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Home My WebLink About196-151MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3F-16A KUPARUK RIV UNIT 3F-16A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2023 3F-16A 50-029-21502-01-00 196-151-0 W SPT 4988 1961510 1500 2444 2445 2443 2443 550 590 580 580 4YRTST P Brian Bixby 6/4/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3F-16A Inspection Date: Tubing OA Packer Depth 880 1810 1785 1780IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230607081011 BBL Pumped:0.6 BBL Returned:0.6 Wednesday, July 26, 2023 Page 1 of 1          MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg / / q DATE: Wednesday, June 12, 2019 P.I. Supervisor ([ (V(1q'q SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, INC. 3F -16A FROM: Guy Cook KUPARUK RIV UNIT 3F.16A Petroleum Inspector Src: Inspector Reviewed B P.I. Suprv�� NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F -16A API Well Number 50-029-21502-01-00 Inspector Name: Guy Cook Permit Number: 196-151-0 Inspection Date: 6/6/2019 Insp Num: mitGDC190608160521 Rel Insp Num: Wednesday, June 12, 2019 Page I of I Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min Well 3F -10A - Type Inj 9ti' TVD 4988 —FTubing 1944 1')1 1944 - 1947 -� PTD 196 15 10 - Type Test SPF Test psi 1300 IA 920 2600 - 2540 2530 BBL Pumped: 1-2 - BBL Rcturned: 1.i OA 260 - 3_0 _ 320. 320 - Interva� 4varST P/F – Notes: Job was completed with a Little Red Services pump truck and calibrated gauges. Wednesday, June 12, 2019 Page I of I Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday, April 14, 2019 10:08 AM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: RE: 3F -16A (PTD 196-151) Suspect OA Behavior Chris, DHD performed diagnostics on 3F -16A, which suggested the OA was communicating through the packoff to the IA. DHD adjusted components on the wellhead to energize the packoff to regain seal integrity. After a few days of observation, we have confirmed that the OA behavior is back to normal. CPAI intends to allow the well to continue normal operations. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: NSK Well Integrity Supv CPF3 and WNS Sent: Sunday, April 7, 2019 8:23 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: 3F -16A (PTD 196-151) Suspect OA Behavior Chris, Kuparuk injector 3F -16A (PTD 196-151) is under review for suspect OA behavior. CPAI intends to send DHD to investigate and will update you if we determine the behavior is due to an integrity issue. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday, April 7, 2019 8:23 AM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: 3F -16A (PTD 196-151) Suspect OA Behavior Chris, Kuparuk injector 3F -16A (PTD 196-151) is under review for suspect OA behavior. CPAI intends to send DHD to investigate and will update you if we determine the behavior is due to an integrity issue. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,July 01,2015 P.I.Supervisor Nen 71'15 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F-16A FROM: Johnnie Hill KUPARUK RIV UNIT 3F-16A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F-16A API Well Number 50-029-21502-01-00 Inspector Name: Johnnie Hill Permit Number: 196-151-0 Inspection Date: 6/27/2015 Insp Num: mitJWH150630143851 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F-16A TType Inj G TVD 4988 Tubing 3590 - 3590 -4_ 3590 - 3590 - PTDy 1961510 - Type Testi SPT Test psi 1500 IA 1220 2020 - 1995 ! 1995 - Intervall4YRTST P/F P OA 160 - 170 - 170 170 Notes: 5 bbls diesel - SCANNED !- fi , `; Wednesday,July 01,2015 Page 1 of 1 Kral( 3_ 1 6A, Pm 1701510 Regg, James B (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, June 22, 2015 2:12 PM � 6/t2115- To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA);Wallace, Chris D (DOA) Subject: Kuparuk 3F pad SW MIT-IA's Attachments: MIT KRU 3F-PAD WAIVED SI 06-21-15.xls Jim, Attached are recently performed SW MIT-IA's on 3F pad (waived by Chuck Scheve). All wells were shut in at the time of testing. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. SCOME° (i 2 1U1t Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 #11WELLS TEAM Conoco`PF,fwps 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to jim.regq(rDalaska goy.AOGCC Inspectors(@talaska qov phoebe brooks@alaska goy chns wallace(rD,alaska ao/v OPERATOR: ConocoPhillips Alaska,Inc 2e'4a b1111 t z( s. FIELD/UNIT/PAD: Kuparuk/KRU/3F Pad \ DATE: 06/21/15 OPERATOR REP: Hight/Riley AOGCC REP: (Chuck Scheve waived) Packer Depth Pretest Initial 15 Min. 30 Min 45 Min 60 Min Well 3F-03 Type In) N ND 5,701' Tubing, 975 1,025 1,050 1,050 Interval 4 P.T.D 1852270 Type test P Test psi 1500 Casing 750 1,710 1,680 1,670 P/F P Notes: OA 40 40 40 40 Well,3F-15 Type In) N ND 5,673'_ Tubing 1,950 1,950 1,950 1,950 Interval 4 P T D. 1852930 Type test P Test psi 1500 Casing 650 2,650 2,550 2,540 P/F P Notes: OA 280 320 320 320 Well 3F-16A Type Inj N - ND - 4,990' Tubing ' 1,700 1,700 1,700 " 1,700 Interval 4 i/ P.T.D 1961510- Type test P ' Test psi - 1500. Casing 210. - 2,420 ' 2,360 -2,340 P/F P Notes: OA 80 80 - 80 80 - Well 3F-20 Type In) N ND 5,781' Tubing 1,825 1,825 1,825 1,825 Interval 4 P T D 1990790 Type test P Test psi 1500 Casing 510 2,550 2,500 2,490 P/F P Notes: OA 200 220 220 220 Well 3F-21 Type Int N ND 5,848' Tubing, 1,450 1,450. 1,450 1,450 Interval 4 PTD 2002030 Type test P Test psi 1500 Casing 100 2,210 2,140 2,130 P/F P Notes: OA 10 20 20 20 Well Type Int ND Tubing. Interval P.T D Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industnal Wastewater R=Internal Radioactive Tracer Survey V=Required by Vanance N=Not Injecting A=Temperature Anomaly Survey 0=Other(descnbe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU OF-PAD WAIVED SI 06-21-15 Ms Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning pr.oject. They are available in the original file and viewable by direct inspection. J C~- l~ J File Number of Well History File PAGES TO DELETE Complete RESCAN Color items- Pages: GraYScale, halftones, pictures, graphs, charts - Pages: .. Poor Quality Original- Pages: Other - Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type 'OVERSIZED [] .Logs of various kinds Other COMMEN'r~: Scanned i~lred. D'erema Nalhan Low~l TO RE-SCAN Notes: Re-Scanned by: E~verry M~ Damtha Nathan Lowell Date: /s/ • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 07, 2011 TO: Jim Regg P.I. Supervisor l 4 f ll SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F -16A FROM: John Crisp KUPARUK RIV UNIT 3F -16A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3F - 16A API Well Number: 50- 029 - 21502 -01 -00 Inspector Name: John Crisp Insp Num: mitJCr110605215817 Permit Number: 196 -151 -0 Inspection Date: 6/5/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3F -16A TType Inj. W TVD 4988 IA 620 2100 / 2070 2060 • P.T.D 1961510 TypeTest t SPT Test psi 1500 ' OA ! 340 480 480 470 Interval 4YRTST P/F P Tubing l 2750 2750 2750 2750 Notes: 1 bbl pumped for test. No problems witnessed. . !.� JI h 1: `-1)11 Tuesday, June 07, 2011 Page 1 of 1 • WELL LOG • TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 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 the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road RoacKANNED APR 1 4 2008 Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 03 -Apr-08 1 Report / EDE 50 -029- 21502 -01 2) Caliper Report 04-Apr-08 31 -01 1 Report / EDe 50-029-2151400 P" l6 3v-? 't iC696 Signed . g /� Date . Print Name: Ct 1 - r,to_ d1,1i,b PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 E-MAIL : ;t szinc: cra e05. ] r;':.rJ7't'> , st] WEBSITE : ',V'AP; r,:;"ral D °i?o'!. r .Tn C \Documents and Settings \ Owner \Desktop \Transnut_Conoco,doe • • Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3F-16A Log Date: April 3, 2008 Field: Kuparuk Log No.: 7222 State: Alaska Run No.: 1 API No.: 50-029-21502-01 Pipet Desc.: 4.5" 12.6 Ib. L-80 Top Log Intvl1.: Surface Pipet Use: Tubing & Liner Bot. Log Intvl1.: 8,228 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the DB Nipple @ 7,846' (Drillers Depth). This log was run to assess the condition of the tubing and liner with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the 4.5" tubing and liner logged is in good condition. There are no significant wall penetrations, areas of significant Cross Sectional Wall loss or I.D. restrictions recorded throughout the interval of 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. