENSON SCHWEN DERMAN FIELD AFC# CC# Signed ESTIMATE AK8981 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 0 PSII 0 PSI DALLY SUMMARY RAN 3-1/2" BRIDGE PLUG. SET COE @ 4764'. PRESSURE TEST TUBING AND BRIDGE PLUG TO 3000 PSI, GOOD. RAN 2-1/2" PERF GUN #1 AND SHOT 20' F/4528' TO 4508', RAN PERF GUN #2 AND SHOT 17' F/4508' - 4491', RAN PERF GUN #3 AND SHOT 11' F/4470' TO 4481'. [Perf, PT Tub-Csq] TIME LOG ENTRY 07:30 MIRU SWS (STEPHENSON AND CREW) TGSM, JOB OVERVIEW, RADIO SILENCE. MU 3-1/2" HALLIBURTON EZ- DRILL BRIDGE PLUG. PT LUB TO 3000 PSI. 08:30 RIH. TAGGED DOWN AT 4771' RKB NO RESTRICTIONS. TIE IN TO SCHLUMBERGER CMT LOG DATED 7/6/98. SET BRIDGE PLUG W/COE @ 4764' TOP @ 4761' RKB. POH. 10:30 RD, LAID DOWN SETTING TOOL. RIGGED UP PUMP AND TESTED 3-1/2" TUBING AND BRIDGE PLUG TO 3000 PSI FOR 15 MIN, BLED TO 2900 PSI, GOOD TEST. 11:45 MU SAVE PERF GUN #1 LOADED 20' HC, DP, 4SPF, 180 DEG PHASING, ORIENT 90 DEG F/LOW SIDE, MPD, CL. TL= 28' RIH. TIE IN W/LOG ABOVE PERFORATE 3-1/2" LINER F/4528' - 4508' RKB. GOOD SURFACE INDICATIONS. 13:15 POH. AT SURFACE RD LUB. ALL SHOTS FIRED. MU SAFE PERF GUN #2, LOADED 17' W/SAME AS ABOVE. RIH. TIE IN AND PERFORATE 3-1/2" LINER F/4508' - 4491' RKB. GOOD SURFACE INDICATIONS. POH. 15:30 AT SURFACE RD. ALLSHOTS FIRED. MU SAFE PERF GUN#3, LOADED 11'W/SAME AS ABOVE. RIH, TIE IN AND PERFORATE 3-1/2" LINER F/4470' - 4481' RKB. GOOD SURFACE INDICATIONS. POH. 17:45 AT SURFACE RD, ALL SHOTS FIRED. LEAVE WELL SHUT IN. NOTIFIED DSO. 0 I:11 I--I--I N G S I~ I:! ~/I r' I~ S 13-Feb-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-109 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD n/a' MD 4,850.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company sURVEY CALCULATION AND FIELD WORKSHEET JobNo. 0450-93469 Sidetrack No. Page 2 of 2 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER- 245 Field KUPARUK RIVER UNIT Well Name & No, 1 D-PAD/1D-lO9(D4) Survey Section Name Definitive Survey BHI Rep. '~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S 59.00 Grid Correction 0,000 Depths Measured From: RKB Target Description Target Coord, E/W Slot Coord. E/W -596.00 Magn. Declination 27.760 Calculation Method MINIMUM CURVATURE Target Direction (DP) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert. Sec. Azim. 331,40 Magn. to Map Corr. 27.760 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F-r) (oD) (DD) (F-T) (FT) (FT) (F-r) (Per ~00 FT Drop (-) Left (-) 09-JAN-98 MWD 3378.66 37,73 333.05 282,20 2924,12 1459.67 1288,62 -685.79 0,25 -0,14 -0.34 6 3/4"MACH 1 C-AKO-1.4 DEG. 09-JAN-98 MWD 3667.20 35.94 331,70 288.54 3155,05 1632.61 1441.89 -765.96 0.68 -0,62 -0.47 09-JAN-98 MWD 3763,78 35.07 331,60 96,58 3233.67 1688.70 1491.26 -792.59 0.90 -0.90 -0,10 09-J^N-98 MWD 3854.28 30.06 331,39 90,50 3309,92 1737,40 1534.05 -815,82 5,54 -5.54 -0.23 09-JAN-98 MWD 3948.56 26,15 332.86 94,28 3393,07 1781.80 1573,28 -836,62 4.21 -4,15 1,56 09-JAN-98 MWD 4042.67 22.86 332.39 94,11 3478,69 1820.82 1607.95 -854.55 3,50 -3,50 -0,50 09-JAN-98 MWD 4135.85 20.76 332,35 93,18 3565,20 1855,43 1638.62 -870,61 2.25 -2,25 -0.04 09-JAN-98 MWD 4326.41 19,58 332.54 190.56 3744,07 1921,12 1696,87 -901,01 0,62 -0,62 0.10 09-JAN-98 MWD 4516,65 18,99 331,25 190,24 3923,63 1983.95 1752.29 -930,59 0,38 -0.31 -0.68 09-JAN-98 MWD ,4642.67 18,56 331,21 126,02 4042.95 2024.51 1787,84 -950,11 0,34 -0.34 -0,03 1 O-JAN-98 MWD 4796.69 18.38 330.42 154.02 4189.03 2073,30 1830.44 -973,91 0.20 -0,12 -0,51 1 O-JAN-98 MWD 4850,00 18,38 330,42 53.31 4239,62 2090,11 1845.06 -982,20 0.00 0.00 0.00 CLO DIST=2091.13 AZ1=331.95 ii I SURVEY CALCULATION AND FIELD WORKSHEET ~o~.o. 0450-93469 Sidetrack No..__ Page 1 of 2 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER - 245 Field ..KUPARUK RIVER UNIT B-'tea''-I/J; :~"~ Well Name&No. 1D-PAD/1D-IO9(D4) Survey Section Name Definitive Survey BHI Rep. Ijllllrr~i~ WELL DATA Target TVD (~r) Target Coord, N/S Slot Coord. N/S 59.00 Grid Correction . 0.000 Depths Measured From: RKB ~ MSL~ SS[- Target Description Target Coord. E/W Slot Coord, E/VV -596.00 Magn, Declination 27.760 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert, Sec. Azim, 331,40 Magn, to Map Corr. 27.760 Map North to: OTHER i i SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FI') (FT) (FT) (Per ~00 FT) Drop (-) Left (-) 0.00 0,00 0.00 0.00 0,00 0,00 0,00 TIE IN POINT 08-JAN-98 MWD 121.00 0.00 0,00 121.00 121,00 0,00 0.00 0.00 0,00 0,00 6 3/4"MACH 1C-AKO-1.4 DEG. 08-JAN-98 MWD 381,1 4 0.91 310.97 260.14 381,13 1,94 1.35 -1,56 0,35 0,35 -- 08-JAN-98 MWD 468.85 2.73 311.76 87.71 468,79 4,56 3.20 -3.64 2.08 2,08 08-JAN-98 MWD 561.41 5,87 315.29 92,56 561,08 11,18 8,04 -8.62 3,40 3,39 3.81 08-JAN-98 MWD 652,43 8.65 320.73 91.02 651.36 22.38 16,64 -16,23 3,14 3,05 5,98 08-JAN-98 MWD 743.52 10.96 322.48 91.09 741,12 37,67 28,82 -25,84 2.56 2.54 1.92 08-JAN-98 MWD 835,04 12,93 323,08 91,52 830,65 56,40 43.90 -37,29 2.16 2.15 0.66 08-JAN-98 MWD 925.05 16.13 323.84 90,01 917,77 78,76 62,05 -50.72 3.56 3~56 0.84 08-JAN-98 MWD 1014.64 19.76 325,61 89.59 1002.99 106,18 84.61 -66,62 4.10 4.05 1.98 08-JAN-98 MWD 1106,58 21.69 327,58 91,94 1088.97 138.59 111.78 -84,51 2.23 2.10 2.14 08-JAN-98 MWD 1203.89 23.06 329.58 97.31 1178,96 175,59 143,39 -103,80 1.61 1.41 2,06 08-JAN-98 MWD 1295.13 25.15 330.77 91.24 1262.24 212.84 175,73 -122,32 2,35 2.29 1.30 08-JAN-98 MWD 1392.12 26.82 331,40 96.99 1349,42 255,33 212.92 -142,86 1,75 1.72 0.65 08-JAN-98 MWD 1487,26 29,06 331,60 95.14 1433.46 299.90 252,10 -164.13 2.36 2.35 0.21 ,. 08-JAN-98 MWD 1582.92 31.09 332.44 . 95,66 1516.24 347,84 294.44 -186,61 2.17 2,12 0.88 08-JAN-98 MWD 1674.93 32.95 332.25 92.01 1594.25 396.61 337.64 -209,25 2.02 2,02 -0.21 08-JAN-98 MWD 1772.65 35.41 332.87 97.72 1675,09 451.49 386.37 -234.54 2.54 2.52 0.63 -- 08-JAN-98 MWD 1868.85 37,32 332.75 96.20 1752.55 508.51 437.10 -260.60 1,99 1.99 -0.12 08-JAN-98 MWD 1962,40 41,81 332.54 93.55 1824.65 568.07 490.01 -287.98 4.80 4.80 -0.22 08-JAN-98 MWD 2246,93 40,06 333.07 284.53 2039.59 754.43 655.81 -373.19 0.63 -0.62 0.19 08-JAN-98 MWD 2529.29 39,19 332.90 282.36 2257.07 934,44 816,24 -454,98 0,31 -0,31 -0.06 08-JAN-98 MWD 2812.87 38.15 334.89 283,58 2478,48 1111,44 975.32 -532.97 0,57 -0,37 0.70 08-JAN-98 MWD 3096,46 38,13 334.02 283,59 2701.53 1286,33 1133,33 -608.49 0,19 -0,01 -0.31 ! SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASi/~n. INC. KRU / iD-109 500292284200 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011098 MWD SURVEY JOB NUMBER: AKMM80078 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -111.40 0 0 N .00 E .00 121.00 121.00 9.60 0 0 N .00 E .00 381.14 381.12 269.72 0 54 N 49.03 W .35 468.85 468.78 357.38 2 43 N 48.24 W 2.08 561.41 561.07 449.67 5 52 N 44.71 W 3.40 .00N .00E .00 .00N .00E .00 1.35N 1.56W 1.94 3.20N 3.64W 4.56 8.04N 8.62W 11.18 652.43 651.35 539.95 8 38 N 39.27 W 3.14 743.52 741.09 629.69 10 57 N 37.52 W 2.56 835.04 830.62 719.22 12 55 N 36.92 W 2.16 925.05 917.73 806.33 16 7 N 36.16 W 3.56 1014.64 1002.95 891.55 19 45 N 34.39 W 4.10 16.64N 16.23W 22.38 28.81N 25.84W 37.67 43.90N 37.29W 56.39 62.05N 50.72W 78.76 84.60N 66.62W 106.17 1106.58 1088.93 977.53 21 41 N 32.42 W 2.23 1203.89 1178.91 1067.51 23 3 N 30.42 W 1.61 1295.13 1262.18 1150.78 25 8 N 29.23 W 2.35 1392.12 1349.35 1237.95 26 49 N 28.60 W 1.75 1487.26 1433.39 1321.99 29 3 N 28.40 W 2.36 111.77N 84.51W 138.59 143.38N 103.80W 175.58 175.71N 122.31W 212.82 212.91N 142.85W 255.31 252.08N 164.11W 299.88 1582.92 1516.16 1404.76 31 5 N 27.56 W 2.17 1674.93 1594.16 1482.76 32 57 N 27.75 W 2.02 1772.65 1674.98 1563.58 35 24 N 27.13 W 2.54 1868.85 1752.44 1641.04 37 19 N 27.25 W 1.99 1962.40 1824.54 1713.14 41 48 N 27.46 W 4.80 294.41N 186.59W 347.81 337.62N 209.23W 396.58 386.33N 234.52W 451.45 437.06N 260.58W 508.47 489.97N 287.96W 568.03 2246.93 2039.46 1928.06 40 3 N 26.93 W .63 655.76N 373.16W 754.37 2529.29 2256.94 2145.54 39 11 N 27.10 W .31 816.18N 454.95W 934.37 2812.87 2478.34 2366.94 38 9 N 25.11 W .57 975.25N 532.93W 1111.36 3096.46 2701.38 2589.98 38 7 N 25.98 W .19 1133.27N 608.46W 1286.25 3378.66 2923.97 2812.57 37 43 N 26.95 W .25 1288.55N 685.75W 1459.59 3667.20 3154.88 3043.48 35 56 N 28.30 W .68 1441.81N 765.91W 1632.52 3763.68 3233.42 3122.02 35 4 N 28.40 W .90 1491.12N 792.52W 1688.55 3854.28 3309.75 3198.35 30 3 N 28.61 W 5.53 1533.96N 815.78W 1737.30 3948.56 3392.90 3281.50 26 8 N 27.14 W 4.21 1573.19N 836.57W 1781.70 4042.67 3478.52 3367.12 22 51 N 27.61 W 3.50 1607.86N 854.50W 1820.72 4135.85 3565.01 3453.61 20 45 N 27.65 W 2.25 1638.52N 870.56W 1855.32 4326.41 3743.88 3632.48 19 34 N 27.46 W .62 1696.77N 900.95W 1921.02 4516.65 3923.44 3812.04 18 59 N 28.75 W .38 1752.19N 930.54W 1983.84 4642.67 4042.75 3931.35 18 33 N 28.79 W .34 1787.75N 950.06W 2024.40 4796.69 4188.84 4077.44 18 22 N 29.58 W .20 1830.35N 973.85W 2073.19 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC. KRU / 1D-!09 500292284200 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011098 MWD SURVEY JOB NUMBER: AKMM80078 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 4850.00 4239.43 4128.03 18 22 N 29.58 W .04 1844.97N 982.15W 2090.00 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2090.10 FEET AT NORTH 28 DEG. 1 MIN. WEST AT MD = 4850 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 331.40 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 4,850.00' MD SPERRY-SUN DRILLING SERVICES ANCHOraGE ALASKA PAGE 3 ARCO ALASKA INC. KRU / 1D-109 500292284200 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011098 JOB NUMBER: AKMM80078 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -111.40 1000.00 989.15 877.75 2000.00 1852.56 1741.16 3000.00 2625.50 2514.10 4000.00 3439.42 3328.02 .00 N .00 E .00 80.58 N 63.86 W 10.85 10.85 512.21 N 299.52 W 147.44 136.59 1079.73 N 582.37 W 374.50 227.06 1592.70 N 846.62 W 560.58 186.09 4850.00 4239.43 4128.03 1844.97 N 982.15 W 610.57 49.99 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA -PAGE 4 ARCO ALAS~ iNC. KRU / iD-~O9 ~0~9228~2~s0 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011098 JOB NUMBER: AKMM80078 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC iNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -111.40 111.40 111.40 .00 211.40 211.40 100.00 311.41 311.40 200.00 411.42 411.40 300.00 .00 N .00 E .00 N .00 E .00 N .00 E .63 N .72 W 1.67 N 1.92 W .00 .00 .00 .00 .00 .01 .01 .02 .01 511.55 511.40 400.00 612.09 611.40 500.00 713.28 711.40 600.00 815.33 811.40 700.00 918.46 911.40 800.00 4.98 N 5.54 W 12.36 N 12.61 W 24.25 N 22.34 W 40.37 N 34.64 W 60.59 N 49.65 W .15 .13 .69 .54 1.88 1.19 3.93 2.05 7.06 3.14 1023.62 1011.40 900.00 1130.76 1111.40 1000.00 1239.20 1211.40 1100.00 1349.62 1311.40 1200.00 1462.10 1411.40 1300.00 87.11 N 68.33 W 119.31 N 89.30 W 155.31 N 110.80 W 196.12 N 133.69 W 241.33 N 158.30 W 12.22 5.15 19.36 7.15 27.80 8.44 38.22 10.41 50.70 12.49 1577.36 1511.40 1400.00 1695.48 1611.40 1500.00 1817.33 1711.40 1600.00 1944.92 1811.40 1700.00 2078.94 1911.40 1800.00 291.87 N 185.26 W 347.51 N 214.44 W 409.37 N 246.32 W 479.73 N 282.64 W 558.91 N 323.78 W 65.96 15.26 84.08 18.11 105.93 21.86 133.52 27.58 167.54 34.02 2210.27 2011.40 1900.00 2340.92 2111.40 2000.00 2470.54 2211.40 2100.00 2599.56 2311.40 2200.00 2727.75 24il.40 2300.00 634.72 N 362.47 W 709.69 N 400.56 W 783.13 N 438.04 W 855.71 N 475.18 W 927.64 N 510.62 W 198.87 31.33 229.52 30.66 259.14 29.61 288.16 29.02 316.35 28.19 2854.92 2511.40 2400.00 2982.07 2611.40 2500.00 3109.20 2711.40 2600.00 3236.31 2811.40 2700.00 3362.77 2911.40 2800.00 998.77 N 543.96 W 343.52 27.16 1069.77 N 577.52 W 370.67 27.16 1140.34 N 611.90 W 397.80 27.13 1210.87 N 646.30 W 424.91 27.12 1279.88 N 681.35 W 451.37 26.46 3489.21 3011.40 2900.00 3613.50 31"i.40 3000.00 3736.78 321!.40 3100.00 3856.17 33~!.40 3200.00 1348.85 N 716.41 W 477.81 26.44 1414.06 N 750.97 W 502.10 24.29 1477.52 N 785.16 W 525.38 23.28 1534.77 N 816.22 W 544.77 19.39 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA .PAGE 5 ARCO ALASKA. iNC. KRU / 1D-109 500292284200 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011098 JOB NUMBER: AKMM80078 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 3969.10 3411.40 3300.00 4078.36 3511.40 3400.00 4185.46 3611.40 3500.00 4291.94 3711.40 3600.00 4398.08 3811.40 3700.00 1581.12 N 840.64 W 557.70 12.93 1620.14 N 860.93 W 566.96 9.26 1654.10 N 878.72 W 574.06 7.10 1686.52 N 895.63 W 580.54 6.48 1718.08 N 912.03 W 586.68 6.14 4503.92 3911.40 3800.00 4609.60 4011.40 3900.00 4715.08 4111.40 4000.00 4820.46 4211.40 4100.00 4850.00 4239.43 4128.03 1748.56 N 928.55 W 592.52 5.84 1778.52 N 944.99 W 598.20 5.68 1807.95 N 961.16 W 603.68 5.49 1836.87 N 977.55 W 609.06 5.38 1844.97 N 982.15 W 610.57 1.51 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ARCO Alaska, Inc. KRU 1D-109 