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (>18%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No areas of significant cross-sectional wall loss (>7%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. ~(~N~ APR ~ ~. 2008 Field Engineer: Wm McCrossan Analyst: J. Thompson Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281} 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDS~amemorylag.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907} 659-2314 uTC 19~-r5 ~ ~ iC~~3/ • • Correlation of Recorded Damage to Borehole Profile ;~ Pipe 1 4.5 in (-5.0' - 8211.2') Well: 3F-16A Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: April 3, 2008 A pprox. Tool De viation ^ A pprox. Borehol e Profil e 1 25 ~ 6 790 50 1573 75 2360 100 3149 v ~ 125 3931 ~ .S Z s c Q- 150 4718 ~ 175 5503 200 6291 225 7138 250 7876 261 8211 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 261 • • PDS Report Overview ~, S. Body Region Analysis Well: 3F-16A Survey Date: April 3, 2008 Field: Kuparuk Tool Type: MFC 40 No 40970 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: J. Thom son Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4 5 ins 12 6 ppf L-80 3 958 ins 4 5 ins 6.0 ins 0.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~ metal loss body 200 150 100 50 0 0 to 1 to 10 ro 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ~oints anal sed total = 266 pene. 17 154 94 0 0 1 loss 80 186 0 0 0 0 Damage Configuration (body ) 80 60 40 20 0 -- isolated general line ring hole /pons pitting corrosion corrosion corrosion iblehole Number of ~oints dama ed total = 68 65 1 1 0 1 Damage Profile (% wall) ~ penetration body ~:~: metal loss body 0 50 100 0 48 100 150 200 244 Bottom of Survey = 248.1 Analysis Overview page 2 • • PDS REPOR T JOINT TABULATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 Well: 3F-16A Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: April 3, 2008 Joint No. Jt. Depth (Ft.) I'~,n. I11>tir~t (Ins.l Pen. Body (Ins.) Nc~n. %> ~tet,il I t>ss °b Min. LD• (Ins.) Cornrnents Damage Profile (%wall) 0 50 100 .1 -5 U 0.01 4 t 3.84 PUP 1 6 t~ 0.02 6 t 3.86 1.1 44 U 0.01 t i 3.90 PUP 2 49 U 0.03 13 4 3.82 Shallow ittin . 3 81 U 0.03 I I 1 3.84 4 112 t t 0.01 ~ 3.85 5 143 U 0.02 t; 3.83 6 175 tt 0.04 15 -I 3.84 Shallow ittin Lt. De sits. 7 210 a 0.03 I U -1 3.83 8 244 U 0.02 6 _' 3.83 9 275 U 0.03 12 t 3.83 Shallow ittin . 10 305 U 0.03 I1 3.83 11 336 U 0.04 14 ; 3.82 Shallow ittin Lt. De sits. 12 367 tt 0.03 l t 3.84 Shallow ittin Lt. De sits. 13 399 ! t 0.03 1 1 -1 3.83 ,, 14 430 ~ t 0.04 13 -1 3.84 Shallow corrosion. Lt. De osits. 15 462 tl 0.03 1_' 3.83 Shallow ittin Lt. De sits. 15.1 493 U 0 U U 3.88 DB Ni le 16 507 (1 0.03 1 1 1 3.84 Lt. De osits. 17 538 t t 0.03 1 1 t 3.84 18 569 tt 0.02 7 3 3.84 Lt De osits. 19 600 tt 0.03 1 3 3.84 Sh Ilow ittin Lt. De sits. 20 632 a 0.03 It1 3.85 Lt. De osits. 21 664 a 0.02 ~, 3.83 22 696 t l 0.03 l t t t 3.83 23 728 tt 0.04 I _i -1 3.81 Line shallow corrosion. Lt De osits. 24 758 U 0.03 11 4 3.83 Shallow ittin . 25 790 tt 0.03 13 i 3.85 Shallow ittin . 26 821 U 0.02 8 t 3.85 Lt. De osits. 2 7 853 U 0.03 ~> t 3.85 Lt. De osi ts. 28 885 a 0.04 I a 3.84 Shallow ittin . 29 916 a 0.03 9 t 3.85 Lt De osits. 30 947 U 0.03 13 -t 3.84 Shallow ittin LC De osits. 31 978 U 0.02 ~t ~ 3.85 2 1010 tt 0.02 8 t 3.83 Lt. De osits. 33 1042 t) 0.02 9 _' 3.83 Lt De osits. 34 1073 tl 0.03 1O s 3.84 35 1104 U 0.03 1 1 t 3.85 Shallow ittin Lt. De sits. 36 1135 U 0.03 1 t 3.82 Shallow ittin . 37 1166 t t 0.03 1 1 3.83 38 1198 tt 0.03 1O ~ 3.82 39 1228 tl 0.03 ~) _' 3.84 40 1258 O 0.02 ~ 1 3.82 Lt. De osits. 41 1289 tt 0.04 Ia 2 3.86 Shallow ittin . 42 1321 U 0.03 11 3 3.85 Shallow ittin . 43 1354 t ~ 0.02 (> _' 3.85 44 1385 t i 0.03 I ' 3.85 Shallow ittin . 45 1415 ! t 0.02 ~ i 3.84 46 1447 ! ~ 0.03 I ' ! 3.87 Shallow ittin . 47 1479 0.03 I I 3.84 Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: 3F-16A Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: April 3, 2008 Joint No. Jt Depth (Ft.) I'E~n. I ll~,~~t (lns.) Pen. Body (Ins.) Pen. °h ~Vlc~tal I cxs ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 48 1511 tJ 003 1t) I 3.86 49 1542 U 0.04 14 ~ 3.86 Shallow ittin . 50 1573 IJ 0.03 1? I 3.86 Shallow ittin . 51 1604 ~) 0.01 ~, 3.88 52 1636 ~) 0.02 tl i 3.88 53 1669 i J 0.02 _ 3.88 54 1702 ~ J 0.02 ti 3.86 55 1735 ~ J 0.03 ~) ~ 3.88 56 1766 ~) 0.03 I t) 1 3.86 57 1797 U 0.05 1 ~t ? 3.88 Shallow ittin Lt. De osits. 58 1828 t) 0.02 G I 3.86 59 1859 ~) 0.04 I > 1 3.86 Shallow ittin . 60 1890 a 0.03 IlJ 3.88 61 1921 t J 0.02 ~) I 3.88 62 1951 t) 0.02 b I 3.87 63 1983 ~ ~ 0.03 1 ~) _' 3.87 64 2015 ~ ~ 0.03 10 3.85 65 2046 a 0.03 1 ~) I 3.85 66 2077 (J 0.02 ti 1 3.86 67 2109 c1 0.02 ~) _' 3.86 68 2140 U 0.02 9 ~ 3.88 69 2172 Jt 0.03 I? Z 3.87 Shallow ittin . 70 2203 ~ J 0.02 ti 1 3.87 71 2234 tl 0.03 11 1 3.88 72 2265 U 0.02 ti 1 3.87 73 2296 U 0.03 1 Z ? 3.88 Shallow ittin . 74 2328 U 0.03 11 ~ 3.85 75 2360 U 0.03 ~~ 1 3.88 76 2392 U 0.03 11 1 3.88 77 2422 U 0.03 1.3 3.87 Shallow ittin . 78 2453 U 0.01 5 1 3.88 79 2484 U 0.03 11 1 3.88 80 2516 U 0.01 -1 I 3.88 81 2548 U 0.03 11 ~ 3.87 82 2580 U 0.02 7 I 3.85 83 2611 U 0.03 Ill 3.88 84 2642 c J 0.03 13 _' 3.88 Shallow ittin . 85 2674 tJ 0.02 8 1 3.86 86 2706 tJ 0.03 12 1 3.86 Shallow ittin . 87 2738 U 0.03 1(J ~ 3.86 88 2770 O 0.02 9 3 3.87 89 2802 U 0.03 I U I 3.87 90 2833 ~) 0.04 1.5 I 3.85 Shallow ittin . 91 2865 U 0.03 1l) 3.87 92 2894 U 0.03 II I 3.88 93 2922 i J 0.02 t9 1 3.86 94 2954 U 0.03 11 I 3.85 Shallow ittin . 95 2988 U 0.03 10 1 3.87 96 3020 ~? 0.02 8 ~ 3.87 97 3053 ! J 0.03 1 1 I 3.88 _ Penetration Body ~1Aetal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 Well: 3F-16A Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: April 3, 2008 Joint No. Jt. Depth (Ft.) I'~:~n. l )I~sE~i (Ins.j Pen. Body (Ins.) Pc•n. °/> V1c~~,rl I r~ss `i~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 98 3085 I) 0.03 12 1 3.87 Shallow ittin . 99 3118 ~) 0.01 4 1 3.88 100 3149 ~) 0.03 ~t ~ 3.88 101 3180 U 0.03 1 1 S 3.87 Shallow ittin . 102 3210 i) 0.03 IZ I 3.87 Shallow ittin . 103 3241 ~) 0.03 1 U I 3.87 104 3271 U 0.01 5 I 3.88 105 3303 i) 0.04 16 I 3.87 Shallow ittin . 106 3335 0 0.02 ~ 3.86 107 3366 U 0.02 ~) I 3.88 108 3398 U 0.02 ~~ I 3.86 109 3430 [~ 0.04 14 I 3.87 Shallow ittin . 110 3461 ~) 0.03 Il) I 3.87 111 3493 (t 0.02 £i i 3.88 112 3524 t) 0.02 £i 3.89 113 3555 ~) 0.03 Il) 1 3.88 1 14 3587 U 0.03 1O ~ 3.87 115 3618 U 0.03 13 ? 3.86 Shallow ittin . 116 3649 O 0.03 11 1 3.87 117 3681 ~) 0.03 12 _' 3.86 Shallow ittin . 118 3713 O 0.04 1.3 1 3.85 Shallow ittin . 119 3744 ~) 0.02 - I 3.88 120 3775 ~) 0.04 13 3.80 Shallow ittin Lt. De sits. 121 3806 U 0.02 8 3.84 122 3838 U 0.04 1 S I 3.87 Shallow ittin . 123 3868 U 0.03 10 2 3.87 124 3900 U 0.03 10 1 3.88 125 3931 U 0.03 13 3.87 Shallow ittin . 126 3964 t) 0.04 13 I 3.88 Shallow ittin . 127 3996 ~) 0.02 ~ I 3.87 128 4027 (~ 0.03 10 ~ 3.87 129 4059 [~ 0.02 7 1 3.87 130 4090 ~) 0.02 9 1 3.88 131 4122 U 0.04 15 3 3.88 Shallow ittin . 132 4153 ~) 0.02 I 3.88 133 4184 U 0.03 11 1 3.88 134 4215 U 0.02 £) ~' 3.86 135 4246 ~) 0.03 ~> 3.85 136 4278 U 0.03 lu I 3.88 137 4309 a 0.02 (~ 1 3.89 138 4340 U 0.01 4 _' 3.86 139 4371 U 0.03 1 U 3.87 140 4403 U 0.02 ~7 3.86 141 4436 U 0.03 13 ~' 3.86 Shallow ittin . 142 4467 U 0.04 1 i 1 3.87 Shallow ittin . 143 4498 t) 0.03 I 1 3.87 144 4531 U 0.02 7 3.88 145 4562 U 0.04 I (, ! 3.88 Shallow ittin . 146 4592 0.03 3.88 147 4624 0.03 3.87 _ Penetration Body Metal Loss Body Page 3 • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: 3F-16A Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: April 3, 2008 Joint No. Jt. Depth (Ft) Pcn. UI»c°i (In~.j Pen. Body (Ins.) Pcn. %> Mc~l.il I ~~s, ~~ Min. LD. (Ins.) Comments Damage Profile wall ( 0 50 100 148 4655 t? 0.03 1(? 