0D:3.500, · SSSV Type: NONE ! Orig Compltn: 1/13/98 Angle @ TD: 18 deg @ 4850 ID:2.992) Annular Fluid: Last W/O: Rev Reason: PERF by vg - Reference Log: Ref Log Date: Last Update: 9/9/98 i Last Tag: 4772 TD: 4850 ftKB Last Tag Date: 8/4/98 Max Hole Angle: 42 deg @ 1962 Casing String; CONDUCTOR::~ 16.000 0 121Ill 121 62.58 H-40 Welded Casing String-SURFACE: :~: :: ::~: ::: Size I Top I Bottomt TVD I 195.W~00 I Grade I Thread NIPPLE 5.500 0 4120 3550 L-80 MBTC (4080-4081, 3.500 4120 4835 4225 . L-80 ABM-EUE 0D:3.500) Tubing String, TUBING : ": :::::i '~: ::i:' . .: ::'.::: ..::::..: : : i'i:: SURFACE ~ Size I Top I Bottom I TVD I Wt I Grade I Thread (0-4120, 3.500I I t I I lo 4120 3550 9.30 L-80 ABM-EUE 0D:5.500, Perforations Summary:~: ::::?::::: :::; ; :: ::::: ;~ :,:: :::::::;: :;::: ; i:::;:: ¥.: :::;~: ::: :i:;:::: ~' ::: ~:: wt:15.50) Interval TVD Zone Status FeetlSPF Date Type I Comment 4238 - 4272 3661 - 3693 341 4 9/8/98 2 1/2" 180 deg. phasing, 90 deg. orient HC, DP 4305-4340 3724-3757 35[ 4 9/8/98 HC, DP 180deg. phasing, 90deg. orient 4350 - 4370 3766 - 3785 201 4 9/8/98 2 1/2" 180 deg. phasing, 90 deg. orient HC, DP 4394 - 4402 3808 - 3815 8 4 9/8/98 2 1/2" 180 deg. phasing, 90 deg. orient HC, DP 4412 - 4448 3825 - 3859 36 4 9/8/98 2 1/2" 180 deg. phasing, 90 deg. orient HC, DP 4470 - 4481 3880 - 3890 11 4 8/4/98 HC, DP 180 deg. phasing, 90 deg. orient SBE 4491 ~ 4528 3899 - 3934 37 4 8/4/98 HC, DP1180 deg. phasing, 90 deg. orient (4120-4121, 4548 - 4562 3953 - 3967 14 4 9/8/98 2 1/2" 1180 deg. phasing, 90 deg. orient OD:4.000) HC, DP Gas LiftMandrelsNalves :i ~:i: ::: ~:. :: ::::: :':i i ::;:i::: ::~ : :: ~: :~ i:~::i : Stn MD TVD Man Man V Mfr VType V OD Latch Port TRO Date Vlv Mfr Type Run Comment 1 4028 3465 BST 3 1/2"X 1" I BST DV 3.5 T-1 O.000 0 6/15/98 AXT I SURFACE Other plugs, equip, etC;), JEWELRY' (4120'4835, Depth TVD Type Description ID 0D:3.500, 4080 3513 NIPPLE W-1 nipple, selective profile 2.812 Wt:9.30) 4120 3550 SBE Baker GBH-22 Locator Seal Assembly w/Baker / Seal Bore Extension. 11.80' 3.000 Seal Assy. 4440 3851 PLUG Set Fast Drill 3.5" bddge plug and tested to 2200 psi. 2.992 4761 4155 PLUG Tested tubing and bridge plug to 3000 psi - good. EZ-Drill Bridge Plug Set @ 2.992 4761. 4834 4224 SHOE I 3.000 General Notes : :::i::: :: : Date Note 7/12/98 PUSHED TUB NG OBSTRUCTION DOWN TO PBTD @ 4772' RKB. SHOE (4834-4835, OD:4.000) 7/24/98 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11363 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: West Sak (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk WS 1D-106 d_~._ ~O CBLSLIM-CMT 980706 I 1 WS 1D-109 ~-- ;~'~ CBLSLIM-CMT 980706 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: Ci !:t I I--C I I~1 G WELL LOG TRANSMITTAL To: RE: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-109, AK-MM-80078 February 11, 1998 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Ji~n Galvin. Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1D-109' 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22842-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22842-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 February 11, 1998. r 9 C- RE: MWD Formation Evaluation Logs 1D-109, AK-MM-80078 The technical dam listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. AP1//' 50-029-22842-00 5631 Silverado Way, Suite G · Anchorage, Alaska99518 · (907)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ~kLASI~A OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 19. 1997 Michael Zanghi Drilling Superintendent ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; West Sak 1 D- 109 (D4) ARCO Alaska. Inc. Permit No 97-_03 Sur. Loc.: 59'FSL, 596'FEL. Sec. 14, T11N, R10E. UM Btmhole Loc: 1920'FSL, 1608'FEL, Sec. 14, T1 IN. R10E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Johnston Chairman x,~~ BY ORDER OF THE COMMISSION dlf/enclosures cc: Department ofFish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Reddll lb Type of Well Exploratory Fi Stratigraphic Test E] Development Oil Re-Entry Deepen Service X Development Gas n-] single zone x Multiple Zone r'] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41' Pad 71' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 59' FSL, 596' FEL, Sec. 14, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1768' FSL, 1528' FEL, Sec. 14, T11N, R10E, UM West Sak 1D-109 (D4) #U-630610 At total depth 9. Approximate spud date Amount 1920' FSL, 1608' FEL, Sec. 14, T11 N, R10E, UM 1/9/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1D-02 4898' MD 1528' @ TD feet 54.8' @ 600 feet 2560 4280' TVD feet i 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 400' feet Maximum hole angle 37.8° Maximum surface 1432 psig At total depth 1882 psig (TVD) 18. Casing program Setting Depth size Specifications Top Bottom Quantib/of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' _+200 CF 8.5" 5.5" 15.5# L-80 BTC MOl: 4095' 41' 41' 4136' 3571' 515 Sx Arcticset III & 8.5" 3.5" 9.3# L-80 8rd 762' 4136' 3571' 4898' 4280' 435 Sx Class G & 60 sx AS I 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: tr%eeaSv~tlcdal ;eeeett Plugs (measured) 0R 161NA L Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth (~t;nUc~tuUcr¢olr R E C E iV E D Surface Intermediate Production DEC l 0 199 ' Liner Perforation depth: measured ~l~ka 0il & Oas Cons. Commission true vertical Anchorage 20. Attachments Filing fee X Property plat [] BOP Sketch [] Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~~://~~~,/~/~///-----~ ¢/~/~"/~/ Title Drilling Superintendent Date Commission Use Only Permit Number APl number I Approval date .~-1 I See cover letter for ~',~-- ~__,.~'~- 50- 0~..-~'.--" ,2_.~___- ~;~/-¢".2.- /,:~ "' ~¢-' other requirements . Conditions of approval Samples required ]-- Yes [~] No Mud Icg required n" Yes [~' No Hydrogen sulfidemeasures [--]Yes r~lNo Directional surveyrequired ]~]Yes [~] No .e.u,redwor in .ressurefor.O.. U! [51 Other: Original .5~g; . David W, ' :-' by order of ¢ ~' uOrlii~LOii Commissioner the commission Date /0~ ~'J Approved by ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor December 9, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-109 (D4) West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1D pad. The well is designed as a monobore injection well using a 5-1/2" x 3-1/2" tapered casing string, with 3-1/2" tubing used as a tieback string. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak pool rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D- 109 (D4), such as shallow gas. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany There have been eight (8) Kuparuk wells and several West Sak wells drilled from KRU 1D pad and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is January 09, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. RECE \/ D Operations Drilling Engineer Attachments CC: West Sak 1 D-109 (D4) Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK-6 Drill, Case and Completion Plan for West Sak 1D-109 (D4) Monobore Iniector General Procedure: o Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. , Spud and directionally drill 8-1/2" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. NOTE: A 9-7/8" hole may be drilled depending on the hole conditions encountered. 4. Condition hole for casing, trip out. . Run and cement 3-1/2" 9.3# L80 8RD x 5-1/2" 15.5# L80 BTC tapered casing string to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. , Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3000 psi. , Pick up 4-3/4" mill tooth bit, 3-1/2" drill collars, and 2-7/8" drill pipe. Trip in and drill out stage collar. Clean out to top of 3-1/2" casing. . Pressure casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. . Swap well over to non-freezing completion brine. Circulate well clean. Trip out. 10. Rig up and run 3-1/2" tubing tieback to surface for monobore injector. Sting into seal bore and pressure test tubing and annulus to 3,000 psi. Set tubing hanger. Install back pressure valve. 11. Nipple down BOP stack. Install production tree and pressure test same. 12. Secure well, release rig. Page 1 13. 14. 15. 16. 17. Rig up Coiled Tubing Unit (CTU) and clean out 3-1/2" monobore tubing to PBTD. Circulate well to clean brine. Secure well and release CTU. Rig up E-line unit and RIH with CBL/CET, and run cement bond log across West Sak interval. Report results to office for remedial action if necessary. Rig up E-line unit and RIH with through-tubing perforating guns. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired West Sak intervals. Rig down E-line unit. Install back pressure valve, shut in and secure well. TAB, 11/20/97, Rev.1 Page 2 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1 D-109 (D4) Drilling Fluid Type Extended Bentonite Slurry Drilling Fluid Properties' Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.5-9.0 ppg 35-70 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.5-10.0 ppg 35-70 20-35 5-15 10-35 5-10 8.0-9.5 8-12% Drilling Fluid System' Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page 1 Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A tapered 5-1/2" x 3-1/2" surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately 200 feet TVD below the base of the permafrost interval. MASP (Maximum Anticipated Surface Pressure)' Since a separate string of surface casing is not planned for the West Sak 1D-109 (D4) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. Based on actual well test data from the nearby WSl-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/fi, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the -i'VD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.6 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a 'I'VD of 3,658' MD/I'VD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WSI-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base in the West Sak 1D-109 (D4) well to surface, the following MASP can be computed: MASP = (4092 ft)(0.46 - 0.11 psi/ft) = 1432 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 5-1/2" x 3-1/2" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 5-1/2" 15.5# LB0 BTC casing to be used has a burst rating of 7,000 psi; 70 % of this burst rating is 4,900 psi. After testing, a 3-1/2" tubing tieback string will be installed in the well to be used as the injection string. Page 2 Drillinq Area Risks: Drilling risks in the West Sak 1D-109 (D4) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-109 (D4). Well Proximity Risks: The nearest existing well to West Sak 1D-109 (D4) is KRU 1D-02. As designed, the minimum distance between the two wells would be 55' at 600' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of an existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. In addition, the West Sak 1D-109 (D4) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 3-1/2" tubing tieback string and prior to the drilling rig moving off of the well. TAB, 12/O8/97 Page 3 250 75C -i ~250 1500 1750 2000 2250 2500 2750 5000 3250 3500 3750 4000 RKB ELEVATION: 1 i2' 'ARCO Ala ' Structure : Pad 10 Well: D4 Field : Kuparuk River Unit Location : North Slope, Alaska TD LOCATION: ig20' FSL, 1608' FEL SEC, 14, T11N, RIOE KOP TVD=400 TMD=400 DEP=O 3.00 BEGIN TURN TO TARGET TVD=600 TMD=600 DEP=IO 8.82 4250 45ool , , , , , , , , , , , , , , , , , 0 250 500 750 1000 ;250 1500 i750 2000 2250 Vertical Secfion (feet) -> Azimuth 551.40 with reference 0.00 N, 0.00 E from slot #109 <- West (feet) 1200 1050 900 750 600 450 300 ~ 50 0 k 1950 TD - Casing Pt Base West Sak Sands k 1800 / TARGET - A5 I West Sok Sands (EOD) 1650 i500 Begin Angle Drop / tl.73 k1350 ., 1768' FSL, 1528' FEL 17.64 DLS: 5.00 deg per 100 ft I SEC. 14, TllN, RIOE k~200 ~ 23.59 TVD=3807 TMD=4594 ~- 1050 '~ 26.57 DEP=1947 j ~. 2956 NORTH !709 , ~~5,~ ~ 900 ~ EOC ~D=1584 TMD=1674 DEP=402 ~ ~ 1947' (~O TAR,?ET) k MAXIMUM ANGLE~ RE~ ~lV E D ~ ~;oo ~ ' I 59' F~L, 596' FEL 50.07 BLS: 3.00 deg per 100 f[ ' SEC. 14, TI1N, RIOE~ 27.07 24.07 ~D~~=4~P~892 % 21.07 TARGg~ - A3 TVD=3807 TMD=~39~ ~D~9~M~4698 DEP=2050 k ..................... ~, TARGET ANGLE T. - cs~ r~ wr:~ao z~,:~a~a ~sv=~ ~,~ ~0 DEG Z O For: T McKAY Date i~atted : 28-0ct-97 Reference is ~ 1D-lOg/D4 Vets. ~2. CocrOinotes ere ~n leer reference slot ~109. De,ms ore ref~e~ce RK8 (Porker ARCO ALASKA, inc.I Field : Kuparuk River Unit Location : North Slope, Alaska! J <- West (feet) 220 200 180 i 60 140 : 20 1 O0 80 60 40 20 0 20 40 60 80 i ", 899.99 '. 260 ~ "'. 1800 " 260 . ', 700 ~, [- 240 240 I "' i ' ~ ',~ 1400 .,. q ', L1600 ', 220 -~ ',, ~, 2500 ~- 220 ,, ~ " ~ 1500 , " ~ ~ 120o 200 ~ ",, ~ 400 ,, 'k 1500 " ', i 60 ~ '", ,/ 160 ' 1600 ~ 2400 140 ',,,1200,,,, ~ ,' '",,,, ~ ;:,¢ /,ooo;~ ~ ' o z ',1100 700 --"~;'~ ', ', 1 oo · ~ 1000 ',,,,, 07~,,,,/' JuO ~ ",, ~oo~ /~2oo :: ~o ',,, goo · , e'~oo ~': L '~ 800 , ', ~ 2200 "~ 700 ,, ~ 20 '-~ 1100 '"~ 500 i o ".. " .. 