3.86 149 4686 a 0.03 1l) 1 3.88 150 4718 I? 0.03 ~) 1 3.87 151 4749 t? 0.01 ~ I 3.88 152 4780 t? 0.03 ~) 3.87 153 4812 ~? 0.02 ~) _' 3.87 154 4843 I? 0.03 1 _' ~ 3.88 Shallow ittin . 155 4875 U 0.02 ti 1 3.90 156 4906 a 0.04 13 I 3.88 Shallow ittin . 157 4938 l? 0.02 ~) ~ 3.89 158 4969 I? 0.03 1 _> I 3.88 Shallow ittin . 159 5001 (? 0.04 I _~ ~ 3.86 Shallow ittin . 160 5032 U 0.03 13 _ 3.88 Shallow ittin . 161 5064 U 0.02 ~) ' 3.87 162 5097 O 0.03 i Z 1 3.85 Shallow ittin . 163 5127 U 0.02 t~ _' 3.89 164 5157 n 0.0 ~? I 3.88 165 5189 I? 0.03 ~) I 3.87 166 5220 n 0.03 1 U ~ 3.87 167 5252 U 0.02 ~ -' 3.87 168 5283 U 0.03 13 _' 3.88 Shallow ittin . 169 5315 U 0.01 4 _' 3.88 170 5346 l) 0.03 11 1 3.87 171 5377 U 0.03 13 ~' 3.88 Shallow ittin . 172 5409 0 0.03 1 ~ _' 3.88 173 5440 t) 0.02 t3 1 3.87 174 5472 a 0.03 1(1 ? 3.88 175 5503 t? 0.03 1 'I 3.88 176 5535 t) 0.03 Ill 3.88 177 5566 l? 0.03 1l1 I 3.87 178 5597 I? 0.03 11 I 3.88 179 5628 ~? 0.04 13 _' 3.87 Shallow ittin . 180 5660 U 0.02 6 3.85 181 5691 ~ 1 0.02 8 ~' 3.87 182 5722 U 0.03 13 ? 3.86 Shallow ittin . 183 5754 ~! 0.02 7 ' 3.87 184 5786 U 0.03 1 Z ~' 3.87 Shallow ittin . 185 5817 I? 0.04 13 ~' 3.87 Shallow ittin . 186 5850 (~ 0.03 11 _' 3.87 187 5883 ~ J 0.02 ~) ~' 3.88 188 5914 (? 0.02 7 Z 3.89 189 5945 t) 0.04 15 3.87 Shallow ittin . 190 5976 ~? 0.03 10 1 3.89 191 6008 ~? 0.03 11 3.87 192 6039 U 0.02 (> I 3.87 193 6071 ~? 0.03 1U -' 3.89 194 6102 r? 0.03 13 _' 3.89 Shallow ittin . 195 6134 l? 0.03 ~) _' 3.87 196 6165 (? 0.01 5 2 3.87 197 6196 U 0.03 1 "; ? 3.88 Shallow ittin . _. Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: 3F-16A Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Cornpany: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: April 3, 2008 Joint No. Jt. Depth (Ft) I'c~n. I )Ixc~t ilm.1 Pen. Body (Ins.) Pc~n. `%~ ti1cl~rl I cis. ~~ Min. LD. (Ins.) Comrnents Damage Profile (% wall) 0 50 100 198 6228 t) 0.02 +i 3.85 199 6260 U 0.04 L5 I 3.88 Shallow ittin . 200 6291 U 0.04 14 I 3.87 Shallow ittin . 201 6321 U 0.03 1 U 3.87 202 6352 U 0.02 t) I 3.88 203 6384 ~) 0.03 10 3.87 204 6416 t) 0.03 1U ? 3.86 205 6448 t) 0.03 11 I 3.88 Shallow ittin . 206 6479 t) 0.02 ti I 3.88 207 651 1 t) 0.02 3.89 208 6542 t) 0.04 1.1 1 3.86 Shallow ittin . 209 6574 i) 0.03 t I 3.88 210 6605 l) 0.02 £3 3.87 211 6636 U 0.02 ~) 3.88 212 6667 U 0.03 II 3.88 213 6699 U 0.03 1 U ? 3.88 214 6730 U 0.02 ~) 2 3.88 214.1 6760 t) 0 U U 3.81 Slidin Sleeve 215 6775 t) 0.03 I U _' 3.88 215.1 6806 U 0 U U 3.88 Packer 215.2 6817 U 0.00 1 .' 3.83 PUP 215.3 6826 U 0 U U 3.81 X Ni le 215.4 6830 U 0.02 9 b 3.80 PUP 215.5 6838 U 0 U U N A Seal Ass 216 6848 U 0.03 1 ~~ 2 3.84 Shall w ittin st t. Liner 217 6880 U 0.01 4 Z 3.85 218 6912 U 0.00 I ; 3.83 219 6945 a 0.00 I 3 3.83 220 6974 U 0.01 _' ~' 3.85 221 7007 U 0.00 I ~' 3.85 222 7039 U 0.00 1 3 3.85 Lt. De osits. 223 7071 U 0.00 1 Z 3.85 224 7105 t) 0.02 8 ? 3.87 225 7138 i) 0.03 I i ~ 3.83 Shallow ittin . 226 7168 a 0.00 I 3.85 Lt. De osits. 227 7199 a 0.02 `) 3.83 228 7231 t) 0.03 II I 3.83 229 7261 U 0.01 4 3.84 230 7289 U 0.02 7 4 3.83 231 7319 U 0.02 ~) > 3.83 Lt. De osits. 232 7349 U 0.00 1 3.83 Lt. De osits. 233 7376 U 0.02 t3 _' 3.85 Lt. De osits. 234 7405 a 0.01 4 ? 3.84 Lt. De osits. 235 7434 t) 0.01 3.84 236 7465 t) 0.03 ') 3.85 237 7495 a 0.00 I 3.85 238 7525 U 0.00 I ~' 3.85 Lt De osits. 239 7555 t) 0.02 7 4 3.85 Lt. De osits. 240 7585 t) 0.01 4 3.84 241 7614 ! ~ 0.01 _' 3.85 _ Penetration Body Metal Loss Body Page 5 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 Well: 3F-16A Body Wall: 0.271 in field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: April 3, 2008 Joint No. Jt. Depth (Ft.) f'e'n. llhset (lns.) Pen. Body (Ins.) I'~~n. %, Mc~t.rl loss `%~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 242 7641 I) 0.01 4 ~ 3.81 243 7669 U 0.01 2 i 3.83 244 7699 t! 0.00 I ~' 3.85 245 7730 t! 0.00 I ~ 3.85 246 7758 ~ ! 0.02 3.84 247 7788 ~! 0.03 I I 3.84 Lt. De osits. 248 7817 ! ! 0.00 I s 3.86 248.1 7846 t! 0 (! tl 3.75 X Ni le 249 7849 t! 0.00 I -t 3.82 Lt. De osits. 250 7876 a 0.02 t3 3 3.84 Lt. De osits. 251 7905 ~! 0.01 ? U 3.83 Lt. De osits. 252 7937 t! 0.02 ~ ; 3.85 253 7968 n 0.02 t, 3.85 Lt. De osits. 254 7996 ~! 0.01 3.84 255 8026 a 0.00 I 3 3.84 256 8056 t! 0.02 _' 3.85 257 8085 U 0.01 4 _' 3.84 258 8114 U 0.02 7 ~ 3.85 259 8143 a 0.00 1 3.84 259.1 817 t! 0.00 1 3.87 PUP 260 8183 i! 0.02 7 ~ 3.84 Lt. De osits. 261 8211 t) 0.23 £ib 7 3.85 Perforation Interval _ Penetration Body Metal Loss Body Page 6 • • ColnocoPhillips Alaska, Inc. KRU 3F-16A ~' 3F-16A API: 500292150201 Well T INJ An le TS: 40 d 7990 SSSV Type: NIPPLE Orig Com letion: 9!23/1996 Angle @ TD: 42 deg @ 8580 Annular Fluid: Last W/O: Rev Reason: TAG FILL wP 510 511 R f L R f L D U d L 8/7/2006 ( - , oD:a.SOO) e erence Last Ta : 8299 o ate: e TD: 8580 fiKB ast ate: TUBING (06838 Last Ta Date: 7/28/2006 Max Hole An le: 54 de 3495 , oD:a.SOO, Casin Strin -CONDUCTOR ID:3.833) Descri lion Size To Bottom ND Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 Casin Strin -SURFACE Descri lion Size To Bottom ND Wt Grade Thread SUR. CASING 9.625 0 3884 3045 36.00 J-55 asin Strin -PRODUCTION Nordic SIDETRACK 7015' Descri lion Size To Bottom ND Wt Grade Thread SLEEVE (67x7-s7sa PROD. CASING 7.000 0 7015 5130 26.00 J-55 , oD:a.SOO) I ( Cesin Strin -LINER PROD. Descri lion Size To Bottom ND Wt Grade Thread CASING a7o1s LINER 4.500 6831 8580 8580 12.60 L-80 ( , oD:7.oo0, Tubin Strin -TUBING wc:zfi.oa) Size To Bottom ND Wt Grede Thread 4.500 0 6838 5005 12.75 L-80 ABM-EUE Perforations Summa Interval ND Zone Stratus Ft SPF Date T e Comment PKR 8230 - 8246 6039 - 6051 A-3 16 4 11/12/1996 IPERF HSD Perf Gun, 180 deg. phasing; Oriented (+/-) 90 (ea14-sa15, de . F/lowsid OD:6.151) 8266 - 8300 6066 - 6092 A-2 34 4 11/12/1996 IPERF HSD Perf Gun, 180 deg. phasing; Oriented (+/-) 90 de . F/lowsid Other lu s ui .etc. -JE WELRY De th ND T Descri lion ID 510 510 NIP Camco'DB' Ni le 3.875 6767 4955 SLEEVE Baker CMU Slidin Sleeve; CLOSED 9/23/96 3.812 NIP 6814 4988 PKR Baker'SABL-3' 3.875 (saz&~~ 6828 4998 NIP Otis'X' Ni le 3.813 , oD 4 5~) 6829 4999 SEAL Baker Locator SEAL ASSEMBLY 3.937 sEAL 6841 5007 HANGER BKER CMC MECHANICAL LINER HANGER 4.313 (sazg683°' oD:a SOO) 7846 5745 NIP Camco'DB' 3.750 . HANGER (6841-6842, OD:5.000) LINER (6831-8580, OD:4.500, Wt 12.60) NIP (7846-7847, OD:3.833) Pert (8230.8246) Pert (8266-8300) lVIEMORANDUlVI . 10: J Ìm Regg 1'.1. Supcnisor rei FROM: John Crisp Petroleum Inspector Well Name: KUPARUK RIV UNIT 3F-16A Insp Num: mitJCr070612123026 ReI Insp Num: Packer ____..-_~....____..H~___. .__..._____ -----------.------- State of Alaska . \Iaska Oil and Gas Conservation Commission IHTE: í I,mc ¡ 2 ~ / Sl BJECT: \k::bniC:l1 rllle;n!\ \ G\ t,-" \ ç I \L,'\SK_-~ KCPARCK RIV UNIT 3F-16A Src: Inspector Reviewed By: P.I. Suprv ,í;q!.2- - Comm NON-CONFIDENTIAL API Well Number: 50-029-21502·01·00 Permit Number: 196-151-0 Inspector Name: John Crisp Inspection Date: 6í8í2007 Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~--_._. -- _.~-- -- ~"---"'~----'---"-"-- .__..~_.._-,~,.._._._--;------_..-.- --.-"-- 4988 IA --,----',,---- ,- - 1500 OA 2460 2450 --.._~._-_.~-_. .- _.._-~----_...._..---.------_.._-- 240 240 ___n___ ,__,'___ , ' _'_______n__ '___ _____..._____________ ___ ________ IntervaL_4YR~ _.RI£n___~___ /__ .-!ubi~~ ,_~O~__ P~0--"_1700__ __~oo_,______,_ Notes: 2,7 bbl's pumped for test Shut in long term since 2íll/06 for res Management Tuesday, June [2,2007 scANNED Jl\N 2 1 2007 Page I of 1 . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALA5KA 99510-0360 September 2, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED S E P 0 (3 2005 Dear Mr. Maunder: . \ 6 i \q~' Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, 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 August 14,2006 and is reported as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I 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 corrosion inhibitor and sealant were pumped in a similar manner August 21-29,2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907 -659-7043f',.i(you have any questions. /' -) ~/ Sincerely, // l? / A?P;'~·"Y;-,'.. /~ , /. µ.,~ ./V'v oÞ" /' lY / / M.J.loveland ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Initial Top Cement Final Top Sealant Well Name PTD # of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date 3.f70.1~. . ..'., '18~";~2º' . ,,'. ,?,,'/t, ' " NA ':', ' , I ' NA··'·',··· .: ·7.~f .".' '. 812:~~o:(lß. / . 3F-02 1 85-226 24' 7.0 8/14/2006 7.5 8/21/2006 ~~~~3 .,' " ts5f4:21· '. ' ~..', . '1i3'!ít" '..., ,2:.3 ' . .<. [,8/1;~r2Q~E? .'. . ·,::âf~t/~..Øl6~; .' ,. 3F-04 1 85-228 80' 22.7 1 0' 8" 8/14/2006 38.2 8/21/2006 .--' ,-"..<21'6'·,. ¡ 5:1, , .. ,:" .. " ·8/14/2ò'f16 . .' 7:5 .. " ., ·gÆ~1~2ØØ6")·' .. , 3F-06 1 85-244 Did not modify 3r;~,Q7:' ,;.. .,·,·;·.:1~~ì45'· ., ,'"'''''o' 6~6 8/14/2008 .. '" 7~5 '." B/21/2QO~; " , 3F-08 1 85-246 1 1 '4" 2.6 8/1 4/2006 6.6 8/21/2006 '3F:Ç1~ '. ' tå'S~t} Did not modify 3F-1 0 1 85-271 SF NA NA 6.6 8/21/2006 ·3F':11'. ;-Y'.- la5:,2:~2' ','··',;;$F f '. NÄ , NI\.. . . . 1.1 J$f2~14~:QJ)· . "i- " 3F-1 2 1 85-273 7'4" 1 .8 ~2006 6.2 8/23/2006 , ·':~19~10~~ .\ '. , ~ !' . NA' 1',.. ':G.t.. ' . .: 'ßll91~«rŒß' . ~4 185-292 Did not ~ t- V: 2~4: . I , :,a'114fZQÓ6F: .. .. ;8l2'3!2COfr· .' " 1.,.1.,-, :.:; " , 3F-1 6 ~51 6" NA NA 2.7 8/23/2006 3E£11 '. , , . ',. 3.1 . '. 8/14/20af,}, " r' 8 '812~lgOØ6;: ->:r -IT 3F-1 8 1 96-1 12 4' NA NA 28 8/23/2006 .3F'::~'9: ' .. ..,'~ 'Z~~~1OC16":~, :; ·'..8'~ " .. ,.. . . WA: ' 8" . ".NA . :, . 2',' , ·"¡à¡:2ß.12~a6:., 3F-20 199-079 36" NA NA 1 7.7 8/23/2006 3F~2'.1 . ,.' " '20Ôi2:03 [ 45" . NA , NA 31 .8/21:12006 . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD I UNIT/PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/3F O6/O5/O3 Arend/Brake- APC Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. ,, P-T.D. I1852450 I.TypeTestl P I Test psiI 1500 1CasingI 11001 23001 22751 22751 P/F Notes: P.T.D. I1852460 TypeTest Test psiI 1500 I Casing I 8001. 22751 22501 22501 P/F Notes: P.T.D, li852720 Type Test TestpsiI 1500 I Casingl 11001 23001 22751 22751 P/F Notes: WelII3F-12 I Typelnjl Sp I T:V.D. 15628 I T,b,,gl ~001 ~001 ~001 13ool,nterva, I ; P.T.D.]1852730 Type Test Test psiI 1500 I CasingI 11501 22751 22501 225.01 P/F . Notes: Well l3F-15 I TypelnjI .Gp I T.V.D. I 5673 I Tubing I 35001 35001 35001 35001 Interval 'P.T.D,:I1852930 I myp.eTest Test psiI 1500 I CasingI 14001 23001 22801 22801 P/F Notes: P.T,D.:I:196~5~0 Type Test Test psiI 1500 I Casingl 01 23001 23001 230'01 P/F 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 Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 2003-0605_M IT_K RU_3 F-07_-08_-11_-12_-15_-16A.xls 6/25/2003 AUG 0 4 /KRU MIT's Subject: KRU MIT's Date: Fri, 6 Jun 2003 15:28:32 -0800 From: "NSK Problem Well Supv" <nl 617~conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, tom_maunder~admin.state.ak.us, jim_regg@admin.state.ak.us CC: "nl 617" <nl 617~conocophillips.com> Attached are the 4 year cycle MIT Results for 3B and 3F. Please call with any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: MIT KRU 3F 06-05-03.xls) (See attached file: MIT KRU 3B 06-05-03.xls) 'i Name: MIT KRU 3F 06-05-03.xls ] ~_~MIT KRU 3F 06-05,03.xls:] Type: EXCEL File (application/msexcel)i :]Encoding: base64 !1 ] Name: MIT KRU 3B 06-05-03.xls ~] [~MIT KRU 3B 06-05-03.xls] Type: EXCEL File (application/msexcel) ] ]Encoding: base64 ~! I of I 6/25/2003 4:37 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak. us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD / UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/3F 06/05/03 Arend/Brake - APC Chuck Scheve Well 13F-07 P.T.D. I1852450 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. ITypelnjI ~ IT'V'D' I5850 ITubing I 25001 25001 25001 25001 Interval Type Test Test psil 1500 I Casing I 11001 23001 22751 22751 P/F Well 13F-08 P.T.D. I1852460 Notes: TypeTest Test psiI 15oo I Casing I 8001 22751 22501 22501 P/F Well 13F-11 P.T.D. 11852720 Notes: Type Test TestpsiI 1500 I Casing I 11001 23001 22751 22751 P/F P.T.D. I1852730 Type Test TestpsiI 1500 I Casing I 11501 2275] 22501 22501 P/F Notes: P.T.D. I1852930 Type Test TestpsiI 1500 I Casing I 14001 23001 22801 22801 P/F Notes: We, 13F-~SA I Typelnj I S IT'v'D' I 49881Tubingl 25501 25501 25501 25501 Interval P.T.D. I1961510 Type TestI P I Testpsil 1500 I CasingI 01 23001 23001 23001 P/F 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 Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 3F 06-05-031 .xls 7/10/2003 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Randy Ruedrich Commissioner Jim Regg ~2~1~~ ~,¢b,i~.5 P.I. Supervisor 'lI ~ Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL DATE: June 5, 2003 SUBJECT: Mechanical Integrity Test Conoco Phillips 3F Pad KRU Packer Depth Pretest Initial 15 Min. 30 Min. We,,I 3F-07 I Type,nj.Ie IT.M.D. 15850 I Tubingl~00 I~00 I~00 I~00 I'nter~a'l 4 P.T.D.I 185-245 ITypetestl P ITestpsil 1463 I CasingI 1100I 2300I 2275I 2275I P/F I P Notes: We,,I3F-08 I Typelnj. I G I T.v.D. I Tubing 13650 I,nterva, I4 P.T.D.I 185-246 ITypetestl P ITestpsil 1432 I Casingl 800 I 22751 22501 22501 P/F I P Notes: WellI 3F-11 IType,nj.I S I T.V.D. I¢~ ITubingl 185o I~o I ~,~o I~o I,nterva, I 4 P.T.D.I 185-272 ITypetestl P ITestpsil 1400 I Casingl 1100I 2300I 2275I 2275I P/F I P Notes: Well Notes: P.T.D. Notes: P.T.D. Notes: 185-273ITypetestl P ITestpsil 1407 ICasingI 115O1 2275I 2250I 2250I P/F I P 3F-15 I Typelnj.I G I ¥.~.D. 15673 I Tubing 13500 13500 13500 I~00 I,nte,,,a,I 4 185-293ITypetestl P ITestpsil 1418 I Casingl 1400I 2300I 2280I 2280I P/F I P 3F-16A I Type,nj.I s I T.V.D. 14988 I Tu~,,.~'l ~5~0 }2~0 12~0 12~0 I,nte,'va, I 4 196-151ITypetestl P I Testpsil 1247 I CasingI 0 I 23001 23001 23001 P/F I P 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 Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Conoco Phillips 3F Pad in the Kuparuk field and witnessed the routine 4 year MIT's on the above listed 6 wells. The pretest pressures were observed and found to be stable. The standard annulus pressure tests were then performed with all wells demonstrating good mechanical integrity. M.I.T.'s performed' _6 Number of Failures: 0 Attachments: Total Time during tests: 4 hours CC: MIT report form 5/12/00 L.G ~~E~' JUL'8 ? 2111:13 2003-0605 MIT KRU 3F-16A cs.xls 6/24/2OO3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Pl~illips Alaska, Inc. Development_ RKB 88 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratlgraphlc__ Anchorage, AK 99510-0360 servi~__x Kuparuk Unit 4, Location of well at surface 8. Well number 5197' FNL, 225' FEL, Sec. 19, T12N, RgE, UM (asp's 508273, 59859O5) 3F-16A At top of productive interval 9. Permit number / approval number 1445' FNL, 1649' FWL, Sec. 19, T12N, R9E, UM 196-151 / At effective depth 10. APl number 50-029-21502-01 At total depth 11. Field I Pool 1059' FNL, 3108' FEL, Sec. 19, T12N, R9E, UM (asp's 505370, 5990040) Kuparuk Oil Pool 12. Present well condition summary 'Total depth: measured 8580 feet Plugs (measured) true vertical 6300 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16' 328 sx AS il 115' 115' SUR. CASING 3796' 9-5/8' 1125 sx PF E & 425 sx Class G 3884' 3045' PROD. CASING 6927' 7' 250 sx Class G& 18o sx PFC 7015' 5130' LINER 1749' 4-1/2' 25o sx C~ass G 8580' 6300' Perforation depth: measured'~)'~;-~.:~:x:.?.:".i .i :-':-:-i-~: :; ?i ;:::i':.-.'i:;';' !-:-! i~!:?:-;.:-;'.:i true verticel:~l;~t.;60$~':i': .{~-;6~. :' ::..~.":';::":' ::[ ;:-: :': .-:.:.~ :::)?..:::- ::::::::' i.-.i..::',:..;i . ..' :.'::.::. :'.':":. -;-:::-;':'-:--:":- ' '.---' ....... ;i-;'-::~--.:.-:::-_-i'-.-'- : '-: -' :-;-i ' - i- -. ;- -: '- !" '.~':::::.'::.:~:i.::::'::''::.':'!..'.. ;.:.::::.-': _::'L:':.' :'..:'.::-::" ~. :.':;. ':'.'.'".:'~.'" Tubing (size, grade, and measured depth) :~;~! ..1~i7~, ;L~S.t~-:'- ~ ~'-~,; :::-::: s:.'::'.i-i'i: ;:;ii' ;-'!' ;:: !'