20 "-.. ~ 21 ~0 20 '"--~ 1000 "--~ ~00 ~~ 200 60 "'"- ~300 ~2000 ~ 60 "--. ~ "~ 800 t ~ , , , , , , ~ , ' ' ' ~ ~ 8~0 ' 6'0 ~ 4'0 ~ 2~0 ~ ~ ' ~ ' 6'0 ' 8'0 2 0 200 !80 160 140 120 t00 20 40 <- West (feet) ! Creot.d oy ,;.~. For: T McKAY Dote ¢~otted : 28-0ct-97 p~ot ~eference ;s w~ ID-lOg/D4 Vera. ~2. T~e Coordinates a~ in feet reference slot ~1~. Ve~icol 0ept~s are reference RK8 (Parker ~2~5~. 'ARC 0 ALASKA, nc. Structure: Pad 1D Well: D4 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 1600 1500 1400 ~ 500 1200 i 1 O0 1000 900 800 700 600 500 400 500 200 ~ O0 0 2000I , ~ ~ ~ ~ ~ ~ I : I I ~ ~ : ~ i ~ ~ ~ ~]\ t ! ~ ~ ~ ~ ~ t , , I 2000 1900 ~ ~4200 1900 ] "~ 4-200 , ~eoo ~ ,~, ~1oo ~4~oo h ~oo t '~. 4000 q '~ 3900 i '~, 3700 4000 r ~ 700 - %, 5600 % ~ : 600 ~ '~ 5500 ~ 600 "x~ 3400 ~3900 ,5oo "~ 5500 ~ ',, ~ 5800 ~ 500 "~, 5200 ~ ~ ~ 1400 .400 %,,~100 ~700 600 I '"~ 2900 ~ 1200 28OO X k~°° ~ t 4oo ~oo xh 2200 ~ ""x ~3000 "-.~ 2300 '~x~l O0 ~2~00 700 6o0 """'- xx,, .... 2600~ 500 "--~ 2000 ........ ,oo "-~ 1900 X ~ P '-....... '~ 1 700 2400 ~ 400 '-. 1800 ', ~ ~ 400 -......... x,. 1600 ~ L --. 1700 ~ ""-...... 300 'xt 1500 ~ 300 -~ 1 600 '"~ 1400 ~ "--...% ""-.-. , ;i 1600 ! 500 1400 1500 1200 I 1 O0 i 000 900 800 700 600 500 400 ZOO 200 1 O0 0 <- West (feet) ~ 500 A ~ 200 I 1100 ' 000 (- 0 z goo 7O0 ARCO ALASKA, Inc. Pad 1D D4 slot #109 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : WS 1D-109/D4 Vets. #2 Our ref : prop2217 License : Date printed : 28-0ct-97 Date created : 17-Apr-97 Last revised : 8-0ct-97 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 18 1.896,w149 30 36.284 Slot Grid coordinates are N 5959723.678, E 560490.481 Slot local coordinates are 59.00 N 596.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEA/~tNCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PGMS <0-8365'>,,1,Pad 1D TOTCO Survey,,WS-8,Pad 1D PG~MS <0-8930'>,,5,Pad 1D PGMS <0-7502'>,,4,Pad 1D PGMS <0-8070'>,,3,Pad 1D PGMS <0-9783'>,,2,Pad 1D PGMS <0-8610'>,,6,Pad 1D MSS <3311-8200'>,,7,Pad 1D WS 1D-130/H4 Version #4,,H4,Pad 1D P~S <0-?????>,,H4,Pad 1D WS 1D-105/C7 Version #4,,C7,Pad 1D WS 1D-118/E5 Version #4,,ES,Pad 1D WS 1D-119/F4 Vers.#3,,F4,Pad 1D WS 1D-120/F6 Vets. #3,,F6,Pad 1D WS 1D-106/D6 Vers.#3,,D6,Pad 1D WS 1D-124/G3 Version #3,,G3,Pad 1D WS 1D-129/J3 Version #3,,J3,Pad 1D WS 1D-133/J5 Version #4,,JS,Pad 1D WS 1D-135/G7 Version #4,,GT,Pad 1D WS 1D-115/E3 Version #4,,E3,Pad 1D WS 1D-117/E7 Version #4,,ET,Pad 1D WS 1D-121/G5 Version #3,,GS,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance 4-Aug-92 16-Oct-96 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 25-Oct-97 25-Oct-97 27-0ct-97 28-Oct-97 22-Oct-97 28-0ct-97 6-Oct-97 6 -Oct- 97 8-Oct-97 22-Oct-97 22-Oct-97 22-Oct-97 22-0ct-97 28-0ct-97 28-0ct-97 23-0ct-97 101.9 661.4 302.0 182.1 61.7 54 8 422 0 542 0 465 0 464 9 75 0 165 0 210 0 225.0 32.1 330.0 450.0 510.0 585.0 112.0 149.8 240.0 M.D. Diverging from M.D. 1175.0 4640.0 400.0 400.0 20.0 400.0 20.0 20.0 240.0 400.0 600.4 600.4 20.0 20.0 400.0 400.0 4O0.0 40O.O 4O0.0 4OO.O 450.0 450.0 400.0 400.0 400.0 400.0 400.0 400.0 775.0 775.0 400.0 400.0 300.0 300.0 300.0 300.0 400.0 400.0 650.0 650.0 525.0 525.0 400.0 400.0 West Sa~ 1 D-109 (D4) Monobom Injector Well Proposed Completion Diagram Tapered Monobore Injector Isolate Injection Thief Zones Using Patches 3-1/2" Tubing 9.3# L-80 8RD EUE (tied back to surface from Seal Bore/PBR) 16" Conductor Casing @ 80' Weatherford Gemoco 754HO 5-1/2" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) 5-1/2" Combination Surface/Production Casing 15.5# L-80 BTC (Cemented to Surface) Baker Seal Bore Extension - 12' Size 80-40 with 80-40 bottom sub to 3-1/2' tbg and 80-40 top sub, 5-1/2' to 3-1/2' (ASN 461-3435) (positioned +/- 100' above perfs) XO From 5-1/2" Casing to 3-1/2' Casing D Sands B Sands A Sands 3-1/2" Tapered Casing/Tubing 9.3# L-80 8RD EUE (Cemented to Surface) ARCO Alaska, Inc. TAB, 11/20/97, Rev. 1 KUPARUK'"RIVER UNIT- WEST ~AK OPERATIONS 20" DIVERTER SCHEMATIC 6 I4 3 2 HCR I DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVEAND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) RECEIVED Naska 0il & Gas Cons. 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"- 2000 PSI ANNULAR PREVENTER. TWM, 9/15/97 8 , 7 6 5 4 '13 5/8" 5000'PSI BOP STACK West Sak Operations - Injector Wells AC¢¥MULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. \ BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. 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. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BI I=ED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES. LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE Bo'FrOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILUNG POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 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 DALLY. VBRS WILL ACCOMODATE 3-1/2" TO 6" OR 4-1/2" TO 7" PIPE ODS AS APPROPRIATE. 1. 16" - STARTING HEAD 2. 7-1/16' - 5000 PSI TUBING HEAD 3. 7-1/16" - 5000 PSI X 13-5/8" - 5000 PSI DOUBLE STUDDED ADAPTER/SPACER SPOOL 4. 13-5/8' 5(:X)O PSI X 13-5/8" 5000 PSI SPACER SPOOL 5. 13-5/8' - 5000 PSI PIPE RAMS 6. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 7. 13-5/8" ~ 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 8. 1 3-5/8" - 5000 PSl ANNULAR TWM, 9/18/97 fATE ~Y ' .]X I APP ~ . 2E$CRIPT!ON 1 !9/02/971 AJR j PC i i AS-BUILT PER KSB~ K97082ACS D.S. 1-D 0 1 10$~) 2 O $ 11,5 · 117 llA 8 4 llg · 120 · · 121 · 124 0 6 · 129 · 150 e 133 e 135 0 8 - i 2 i9/17/97i 14 1.3 2.3 24 o ,~,,. 10 S. iB 21 DESCRIPTION ,AS-BUILT PER KS~ Kg7082ACS / : ~',~ST SAK-t THIS SURVEY VICINITY MAP SCALE: 1" = I MILE NO $CA1.£ LEGEND 0 EX/STING CONDUCTORS · NEW CONDUCTOR LOCA UON ARCO Alaska, inc. LK610410 9/02/97 SEE SHEET # 2 FOR NOTES AND LOCATION INFORMATION LOUNSBURY & ASSOCIATES, INC. E,~NEgRS PLANNERS SURVEYORS AREA: 1D MOOULE XX UNIT: 01 DRILL SITE 1-D WEST SAK PHASE I - WELL CONDUCTORS AS-BUILT CEA- D 1D X-6104010 J SHEET: 2 , ]'~ i Apl~ ~ DESCRIPTION REVI '~,TE i ~y ~, GK ! aPP I DESCRIPTION .fiEV~ OATE ~ ~' i ' 1 mg/02/97j AdR j ~C J j AS:~UmLT PER K~J Kg7082ACS J 2 jg/17/g7J A~ I PC J AS BUILT PER K~J Kg7~2A~ ,.VOTES . ,. ~ /. S[A LE~L. ALL DISTANCES SHO~ ARE TRUE. j , UONU~ENTS PER LHD ~ND ~SSOCI~. , ', ~ E tz ~ 23, TO~SHIP 11 NOR~, RANGE 10 EAS~ U.M. ~ ~- / ~~~ 4. OA~ OF SUR~: 8/25, 29 ~ ~0/97, FIELD 8K L97-24,~w'/ I ~ j-~) ~ ~ST FRO~ A.S.P. ZONE 4 GRID NOR~. CF CONDUCTORS ~1 ~ROUGH t8. . , ~, . ~ . ~.