}i:!!;:;''I-!:;'::;:'':!!;::::' !' :-.:: i;'ii!:!s~ ~'' '~'"~':r~*'S Packers & SSSV (type & measured depth) '~Al~}~{:~;i~;6~*;~l:~?-i.::i:i i':.::.i!!;i:' .:.? :-::::;?-.::!.:.; .':.!:::si:.. ':!.:::? :-J" '. ::. ::.:?ii~i-'.'-:i~iii'i!i ?;:::i!:ii~.~i,:;!::::::!:::i-:-:'i:'i: ?:i-'-.~'::'::-i'X' UA~-~: ~:S~o"I~D::: '~:'::: ::.:: :;: .~ :'~:-': :..;: .;'~:i:.::;::..!: .::-:. ';:i-~-i:-:-: .--'i :"-:: - ,~.:;:::~ii':': i'i?:-:-'; '"~:! ~: "-'"-;i :: i"::-;:":!i'~ ::.~?:::!';-:. ~-':::' 13. Stimulation or cement squeeze summary Intervals treated (measured) :ii~:~ 'i-:i:;:~:!:'ii::::."i?':":!i.:? ~.~;'i :' ::ii-i :! !{!: ':' )i--.:!':Z" ':i! :~"ii "::-';.iil "i::' '. Treatment description including volumes used and final pressure i'..';:i-i;'i?i:i'i '-.-:*.' i.:.~i;!;.~!i.: ;-:i!! !:i. i:!i-!ii-! !!;::?.::.:-i}!"-; 14. Representative Daily Avera,qe Production or Injection Data OiI-Bbl · . Gas-Md . Water*Bbl Casing Pressure Tubing Pressure Prior to well operation iiii?ii:i": '"; ':~-i.-::'!? ':"!:: '.i::-: ~:::i!i'' '~! i"i!' ~:i.:i: '! i{i:.!; :}. ::i.-:}iii?'.. ;'i' 1~09. --.:-'i:: :::i:-i;!i:' ii!iii{'!:i~ i~01'il i--'.::: i}: Subsequent to operation ": ::::::::::}::::::::: !-:.'"':ii' i-: :': i:.; i.::;.!.: .: i.:' '~t;:i.i.";'.i':.-!'i~i ;:;.:i-: Z.??:i. :' ~'?.'}'*.---?:.Z!:.'i?:?;*ii; iiii-::?l~'~ ;ii}~.::ii'i.-:-.}i} 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X :i ' '0~"?i.!.;;!:~- i G'.a~i.~ ; :.~ ~ :':; ;;:' ;;:i~~'W".~.~:l~lJ~_F-"'r:i.. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Que~tfona? CallJeffSpencer655-72EO Signed '~, ~.~'~ Title Production Engineering Supervisor Date/~rd,~ -~ Jeff A. Spencer Prepared by Robert Christensen 6~9- Form 10-404 Rev 06/15/88' SUBMIT IN DUPLICATE 3F-16A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS 96-151 CBT IL 6700-8469 96-151 CBT -~ 6685-8469 96-151 MWD SRVY ~7020-8580 96-151 NGP-MD ~7020-8580 96-151 NGP-TVD ~ 5134-6300 Page: 1 Date: 11/05/98 RUN RECVD FINAL 11/22/96 FINAL 11/22/96 02/12/97 FINAL 02/19/97 FINAL 02/19/97 1 03/20/97 96-151 MWD SRIrY a~R.~SPERRY 7020-8580 04/01/97 10-407 C~COMPLETION DATE DAILY WE~,~ OPS R ~/'?/'i~q TO j Are dry ditch samples required? yes ~_~d received? Was the well cored? yes ~~alysis & description received? Are well tests required? ~yes ~eceived? Well is in compliance Initial COMMENTS ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 27, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3F-16A (Permit No. 96-151) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent operations to sidetrack KRU 3F-16. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad ALASh,,~ OIL AND GAS CONSERVATION C,.,MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND 1. Status of Well Classification of Set~ Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Inj~.~.n_.-"q 2. Name of Operator 7. Permit Nur~lYcUr.~ Gas Con.~ ARCO Alaska Inc. 96-151 3. Ad~l~:~ss 8. APl Number "'~.Urag P. O. Box 100360, Anchorage, AK 99510,_- ~ ~--,~-~-~,,--,-,.,.,.~- -~_ 50-029-21502-01 "~,-~, ~ ~ 4. Locati~ ofwell at surface ~' ~r~,~j/~?;:'.-~;:.~--~ ~' ~',.~:~- 9. Unit or Lease Name ~ ...... ""~:'"'~;~ ~' f~ :~_~; ~ Kuparuk River Unit 82' FSL, 227' FEL, Sec. 19, T12N, RDE, UM ~ ~' ~,,._.,~/;. ,~7;.~ ~ .... At top of productive interval ~/~'y(- ~Z~ ~.~r,~.._~, ~ 10. Well Number 1062' ........... FNL, 1710' FWL, Sec. 19, T12N, R9F, UM .......... · Kuparuk River 5. ~levation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. ~ordic Rig RKB 32', Pad Flor. 56'I ADL 25632 ^LK 2565 i12. Date SpuddedD/13/96 !i13' Date T'D' Reached ! 14' Date ¢°mP" Susp" °r Aband115' water depth' if °fish°re ' 16' N°' °f C°mpleti°nsD/19/96 11/12/96 N/A MSLI One 17. Total Depth (MD+TVD)! 18. Plug Back Depth (MD+TVD)J19. Directional Surveyi20. Depth where SSSV set~21. Thickness of Permafrosl 8580 6301 FT~ 8484' 6228 FT~ []Yes I~No ! N/A MD| 1465' (Approx.) 22. Type Electric or Other Logs Run CBT, CBL, GR, Resistivity 23. CASING, LINER AND CEMENTING RECORD CASING I SETTING DEPTH HoLE SIZEI VVT. PER FT. . G?~....DE ,-- ~-~ ...... j] B(~-~'~(~-I~---~ ..... _S_IzE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf. 115' 24" 328 sx AS II 9-5/8" 36:0# J-55 Surf. 3884' 12.25" 1125 sx PF E & 425 sx Class G 7" 26.0# J-55 Surf. 7015' 8.5" 250 sx Class G & 180 sx PFC 4-1/2" 12.6# L-80 ---~832'~ ..... 8-580' - 6.125"-~50 sx CJ~a-~ G 24. Perforations open to Production (MD+TVD Of Top and BottOm 125. TUBING RECORD and interval, size and number) "'SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 6838' 6814' MD TVD MD TVD 8230'-8246' 6039'-6051' 8266'-8300' 6066'-6092' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRoDuCTION TEST IDate First ProductiOn iMethod of Operation (Flowing, gas lift, etc.) i Water Injection Date of Test iHours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO i ............................................................................................ 1 Flow TubingiCasing Pressure ~ALCULATED · OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. ! 24-HouR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate ............................................................... ~r -- ........................................ 30. 29. Geologic Marl, Formation Tests "' I~asured True Vertical ! Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. , , Top Kuparuk C 7990' 5856' Bottom Kuparuk C 8096' 5937' Top Kuparuk A 8206' 6022' Bottom Kuparuk A 8378' 6152' Freeze protected well. APR 1199-/ I ~.Jas~a 0il & Bas Cons. C0mmiss~,- I Anchorage 3i ~ Eist Of Attachments ' Summary of Daily Drilling Reports, Surveys !32. I hereby certify that the foregoing is true and correct to the best of my knowledge Prepared By Name/Number: INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 11/6/96 ARCO ALASKA INC. Page WELL SUMMARY REPORT wi: I API NUlV~ER 50-029-21502-0,~-- "OOorago' WELL:3F-16A RIG:NORDIC WELL ID: AK8549 TYPE: AFC:--AK8549 AFC EST/UL:$ 1000M/ OM STATE:ALASKA AREA/~TY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:09/09/96 START COMP:09/10/96 FINAL: 09/10/96 (C 1) TD: 8484' PB: 0' SUPV:DLW DAILY:$ 09/11/96 (C 2) TD: 7916' PB: 8193' SUPV:DLW DAILY:$ 09/12/96 (C 3) TD: 7215 ' PB: 8193' SUPV: D LW DAILY: $ 09/13/96 (C 4) TD: 7015 ' PB: 7048' SUPV: DLW DAILY: $ 09/14/96 (C 5) TD: 7015' PB: 7048' SUPV:DLW DAILY:$ CIRCULATE & CONDITION MUD MW:10.3 FW Accept rig 9/9/96 @ 1800 hrs. Pump water down tubing. Pump mud. Well dead. 36,909 CUM:$ 73,818 ETD:$ 0 EFC:$ 1,073,818 PULL & LD 3.5" TBG MW:10.3 FW Continue to circulate and condition mud. Set BPV, N/D tree. N/U BOP's. Test BOP's 250-3500 psi. Pull BPV, Pull tbg. Monitor well, well dead. Pull 3.5" tubing and jewelry. 36,504 CUM:$ 146,826 ETD:$ 0 EFC:$ 1,146,826 POOH FOR SECTION MILL MW: 9.5 UNKN Continue to pull 3.5" tbg. Test blind rams, kelly valves and set wear ring. RIH w/cement retainer on 3.5" DP. Set Baker retainer @ 7215'. Pump cement. Squeezed. 49,389 CUM:$ 245,604 ETD:$ 0 EFC:$ 1,245,604 CUTTING 7" SECTION @ 7048 MW: 9.7 UNKN Continue to POOH w/ Baker running tool. RIH w/ section mill on BHA #1 to 7015' Start cut out @ 7015'. Mill from 7015' to 7048 @ 0600 hrs. 42,891 CUM:$ 331,386 ETD:$ 0 EFC:$ 1,331,386 HOLD PRESSURE ON SQUEEZE MW: 9.8 UNKN Continue cutting 7" section from 7048' to 7065', 17' section from 7015' to 7065'. POOH. Pump cement. CIP @ 0340 hrs. Estimate top cement @ 6767' 46,063 C~:$ 423,512 ETD:$ 0 EFC:$ 1,423,512 09/15/96 (D 6) TD: 6992' ( 0) SUPV: D LW DAILY:$ 09/16/96 (D 7) TD: 7420' (428) SUPV: DLW DAILY: $ 09/17/96 (D 8) TD: 8016' (596) SUPV: DLW ~W: 9.5 VISC: 48 PV/YP: 10/24 APIWL: 7.3 CIRC CMT CONTAMINATED MUD Bleed off pressure after squeeze. POOH w/3.5" DP. RIH w/3.5" DP. Found cement strings at 6250'. C/O tag cement @ 6885'. C/O cement from 6885' to 6992' Circulate cement contaminated mud & condition. 