~.~. , ~CINI ~ gAP ....... %'%>. ...... ~ v ~ 'eeeee.eeee*~ ~ ~ S~c. ~4, T. lt N., R.?O ~. ~'L'~'~'L'' log 5, g59,72~.89 560,490.60 70' 18' 01.898' 149' ~0' ~6.2~0' 59' 596' 70.4' 62.7' S,~c. 23, T. 11 N., R. 10 E. F.N.L.F.E.L. , ~5 5.959.603.93 560.490.68 70' ~a'.oo. 7~a' ~49' ~0' ~6.3~' 6z' 5gz' 70.4' 1,7 5,959,57J. 95 ~0.4~.65 70' 18' ~.42J' ~49' JO' J6. J14' 9~' 597' ' ~ ~8 ! 5.959,558.95 560.490.68 70' ~a' oo.276' r4g' Jo' J6. jt6' ~' ~ 597' 7o. 4" 6~4' ~t9 I 5,959,5tj. 86 : 560,490.72 70' ~7' 59.832' ~49' Jo' J6. J26' i51' ~ 598' 7~6" 6~.o' ,20 ~,~5~.~.o~ 5~o.,~o. zz ~o' rz' 5~.~a~' ~' ~o' ~6.~2z' ~6~' 5~e' zo.~' 6~.o' 12I ~.959.48~.89 560.490.67 70' ~7' 59.5~8' ~49' ~o' ~6.~5- ~at' I 598' ~ 70.5' ~s.o i ~z, ~ ~.~5~.~9~.~ 5~o.~0.~o zo' zz' 5e.~5~' ~' ~o' ~.J55' 2~' ~ 5~' r zo. J' ~o' ~o ~.~5~.25~.o~ 5~o.~o.e~ zo' ~z' 5z.~2~' ~' ~o' ~6.~' ~' ~oo' ~o.~' ~ ~' I~ 5,9~,21~.~ 5~0,4g0.68 70' 17' 5~.~2' 14~' ~0' ~.~97' ~51' ~' ' 70.~' : ~.0' ! tJ5 5,959, l~9.02 5~0,490.80 ~ 70' 17' 56.146' , 149' ~0' ~6.412' j526' 601' 70.5'I. 69.4' 5UR~YOR'E CER~RCA ~ I HEREBY CERnFY ~AT i AV P~OPERL Y REG/S~RED A SURLY OONE BY ~E OR UNOER ~Y O/RECT SUPERWSION AND ~Ar ALL DIMENSIONS AND O~ER ~/]~ k ASSOC~TES, INC. DETAILS ARE CORRECT AS OF AUGUST 30, 199Z ~'~N~ P~N~ ~EA: 1D M~U~: ~ UNIT: D1 ~ DRI~ Si~ 1-D ARCO Alaska, Inc. - co, uc o,s C DFILENO. JORA NG ~610410 9/02/97 CEA-D1DX-610~10 2 ~ 2 2 No. ,y, A.S.P.$ 'X' LA T1TUDE LONGITUDE ELEV. ELEV. S,;c. 14, T. 11 N., R. IO E. F.S.L.F,£.L. ~05 5.959.796.99 560.490.57 70' 18' 02.6:7' ~49. `30' `36.26.~' ~.~4' 595' 70.5' 62.0' ,06 5,959,766.9J 560,490.67 70' 18' 02..,T4~" ~49' u~O' .36.268' ~04' 595' 70.4' ,09 5,959,72`3.89 560,490.60 70' 18' 01.896' 149' `30' `36.280" 59' 596' 70.4' 62.7' S,;c. 23, 7'. 11 N., R. 10 E. F.N,L,F.E.L. ,~5 5.959.60.~.9.~ 560.490.66 70' 16'.00.7~a' ~49' `30' :6..~0~' 6~' 597' 70.4' 6.~4' ~,a 5.959.556.95 560.490.66 70' ~a' 00.276' ~49' `30' `36.j~6' ~06' 59z' 70.4' 6[4' ,19 5.959.51z66 560.490.~z 70' ~7' 59.a.~2' ~4~' ~0' `36..~26' ~5~' 596' 7~6' 66.0' ,20 5.959.~9~.01 560.490.77 ~0' ~7' 59.666' ,~9' `30' `36..~27'~66' 596' 70.6' 66.0' ,2~ 5.959.~6z69 560.490.67 70' ~' 59.5~a' ~' ~0' ~.~5' ~a~' 5~a' ~0.5' ~.0 ~ ~,95~,~9~.9~ 5~0.~0.~0 ~0' ~r ~a.~5~' ~' ~0' ~.~55' 2~' 5~' ~0.~' ~0' ~29 ~,~5~,2~z9~ ~0,~0.~ ~0' ~' 5z~x2' ~' ~0' ~.~0' ~' ~' ~o.J' ~0 ~,~5~,25~.09 5~0,~0. a~ ~0' ~' 5z~26' ~' ~0' ~6.~' ~' ~00' ~0.~' ~2' ~ 5,959,2~.89 ~0,490.68 70' 17' 56.~2' ~49' ~0' ~6.~9~' 45~' 6~' 70.4' 6~.0' t35 5,959,~9.02 560,490.80 70' ~7' 56.~46' 149' ~0' ~6.412' 526' 60~' 70.5' 6A4' · FIELD & POOL, WELL PERMIT CHECKLIST COMPANY C ASS ADMINISTRATION R DATE, WELL NAME .,~/, GEOL AREA ENGINEERING APPR ~--DA.TE 1. Permit fee attached ....................... N 2. Lease number appropriate ................... N 3. Unique well name and number .................. N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unit boundary .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included .............. N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N PROGRAM: exp [] dev [] redrll [] serv~wellbore seg F: ann. disposal para req I-i UNIT# _//,,//~/~',-~r ON/OFF SHORE <~¢L/ GEOLOGY APPR D~TI~ 14. Conductor string provided ................... ~ N 15. Surface casing protects alt known USDWs ........... (..y2 N 16. CMT vol adequate to circulate on conductor & surf csg ..... ~ N 17. CMT vol adequate to tie-in long string to surf csg ........ ~) ~N 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. N 21. If a re-drill, has a 10-403 for abandonment been approved...~N 22. Adequate wellbore separation proposed.... .......... ~N 23. If diverter required, does it meet regulations .......... ~ N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ..... ~¢r:z¢~ .... Ps:~g; N 26. BOPE press rating appropriate; test to N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. YNC REMARKS 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N ~ /,, //,) 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. Y, 33. Seabed condition survey (if off-shore) ............. /,~' N 34. Contact name/phone for we,eklyprogress reDo, ds ....... ,/Y N lexp~oratory on~yj GEOLOGY: RPC A¢¢~('' / ~ ENGINEERING: COMMISSION' JDH ..M" RNC (_,/,.¢f_~,~,,/ Comments/Instructions: HOW/lil - A \FORMS\nhPkh.~I rc, v oR/q? Well History 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 APPENDIX. , No special effort has been made to chronologically organize this category of information. i\ U/r~ I q 7 - ;¿ J )- Memory Multi-Finger Caliper Log Results Summary II' Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. August 15, 2005 7011 1 3.5" 9.3Ib. L-80 Tubing & Liner Well: 1 D-1 09 Field: Kuparuk State: Alaska API No.: 50-029-22842-00 Top Log IntvI1.: Surface Bot. Log IntvI1.: 4,159 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the "W-1 JJ Nipple @ 4,080' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing and liner with respect to corrosive and mechanical damages. The 3.5" tubing and liner logged appear to be in good to poor condition with respect to corrosive damage, with a maximum wall penetration of 60% in joint 130 (4,157'). Wall penetrations ranging from 20% to 60% are recorded in 88 of the 139 joints logged. The damage appears in the forms of general corrosion, isolated pitting, and lines of corrosion. A line of corrosive damage is recorded in the interval between joints 61 and 130 (1,950' - 4,159'). No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing and liner logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WAll PENETRATIONS: Line of Corrosion Line of Corrosion Line of Corrosion Line of Corrosion Line of Corrosion ( 60%) ( 57%) ( 57%) ( 55%) ( 54%) Jt. Jt. Jt. Jt. Jt. 130 @ 71 @ 117 @ 97 @ 110 @ 4,157 Ft. (MD) 2,252 Ft. (MD) 3,673 Ft. (MD) 3,059 Ft. (MD) 3,477 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss (> 6%) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing and liner logged. SEP :? :;); I Field Engineer: W McCrossan Analyst: M. Tahtouh Witness: T. Senden ProActive Diagnostic Services! Inc. I P,O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1.369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 clds" Well: Field: Com pany: Country: 1 0-109 