67,264 CUM:$ 279,020 ETD:$ 0 EFC:$ 1,279,020 Mgm: 9.7 VISC: 52 PV/YP: 18/26 APIWL: 5.5 DIRECTIONAL DRILL 6.125" HOLE Continue to clean out cement from 6992' to 7020'. Drill 10' of new hole from 7065' to 7075'. Do a FIT test @ 7065' MD. Continue directional drilling 6.125" hole from 7075' to 7420' 58,342 CUM:$ 337,362 ETD:$ 0 EFC:$ 1,337,362 ~W: 11.0 VISC: 46 PV/YP: 16/26 APIWL: 4.7 DRILLING AHEAD @ 8016' Continue directional drilling 6.125" hole from 7420' to 8016' Date: 11/6/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 DAILY:$ 53,982 CUM:$ 391,344 ETD:$ 0 EFC:$ 1,391,344 09/18/96 (D 9) TD: 8565' (549) SUPV:DEB DAILY:$ MW: 11.1 VISC: 46 PV/YP: 16/26 APIWL: 4.4 DRILLING @ 8565' Drill 8016' to 8565' 53,089 CUM:$ 444,433 ETD:$ 0 EFC:$ 1,444,433 09/19/96 (D 10) TD: 8580' ( 15) SUPV: DEB DAILY:$ [~: 11.5 VISC: 45 PV/YP: 17/22 APIWL: 4.2 POH Drill 8565' to 8580'. Monitor well - stable, no flow. Rotate and service rollers in kelly drive bushing while monitoring well. RIH. Kelly up and wash to bottom @ 8580', OK. Started seeing gas cut mud a little after half-way to bottoms up. Circulated out mud gas cut to +/- 7 ppg & trace of oil until 11.1+ ppg returns. Monitor well, no flow. Weight up to get trip margin. Monitor well, stable. POH 17 stands into 7" casing. Monitor well, stable. PU kelly & wash to bottom @ 8580', OK. Circulate once around, no gas cut. 46,184 CUM:$ 490,617 ETD:$ 0 EFC:$ 1,490,617 09/20/96 (D 11) TD: 8580'( 0) SUPV:DEB DAILY:$ MW: 11.5 VISC: 42 PV/YP: 16/17 APIWL: 4.4 CIRCULATE W/LINER @ TD Run 4.5" liner. 32,207 CUM:$ 522,824 ETD:$ 0 EFC:$ 1,522,824 09/21/96 (D 12) MW: 11.5 VISC: 42 PV/YP: 16/17 APIWL: 4.4 TD: 8580' ( 0) RUNNING 4.5" COMPLETION ASSY SUPV:DEB Pump cement. CIP @ 1000 hrs. Start running 4.5" completion assembly. DAILY:$ 116,659 CUM:$ 639,483 ETD:$ 0 EFC:$ 1,639,483 09/22/96 (D 13) TD: 8580' ( 0) SUPV: DEB DAILY:$ MW: 11.5 VISC: 41PV/YP: 16/15 APIWL: 4.8 TEST TREE - PREP TO DISPLACE Run 4.5" completion assembly. Using vent plug in tubing to prevent flowback. Tag and land locator at TOL @ 6831'. Land hanger. Set BPV. ND BOP stack. NU tree. Pull BPV, set TP. Test tree to 250/5000 psi. Test packoff to 5000 psi. 159,437 CUM:$ 798,920 ETD:$ 0 EFC:$ 1,798,920 09/23/96 (D 14) TD: 8580'( 0) SUPV:DEB DAILY:$ MW: 6.8 VISC: SLICKLINE - PULL RHC PLUG Freeze protect well. 36,766 CUM:$ 835,686 ETD:$ 0 PV/YP: 0/ 0 APIWL: 0.0 0 EFC:$ 1,835,686 09/24/96 (D 15) TD: 8580' ( 0) SUPV:DEB DAILY:$ MW: 6.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Release rig @ 1030 hrs. 9/23/96. 16,441CUM:$ 852,127 ETD:$ 0 EFC:$ 1,852,127 ARCO Alaska, Inc. A KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(3F-16A(W4-6)) 3F-16A DATE 11/12/96 DAY 3 DAILY JOB SCOPE JOB NUMBER PERFORATE, PERF SUPPORT 1018961617.6 DAILY WORK UNrl' NUMBER A SAND INITIAL PERFS OPERATION COMPLETE [ SUCCESSFUL [ KEY PERSON SUPERVISOR YES YES SWS-JOHNSON JORDAN Initial Tbg Press [FinalTbgPress [InitiallnnerAnn [FinallnnerAnn [InitialOutermnn I Final Outer ann 0 PSI 1000 PSI 0 PSI 0 PSI 0 PSI 0 PSI SUMMARY PERFORATED 8230'-8246' AND 8266'-8300' W/3-3/8", 4SPF, 180 DEG PHASE, HSD PERI; GUNS ORIENTED +/- 90 DEG FROM THE LOW SIDE OF THE HOLE. INITIAL A SAND PERFS COMPLETE. I TIME LOG ENTRY 10:30 MIRU SWS E-LINE UNIT. PT BOP, LUB 3500 PSI OK. 12:00 RIH W/20' X 3-3/8" HSD PERF GUN, 4 SPF. 180 DECreliASING, ORIENTED +/- 90 DEG FROM LOW SIDE OF THE HOLE. TIE INTO CBT DATED 11/12/96. 13:5 0 PRESS TBG TO 1000 PSI (+100 PSI OVER EST RES. PRESS) & MAINTAIN 14:05 PERF 8280'-8300'. TBG PRESS DROP FROM 1000 PSI TO 850 PSI. POOH 15:10 ON SFC. ALL SHOTS FIRED 15:40 RIH W/14' X 3-3/8" HSD PERF GUN, 4 SPF, 180 DEG PHASING, ORIENTED +/- 90 DEG FROM LOW SIDE OF THE tIOLE. 16:30 17:25 17:50 18:50 19:40 20:30 PERF 8266'-8280'. WHP 900 PSI. POOH. AT SFC. ALL SHOTS FIRED RIH W/16' X 3-3/8" HSD PERF GUN, 4 SPF, 180 DEG PHASING, ORIENTED +/- 90 DEG FROM LOW SIDE OF THE HOLE. PERF 8230'-8246'. WHP 1000 PSI. POOH. AT SFC. ALL SHOTS FIRED RDMO SWS Oil & Gas Cons. [;ommis~: Anchora,go SPE~. _-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT/3F-16A 5002921500201 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/11/97 TRUE sUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN DATE OF SURVEY: 091896 MWD SURVEY JOB NUMBER: AK-MW-60128 KELLY BUSHING ELEV. = 88.00 OPERATOR: ARCO ALASKA INC FT. COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 7020.00 5134.24 5046.24 45 4 N 44.74 W .00 3135.45N 2916.90W 7121.51 5206.35 5118.35 44 35 N 32.80 W 8.30 3191.03N 2961.58W 7214.86 5274.16 5186.16 42 30 N 19.20 W 10.27 3248.49N 2989.77W 7308.23 5343.50 5255.50 41 42 N 10.60 W 6.23 3308.85N 3005.87W 7402.12 5413.06 5325.06 42 54 N 2.00 E 9.11 3371.60N 3010.51W 2568.16 2614.93 2666.48 2723.03 2783.96 7493.95 5481.07 5393.07 41 35 N 8.00 E 4.61 3433.06N 3005.17W 7587.46 5550.33 5462.33 42 47 N 8.70 E 1.38 3495.20N 2996.04W 7681.51 5620.17 5532.17 41 17 N 8.60 E 1.60 3557.47N 2986.57W 7774.60 5690.79 5602.79 40 0 N 6.80 E 1.88 3617.55N 2978.43W 7868.18 5762.11 5674.11 40 42 N 8.60 E 1.45 3677.58N 2970.31W 2845.38 2908.16 2971.12 3031.70 3092.22 7960.63 5832.77 5744.77 39 35 N 8.50 E 1.19 3736.53N 2961.45W 8053.60 5904.14 5816.14 40 5 N 8.00 E .64 3795.49N 2952.90W 8147.53 5976.15 5888.15 39 47 N 9.00 E .75 3855.14N 2943.99W 8244.61 6050.30 5962.30 40 35 N 8.20 E .98 3917.09N 2934.62W 8340.32 6122.47 6034.47 41 30 N 8.40 E .95 3979.28N 2925.55W 3151.80 3211.34 3271.62 3334.26 3397.07 8432.89 6191.43 6103.43 42 12 N 10.40 E 1.63 4040.20N 2915.46W 8517.79 6254.22 6166.22 42 24 N 10.80 E .39 4096.37N 2904.94W 8580.00 6300.16 6212.16 42 24 N 10.80 E .00 4137.57N 2897.08W 3458.82 3515.95 3557.90 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5051.00 FEET AT NORTH 34 DEG. 59 MIN. WEST AT MD = 8580 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 10.22 DEG. TIE-IN SURVEY AT 7,020.00' MD WINDOW POINT AT 7,020.00' MD PROJECTED SURVEY AT 8,580.00' MD SPL f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, INC. KUPARUK RIVER UNIT/3F-16A 5002921500201 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/11/97 DATE OF SURVEY: 091896 JOB ~BER: AK-MW-60128 KELLY BUSHING ELEV. = 88.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 7020.00 8020.00 8580.00 5134.24 5046.24 5878.44 5790.44 6300.16 6212.16 3135.45 N 2916.90 W 1885.76 3774.05 N 2955.91 W 2141.56 255.80 4137.57 N 2897.08 W 2279.84 138.28 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SP~ f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT/3F-16A 5002921500201 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/11/97 DATE OF SURVEY: 091896 JOB NUMBER: AK-MW-60128 KELLY BUSHING ELEV. = 88.00 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 7020.00 5134.24 5046.24 3135.45 N 2916.90 W 1885.76 7095.73 5188.00 5100.00 3176.11 N 2951.34 W 1907.73 21.97 7233.59 5288.00 5200.00 3260.49 N 2993.70 W 1945.59 37.86 7368.09 5388.00 5300.00 3348.59 N 3010.34 W 1980.09 34.49 7503.22 5488.00 5400.00 3439.15 N 3004.31 W 2015.22 35.14 7638.67 5588.00 5500.00 3529.49 N 2990.80 W 2050.67 35.45 7770.96 5688.00 5600.00 3615.23 N 2978.71 W 2082.96 32.29 7902.33 5788.00 5700.00 3699.59 N 2966.98 W 2114.33 31.37 8032.50 5888.00 5800.00 3782.03 N 2954.79 W 2144.50 30.17 8162.96 5988.00 5900.00 3864.89 N 2942.44 W 2174.96 30.46 8294.34 6088.00 6000.00 3949.18 N 2929.98 W 2206.34 31.38 8428.26 6188.00 6100.00 4037.15 N 2916.02 W 2240.26 33.92 8580.00 6300.16 6212.16 4137.57 N 2897.08 W 2279.84 39.57 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS r'l !:! I I_1_ I ~ G S I::: I::t L/I I-- G S WELL LOG TRANSMITTAL To: State of Alaska March 19, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor ~/?.~ \ 3001 Porcupine Dr. q L0 ~ '~ cl Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS 3F-16A, AK-MW-60128 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' ,run Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21502-01 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 F11 I._1_ I r~l CS S E !::t ~./I l-- E c: WELL LOG TRANSMITTAL To: State of Alaska February 19, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ci RE: MWD Formation Evaluation Logs DS 3F-16A, AK-MW-60128 The technical data 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 DS 3F-16A: 2" x 5" MD Gamma Ray Logs: 50-029-21502-01 2" x 5" TVD Gamma Ray Logs: 50-029-21502-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, A~aska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company February 11, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Dear Sir/Madam, Re: MWD Survey 3F-16A Enclosed is one hard copy of the above mentioned file(s). Well 3F-16A Tie in point 7,020.00', window point 7,020.00', interpolated depth at 8,580.