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Weight 9.3 ppf Grade & Thread l-80 Nom.OD 3.5 ins Penetration and Metal Loss (% wall) _ penetration body 120 100 80 60 40 20 o JaIl metal loss body o to 1% 1 to 10% 1 0 to 20 to 40 to ove r 20% 40% 85% 85% Number of joints analysed (total = 139) pene. 0 7 44 38 50 loss 39 1 00 0 0 0 o o Damage Configuration ( body) 80 60 40 20 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 121) 37 11 73 0 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 2.992 ins August 15, 2005 MFC 24 No. 00387 1.69 24 M. T ahtouh Upper len. 1.2 ins lower len. 1.2 ins Nom. Upset 3.5 ins Damage Profile (% wall) ~ metal loss body 50 _ penetration body o O~ ==- ~ :æ: § 100 ~ 47_ --- ===- '-- I ~ ~ It '~. ~ l = GlM 1 I 9l l" Bottom of Survey = 130 Analysis Overview page 2 '~ i PDS KEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 0- 1 09 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 2.992 in Country: USA Survey Date: August 15, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) ¡Yo (Ins.) 0 50 100 .1 36 0 0.03 1 1 ~ 2.90 PUP 1 39 0 0.03 13 6 2.92 Shallow corrosion. 1.1 69 0 0.01 5 1 2.92 PUP 1.2 79 0 0.03 13 0 2.91 PUP Shallow corrosion. 1.3 81 0 0.03 1 1 1 2.88 PUP 2 90 0 0.02 9 1 2.94 3 121 0 0.03 12 1 2.94 4 153 0 0.03 11 1 2.95 5 184 0 0.03 13 2 2.93 Shallow pitting. 6 215 0 0.04 15 2 2.92 Shallow corrosion. 7 246 0 0.03 12 2.95 8 278 0 0.03 13 2.93 Shallow pitting. 9 309 0 0.03 12 2.94 10 340 0 0.03 13 2 2.94 Shallow pitting. 11 372 0 0.04 14 ") 2.93 Shallow pitting. 12 404 0 0.03 10 1 2.94 13 435 0 0.03 13 3 2.93 Shallow pitting. 14 467 0 0.03 12 2 2.95 Shallow pitting. 15 498 0 0.04 14 2 2.93 Shallow pitting. 16 530 0 0.03 12 2 2.93 Shallow pitting. 17 561 0 0.03 13 1 2.93 Shallow corrosion. 18 592 0 0.03 11 2 2.94 19 624 0 0.03 13 2 2.92 Shallow corrosion. 20 655 0 0.03 13 2 2.90 Shallow pitting. 21 687 0 0.02 6 2 2.93 22 717 0 0.03 12 2.93 Shallow pitting. 23 748 0 0.03 10 2.92 24 780 0 0.04 14 2.91 Shallow pitting. 25 811 0 0.02 9 2.93 26 843 0 0.04 16 2.89 Shallow corrosion. 27 871 0 0.03 12 2.92 28 902 0 0.03 12 2.93 29 934 0 0.03 10 2.93 30 964 0 0.03 13 2.91 Shallow pitting. 31 995 0 0.03 12 2.91 32 1025 0 0.03 13 2.92 Shallow pitting. 33 1057 0 0.03 12 2.91 Shallow pitting. 34 1088 0 0.04 15 2 2.92 Shallow corrosion. 35 1120 0 0.04 14 1 2.91 Shallow pitting. 36 1151 0 0.03 13 0 2.92 Shallow corrosion. 37 1183 0 0.04 14 1 2.93 Shallow corrosion. 38 1214 0 0.04 14 1 2.93 Shallow pitting. 39 1245 0 0.03 11 1 2.94 40 1277 0 0.05 20 1 2.93 Shallow pitting. 41 1308 0 0.07 30 2 2.92 Isolated pitting. 42 1340 0 0.05 20 2.92 Isolated pitting. 43 1371 0 0.06 23 2.93 Isolated pitting. 44 1403 0 0.05 20 2.92 Shallow pitting. 45 1434 0 0.07 26 2 2.92 Isolated pitting. 46 1465 0 0.06 22 2.92 Isolated pitting. I Penetration Body H:iì'i Metal Loss Body Page 1 PDS(KEPORT JOINT TABULATION\ SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 0-1 09 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal J.D.: 2.992 in Country: USA Survey Date: August 15, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins.) (Ins.) (X) (Ins.) 0 50 100 47 1497 0 0.05 18 2 2.93 Shallow pitting. 48 1528 0 0.06 22 6 2.92 Isoalted pitting. 49 1559 0 0.05 21 1 2.91 Isolated pitting. 50 1589 0 0.05 20 2 2.92 Isolated pitting. Lt. Deposits. 51 1620 0 0.03 13 2.90 Shallow corrosion. 52 1652 0 0.09 35 2 2.93 Isolated pitting. 53 1683 0 0.06 24 2 2.93 Isolated pitting. 54 1714 0 0.05 20 2 2.91 Shallow pitting. 55 1746 0 0.06 22 2 2.92 Isolated pitting. 56 1777 0 0.07 27 2.93 Isolated pitting. 57 1809 0 0.06 24 2.92 Isoalted pitting. 58 1840 0 0.07 27 2 2.92 Isolated pitting. 59 1872 0 0.05 21 1 2.90 Isolated pitting. 60 1903 0 0.06 24 1 2.92 Isolated pitting. 61 1934 0 0.11 43 2 2.92 Line corrosion. 62 1965 0 0.08 33 2 2.92 Line corrosion. 63 1994 0.06 0.09 36 2 2.92 Line corrosion. 64 2023 0 0.09 34 4 2.92 Line corrosion. 65 2055 0 0.09 37 2 2.93 Line corrosion. 66 2086 0 0.07 29 4 2.93 Line corrosion. 67 2118 0 0.09 36 3 2.92 Line corrosion. 68 2148 0.08 0.10 41 3 2.93 Line corrosion. 69 2180 0.07 0.13 51 4 2.92 Line corrosion. 70 2211 0.06 0.13 53 4 2.92 Line corrosion. 71 2241 0 0.14 57 4 2.91 Line corrosion. 72 2271 0.07 0.10 40 3 2.92 Line corrosion. 73 2302 0.05 0.12 47 3 2.93 Line corrosion. 74 2334 0 0.12 49 4 2.90 Line corrosion. 75 2364 0 0.13 50 4 2.91 Line corrosion. 76 2395 0 0.09 36 3 2.91 Line corrosion. 77 2427 0 0.10 38 3 2.90 Line corrosion. 78 2458 0 0.12 46 3 2.91 Line corrosion. 79 2488 0 0.12 49 3 2.92 Line corrosion. 80 2520 0.06 0.10 37 3 2.93 Line corrosion. 81 2549 0.07 0.12 49 4 2.92 Line corrosion. 82 2581 0 0.13 53 3 2.93 Line corrosion. 83 2612 0 0.09 37 4 2.92 Line corrosion. 84 2642 0 0.10 39 4 2.93 Line corrosion. 85 2674 0 0.11 43 4 2.93 Line corrosion. 86 2704 0 0.10 41 3 2.93 Line corrosion. 87 2736 0 0.09 35 3 2.94 Line corrosion. 88 2767 0 0.10 40 2 2.92 Line corrosion. Lt. Deposits. 89 2796 0.06 0.10 41 ..., 2.92 Line corrosion. :J 90 2827 0.07 0.11 42 3 2.92 Line corrosion. 91 2859 0.11 0.11 44 3 2.90 Line corrosion. 92 2890 0 0.11 45 3 2.91 Line corrosion. 93 2922 0 0.11 42 3 2.91 Line corrosion. 94 2953 0 0.10 39 4 2.93 Line corrosion. 95 2985 0.06 0.11 45 3 2.92 Line corrosion. 96 3016 0 0.12 49 5 2.92 Line corrosion. Lt. Deposits. I Penetration Body ~:~::; Metal Loss Body Page 2 ¡ PDS'KEPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: N ominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Joint Jt. Depth Pen. Pen. Pen. Metal Min. No. (Ft.) Upset Body DID Loss 1.0. (Ills. ) (Ins.) 01 (Ins.) /0 97 3046 0 0.14 55 4 2.93 98 3078 0 0.10 39 4 2.90 99 3107 0 0.14 54 4 2.92 100 3138 0 0.12 48 4 2.92 101 3170 0 0.11 44 4 2.93 102 3201 0 0.14 54 5 2.93 103 3233 0 0.13 50 4 2.93 104 3264 0 0.12 49 3 2.93 105 3295 0 0.13 50 4 2.92 106 3326 0 0.11 43 4 2.92 107 3357 0 0.11 44 4 2.92 108 3389 0 0.12 47 4 2.92 109 3420 0 0.13 50 3 2.90 110 3451 0 0.14 54 3 2.90 111 3483 0.08 0.08 31 1 2.91 112 3514 0 0.11 44 5 2.93 113 3546 0 0.10 39 3 2.93 114 3576 0 0.12 48 4 2.93 115 3607 0 0.12 46 4 2.92 116 3639 0 0.12 49 4 2.92 117 3670 0 0.14 57 4 2.92 118 3702 0 0.12 46 3 2.92 119 3732 0 0.11 44 3 2.93 120 3761 0 0.10 39 4 2.93 121 3793 0 0.11 43 2 2.91 122 3824 0 0.14 54 3 2.92 123 3855 0 0.09 34 3 2.92 124 3887 0 0.11 43 4 2.93 125 3918 0 0.09 36 4 2.93 126 3950 0 0.12 47 4 2.92 127 3981 0 0.12 48 3 2.93 127.1 4011 0 0.11 43 3 2.92 127.2 4027 0 0 0 0 N/A 127.3 4033 0.06 0.09 35 3 2.94 128 4048 0 0.14 54 4 2.90 128.1 4080 0 0 0 0 2.81 129 4082 0 0.12 47 4 2.92 129.1 4113 0 0.08 30 4 2.91 129.2 4119 0 0.07 26 1 2.98 129.3 4131 0 0 0 0 N/A 129.4 4141 0 0.03 13 1 2.91 130 4147 0 0.15 60 3 2.91 Well: Field: Company: Country: Survey Date: 1 0-1 09 Kuparuk ConocoPhillips Alaska, Inc. USA August 15, 2005 Comments Line corrosion. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. PUP Line corrosion. GLM (Latch @ 11 :30) PUP Line corrosion. Line corrosion. Lt. Deposits. W-l NIPPLE Line corrosion. PUP Isolated pitting. Lt. Deposits. Seal Line of pits. Seal Bore Extension PUP Shallow corrosion. Line corrosion. 1 st Jt. of Liner Page 3 Damage Profile (% wall) o 50 100 I I I.. .. .. ... .. .. ... .- .. . II.. . ~ I I I I I Penetration Body i::~;\! M~tal Loss Body .~~ )- ~ .-. /- ~s ~ ""Jr. PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0-109 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-BO Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 15! 2005 MFC 24 No. 00387 1.69 24 M. T ahtouh Cross Section for Joint 130 at depth 4156.75 ft Tool speed = 47 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 97 % Tool deviation = 24 0 Finger 11 Penetration = 0.152 ins Line of Corrosion 0.15 ins = 60% Wall Penetration HIGH SIDE = UP Cross Sections page 1 cId· -. ..~.. "... ~., ..... '. ...._~ .LS h- PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0- 109 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of fingers: Analyst: August 15, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 71 at depth 2251.81 ft Tool speed = 54 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 96 % Tool deviation = 38 0 Finger 11 Penetration = 0.145 ins Line of Corrosion 0.15 ins = 57% Wall Penetration HIGH SIDE = UP Cross Sections page 2 Sperry-Sun Drilling Services LIS Scan Utility Wed Feb 04 10:45:09 1998 Reel Header Service name ............. LISTPE Date ..................... 98/02/04 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/02/04 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-M~4- 80078 S. BURKHARDT G. WHITLOCK 1D-109 500292284200 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 04-FEB-98 MWD RUN 2 AK-M~4-80078 S. BURKHARDT D. BREEDEN 14 liN 10E 59 596 .00 111.40 70.40 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 4850.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 3. ALL GAMMA RAY DATA (SGRC) PRESENTED HAS BEEN CORRECTED TO PROPER CALIBRATION VALUES. 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ROB KALISH OF SPERRY-SUN AND MIKE WERNER OF ARCO ALASKA, INC. ON 19 JANUARY, 1998. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4850'MD, 4240'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP $ .5000 START DEPTH 85 0 85 0 85 0 85 0 93 0 123 0 STOP DEPTH 4812.5 4812.5 4812.5 4812.5 4820.0 4850.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 123.0 4703.0 2 4703.0 4850.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 ROP MWD FT/H 4 1 68 12 4 RPX MWD OHFR4 4 1 68 16 5 RPS MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 85 4850 2467.5 9531 85 GR 7.0566 147.962 67.2377 9455 93 RPM 0.7964 2000 120.145 9456 85 ROP 12.6584 916.331 262.96 9455 123 RPX 0.5374 2000 93.601 9456 85 RPS 1.0294 2000 97.6859 9456 85 RPD 0.3636 2000 145.484 9456 85 FET 0.0678 14.3929 0.404378 9384 121 Last Reading 4850 4820 4812.5 4850 4812.5 4812.5 4812.5 4812.5 First Reading For Entire File .......... 85 Last Reading For Entire File ........... 4850 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/04 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD RPM RPS RPX GR FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 85 0 85 0 85 0 85 0 93 0 121 0 123 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 4673 4665 4702 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS STOP DEPTH 4665 5 4665 5 4665 5 4665 5 0 5 5 09-JAN-98 ISC 5.06 CIM 5.46 MEMORY 4703.0 123.0 4703.0 .9 41.8 TOOL NUMBER P0891CRG6 P0891CRG6 8.500 8.5 MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 SPUD MUD 175.00 325.0 8.5 350 6.2 6.OO0 4.711 8.000 3.000 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 1 AAPI 4 1 68 RPX MWD 1 OHMM 4 1 68 RPS MWD 1 OHM~ 4 1 68 RPM MWD 1 OHMM 4 1 68 RPD MWD 1 OHFIM 4 1 68 ROP MWD 1 OHMM 4 1 68 FET MWD 1 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32.8 Name Min Max Mean Nsam DEPT 85 4702.5 2393.75 9236 GR 7.0566 147.962 66.2604 9161 RPX 0.5374 2000 96.4897 9162 RPS 1.0294 2000 100.703 9162 RPM 0.7964 2000 123.884 9162 RPD 0.3636 2000 150.034 9162 ROP 12.6584 916.331 266.882 9160 FET 0.0678 3.2973 0.293772 9090 First Reading 85 93 85 85 85 85 123 121 Last Reading 4702.5 4673 4665.5 4665.5 4665.5 4665.5 4702.5 4665.5 First Reading For Entire File .......... 85 Last Reading For Entire File ........... 4702.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/04 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SI/MMARY VENDOR TOOL CODE START DEPTH FET RPM RPS RPX RPD GR R0P $ LOG HEADER DATA DATE LOGGED: SOFTWARE 4666 0 4666 0 4666 0 4666 0 4666 5 4674 0 4704 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMIDMANGLE: STOP DEPTH 4812.5 4812.5 4812.5 4812.5 4812.5 4820.0 4850.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 10-JAN-98 ISC 5.06 CIM 5.46 MEMORY 4850.0 4703.0 4850.0 18.4 18.4 TOOL NUMBER P0891CRG6 P0891CRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.500 8.5 SPUD MUD 175.00 270.0 8.5 35O 6.5 6.100 5.294 7.900 3.100 Name Service Order Units Size Nsam<Rep DEPT FT 4 1 68 GR MWD 2 AAPI 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 ROP MWD 2 OHMS4 4 1 68 FET MWD 2 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 28.6 Name Min Max Mean DEPT 4666 4850 4758 GR 61.4761 139.406 97.7232 RPX 1.9711 8.1389 3.58066 RPS 2.0243 7.5121 3.66237 RPM 2.0662 7.4035 3.62222 Nsam 369 293 294 294 294 First Reading 4666 4674 4666 4666 4666 Last Reading 4850 4820 4812.5 4812.5 4812.5 RPD 2.1472 7.4863 3.6987 ROP 50.8188 221.597 141.391 FET 0.2658 14.3929 3.82414 293 292 294 4666.5 4704.5 4666 4812.5 4850 4812.5 First Reading For Entire File .......... 4666 Last Reading For Entire File ........... 4850 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/04 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/02/04 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/02/04 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File