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company 11/20/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10585 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1 .B-15. ..... ~"q---, (.7~ ~' i PRODUCTION LOG W!TH DEFT 961110 1 1 3F-16A .... c!_(o- I~--I CEMENT BOND LOG-CBT ., 961111 I 1 3F-16A ~ CEMENT BOND LOG-SET-J/GE 961 1 1 1 I 1 , , ,,, ............ ., ., Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 10, 1996 Blair Wondzell, ~ P. !. Supervisor ,)!~1~, .OM: Petroleum Inspector FILE NO: ACVIIJDD.DOC BOP Test Nordic #2 KRU - 3F-16A PTD# 96-0151 Tuesday, September 10,1996: I traveled this date to ARCO's KRU well 3F-16A being sidetracked by Nordic rig 2 and witnessed the BOPE test. As the attached AOGCC BOPE test report shows there were no failures of the equipment tested. The lower pipe rams, blind rams, upper and lower kelly valves and dart floor safety valve will be tested after the tubing is pulled. A back pressure valve could not be installed in the tubing due to the FMC well head equipment. I discussed this with Don Wester, ARCO rep., and since the perferations had been cemented I agreed to letting the tubing be pulled before testing the above listed equipment. The rig was clean and ali equipment seemed to be in good working order. The pad was small but there was good access toall areas of the rig. SUMMARY: ! witnessed the BOPE test on Nordic rig 2 sidetracking ARCO's 3F-16 - test time 2 hours - no failures. Attachments: ACVIIJDD.XLS X Unclassified Classified Unclassified with Document Removed STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drig Contractor: Operator: Well Name: Casing Size: 7" Test: Initial X Workover: Nordic Rig No. 2 PTD # ARCO Alaska Inc. Rep.: 3F-IOA Rig Rep.: Set @ 8198'- PBD Location: Sec. Weekly Other 96-0151 DATE: 9/10/96 Rig Ph.# 659-7115 DON WESTER LANCE 19 T. 12N R. 8E Meridian Umiat MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P ,, Well Sign P Dri. Rig P Hazard Sec. P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan, Test Pressure 500/3500 P/F 500/3500 500/3500 ' 500/3500 BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 250/3000 P I 500/3500 I 500/3500 P 1 2 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P 500/3500 P 500/3500 ,NOTE ~IO TE 500/3500 5OO/35OO CHOKE MANIFOLD: No. Valves 12 ~ J No. Flanges 32 Manual Chokes 1 Hydraulic Chokes I . Test Pressure P/F 500/3500 P 500/3500 Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pres_~ure After Closure 200 psi Attained After Closure 0 System Pressure AttainedMast~;: Blind Switch Covers: Nitgn. Bti's: Four Boffies 2100 Avg. 3,000 I P 2,2~o p ~H,~u[u= '/6 sec. ~ minutes ~ sec. P Remet~-~---. P Psig. Number of Failures: 0 ,Test Time: 2.0 Hours. Number of valves tested 18 Repair or Replacement of Failed Equipment will be made within 1 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Pax No 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: NOTE: The upper andlower kelly valves, floor safety dart valve, lower pipe rams and blind rams will be tested afler the tubing is pulled out of the hole. Distribution: orig-Weil File c - Oper./Rig c- Database c - Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES NO X Waived By: Witnessed By: BOBBY D. FOSTER F!-021L (Rev. 12/94) ACVIIJDD.XLS TONY KNOWLE$, GOVERNOR ~ KA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 29, 1996 Mr. Mike Zanghi, Drill Site Develop. Supv. ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 3F-16A ARCO Alaska Inc. 96-151 82' FSL, 227' FEL, SEC. 19, T12N, R09E, UM 1102' FN-L, 1691' FWL, SEC. 19, T12N, R09E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-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) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Commissioner BY ORDER OF THE COMMISSION dlf/encl c: Dept ofFish & Game, Habitat Section - w/o encl Dept 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 Redrill X lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry [~ Deepen r-I Service E] Development Gas E] Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 88', Pad 56' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25632, ALK 2565 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.025) 82' FSL, 227' FEL, Sec. 19, T12N, RDE, UM Kuparuk River Unit Statewide At top of 'productive interval 8. Well number Number 1485' FNL, 1623' FWL, Sec. 19, T12N, RDE, UM 3F-16A #U-630610 At total depth 9. Approximate spud date Amount 1102' FNL, 1691' FWL, Sec. 19, T12N, RDE, UM ~/7/96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'IYD) property line 3 F- 1 7 8537' MD 1623' @ Top Intvl feet 15' @ surface feet 2560 6273' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 7020' feet Maximum hole angle 45.1 o Maximum.surface 2840 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6-1/8" 4-1/2' 12.6# L-80 NSCT 1722' 6815' 4993' 8537' 6273' 213 sxs Class G 19. To be completed for R edrill, Re-entry, and Deepen Operations. ~'~ ~ {r-~. Present well condition summary Total depth: measured 8600 feet Plugs (measured) ,~,ll~ ~ ~_ '~ true vertical 6266 feet Effective depth: measured 8484 feet Junk (measured) ~l~tS[(~ 0,!1 ~ ~-2S 00,qS. C0.~,ITIiSS{0t3 true vertica 6180 feet Casing Length Size Cemented Measured depth True Vertical deplh Structural Conductor 80' 1 6" 328 Sx AS II I 15' 1 16' Surface 3849' 9-5/8' 1125 sx PF E, 425 sx G 3884' 3046' Intermediate Production 8538' 7 ' 250 sx Class G, 180 sx Permafrost C 8573' 6246' Liner Perforation depth: measured 8369'-8381', 8273'-8322', 8014'-8112' MD O R ! Gl NA L true vertical 6102'-6110', 6032'-6071', 5845'-5916' TVD 20. Attachments Filing fee X Property plat E] BOPSketch X Diverter Sketch F~ Drilling program X Ddlling fluid program X Time vs depth plot ~ Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify ti!at the fore(~oing is true and correct to the best of my knowledge Signed ~/~, /'~_.;_/~ Title Drill Site Develop. Supv. Date ' / / "~ Commission Use Only/ t~/l~ .~:~'l"number .... ~ Approval da~ Perm~:::~lzbe.~,/,..,4"/_ r50. d:::22..~- .2~__.. / ._5 ,~..~ <::~/ I r-~'--' ~F-/~'~::2 ISee c°ver loiter f°rother requiremenls Conditions of approval Samples required ~ Yes /~ No Mud logrequired E] Yes ~] No Hydrogen sulfide measures /~ Yes E] No Directional survey required ~ Yes ~ No Required working pressure for BOPE [--I 2M E] 3M E] 5M FI 1OM ~ 15M ~ Other: Original Signed By by order of Approved by ruckerman Babcock Commissioner the commission Date {~)- ¢;~ ~-' /~' Fnrm 11~-41~1 Rp.v 7-24-R.Cl R,~hmit in trinlinRlR REDRILL PLAN SUMMARY Well 3F-16A Type of well (producer/injector): Surface Location: Top Producing Interval: Bottom Hole Location: MD: TVD: Rig- Estimated Operation Start Date: Days to Complete: Injector 82' FSL, 227' FEL, SEC 19, T12N, R9E, UM 1485' FNL, 1623' FWL, SEC 19, T12N, R9E, UM 1102' FNL, 1691' FWL, SEC 19, T12N, R9E, UM 8537' 6273' Nordic Rig 2 9-06-96 14 Drill Fluids Program- Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Milling Section in 7" casing 9.4 >25 15-35 85-95 20-30 30-40, .. 8.5-9.5 Kick off to weight up 9.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.6 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Swaco Geolograph Adjustable Linear Shaker Brandt SMC-10 Mud Cleaner Triflow 600 vacuum Degasser, Poor Boy Degasser Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators and Jetting Guns Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page 1 Casing/Tubing Hole size 6-1/8" Program: Csg/'rbg 4-1/2", 12.6#, L-80, NSCT Tubing 4-1/2", 12.75#, L-80, EUE Length Top (MD/TVD) Btm (MD/TVD 1722' 6815'/4993' 8537'/6273' 6789' 26'/26' 6815'/4993' Cement Calculations: Casina to be cemented: -- 4-1/2" in 6-1/8" open hole Volume = 213 sxs of class G Blend @ 1.19 cu ft/sx Based on: Shoe volume, open hole volume + 55%, & 200' liner lap. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 2,840 psi and is calculated using a gas column to surface. The expected leak-off at the section cut in the 7" casing is estimated at 13.5 ppg EMW. With an expected formation pressure in the Kuparuk of 3500 psi and a gas gradient of 0.11 psi/fi, this shows that formation breakdown would not occur before a surface pressure of 2,840 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE schematic. Drilling Hazards: Lost Circulation: Overpressured Intervals: Other Hazards: The suspect lost circulation zones throughout the Kuparuk field are the K- 10 and the K-5 intervals. The sidetrack 3F-16A, will kick off out of the 7" casing below both the K-5 and K-10. The casing around the kick-off window will be squeezed with cement prior to drilling out, which should isolate both the intervals from sidetrack operations. If the cement squeeze is unsuccessful at achieving isolation, it is believed that both intervals should be able to handle the expected mud weights to be used for this sidetrack. Recent infill drilling data shows that wells in the area of 3F-16A were drilled to TD through the K-5 and K-10 intervals with mud weights as high as 12.6 ppg and no loses. The kick-off point in 3F-16A is below any zones which would be of pressure concern prior to weighting up for the Kuparuk interval. None Directional: KOP: Max hole angle: Close approach: 7020' MD / 5134' TVD 45.1° (in sidetrack portion) No Hazards 54.2° (in original well at 3500' MD) Page 2 Logging Program: Open Hole Logs: GR/Resistivity Cased Hole Logs: GR/CCL Notes: All ddll solids generated from the 3F-16A sidetrack will be hauled to CC-2A in Prudhoe Bay for grind and inject. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or to Parker 245 to be disposed by annular pumping into the permitted annulus Parker is connected to at that time. The permitted well will be within the Kuparuk River Unit. Page 3 KRU 3F-16A GENERAL SIDETRACK PROCEDURE PRE-RIG WORK: . RIH with inflatable cement retainer on CTU. Set inflatable retainer in 2-7/8" tubing tail below bottom packer. Pump cement squeeze below retainer and into A Sand perfs with enough cement volume to fill the 7" casing from the retainer depth, down to 50' below the bottom A Sand perf. Unsting from retainer and circulate the well clean. . RU slickline unit. RIH and pull sleeve from AVA ported nipple at 8166' MD. Pull the dummy valves from the C Sand GLM at 7974' MD and from the bottom GLM at 7904' MD, leaving open pockets in each. Dummy off all other GLM's. 3. Set BPV in tubing. Install VR plug in annulus valve if necessary. WORKOVER RIG WORK: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits w/kill weight mud. Circulate well to kill weight mud. Ensure well is dead. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH laying down all tubing and jewelry. . PU DP and RIH with cement retainer. Set retainer at 7220' MD. Down-squeeze 38 bbls cement below retainer into perfs filling 7" casing across the C Sand with excess cement to squeeze into C Sand perfs. Unsting from retainer and circulate well to milling fluid. Spot an 18 ppg balanced mud pill from PBTD to the base of proposed section. POOH standing back DP. 6. RIH w/section mill. Cut a 50' section in the 7" casing from 7020' - 7070'. POOH w/mill. 7. RIH w/open ended DP. Wash down through section and circulate any metal shavings f/well. Mix and pump balanced cement kick-off plug f/100' below base to 200' above top of section. POOH. . RIH w/6-1/8" bit, mud motor, MWD/LWD, and steerable drilling assembly. Dress off cement to top of section. Kick-off well and directionally drill to total depth as per directional plan. Short tdp to window in casing. POOH. 9. Run 4-1/2" liner to TD w/200' of overlap to top of milled section. 10. Cement liner. Set liner hanger. POOH w/DP. 11. RIH w/completion assembly and sting into polished bore receptacle at top of liner. Space out. Displace well to sea water at max rate. Set production packer. Test tubing, liner, and annulus. 12. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. 13. Clean out well to PBTD w/coiled tubing. Run Cement Evaluation tool & perforate through tubing. Lower Limit: 12 days Expected Case: 14 days Upper Limit: 20 days No problems milling section, drilling new hole, or running completion. Difficulties encountered milling section, or drilling new hole. WSI 8/2O/96 Page 4 Creoted by jones For: B [SAACSON Date plotted: 20-Aug-96 Plot Referenco is 16A Version ~5. I Coordinates ore in feet refersnco slot N '1.0.22 DEG E 3383'(T0 TARGET) ***Plane of Proposal*** ARCO ALASKA, inc. Structure : Pod 3F Well : 16A Field : Kuparuk River Unit · Location : North Slope, Alaska WELL PROFILE DATA ..... Point MD Inc D[r TVO North East V. SectDeg/lO0 . KOP 7020.00 45.07 .315.265154.24 3135.45-2916.90 2567.93 0.00 End of Drop/Turn 7549.10 41.50 10.22 5533.19 .3452.12 -3021.27 2863.04 7.00 Tarcjst .3F-16A g-Jul-g6 8536.66 41.50 10.22 6125.00 3965.73-2926.63 3582.93 0.00 T.O. ~ End of Hold8636.66 41.50 10.22 6272.78 4096.16-2905.11 3515.47 0.00 50OO 5100 5200 5300 5400 5500 5600 0 5700 .ii > 5800 i~. 5900 ' I 6000 6100 62O0 6300 6400 ¢2.87KOP - Sidetrack Point 40.86 BLS: 7.00 de9 per 100 ft 39.79 39.72 40.6%-30 End Drop / Turn B/ HRZ K- 1 Marker Top Units D/C AVERAGE ANGLE 41.5 DEG Top Unit A <- West (feet) 3450 3300 3150 3000 2850 2700 I ! ~ J ~ I I J I ~ 4350 4200 4050 59oo A I 3750 3600 3450 3300 5150 3000 TARGET - B/ KUP SANDS TO / Casing Pt i i i i I i i i i , i i ' ! i i ' -i i i i i i i i t I 2500 2600 2700 2800 2900 3000 31 O0 3200 3300 3400 5500 3600 3700 Verfical Secfion (feel) -> Azimuth 10.22 with referonee 0.00 N, 0.00 W from slot #16A 7-1/16" 5000 PSI BOP STACK ACCUMULATOR CAPACITY TEST I 6 PIPE RAM > / I I I ={~ 5 BLIND RAM~ MUD < 3PIPE RAM > I L._ t' 1 L~ I 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURETHAT 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 THATTEST 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 5 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND OUTSIDE MANUAL VALVE ON KILL LINE. 6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3500 PSI HIGH. TEST AS 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 BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3500 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BLIND RAMS AND TESTTO 3500 PSI FOR 5 MINUTES. BLEED TO ZERO PSI. 11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL (DF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRIllING POSITION. 12. TEST STANDPIPE VALVES TO 3500 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP. 14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1.11"- 3000 PSI CASING HEAD 2.11" - 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16"- 5000PSI SINGLE GATE W/PIPE RAMS 4.7-1/16"- 5000 PSI DRLG SPOOL W/CHOKE & KILL LINES 5.7-1/16"- 5000 PSI SINGLE GATE W/ BLIND RAMS 6.7-1/16" - 5000 PSI SINGLE GATE W/PIPE RAMS 7.7-1/16"- 5000 PSI ANNULAR PREVENTER NORDIC RIG g2 LEVEL I 28'-6" Z L~ 73'-0' i = 25'-0" '~' ~ SPIRAL n' STAIRS - :2 EMSCO F-800 ~ 0 (~ TRIPLEX MUD(~~': ~ PUMP _,. EMSCO F-800 (~ TRIPLEX MUD PUMP SPIRAL STALES CONTROL ~CONSOLE ~NORDIC RIG LEVEL 90'-0" 3~' NORDIC RIG ~2 LEVEL uN~ SPOOL US*R~R AIR HEATER MUD TANK 750 OBLS SPIRAL STAIRS CHOKE MANIFOLD OFFICE WATER TANK /GLYCOL TANK . HYORAUUC · =! 84'-0' RACK . STATE OF ALASKA , ~' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~X Suspend Alter casing _ Repair well Change approved program_ Operation Shutdown_ Re-enter suspended well _ Plugging ~ Time extension Stimulate Pull tubing_ Variance_ Perforate _ Other Plugback for X Reddll 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 82' FSL, 227' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1589' FNL, 3639' FEL, Sec 19, T12N, R9E, UM At effective depth 1365'-'FNL, 3850' FEL, Sec. 19, T12N, RgE, UM At total depth 1310' FNL, 3945' FEL, Sec. 19, T12N, R9E, UM 12. Present well condition summary Total Depth: measured (approx) true vertical 8600' 6266' Effective depth: measured 8484' (approx) true vertical 61 80' 5. Type of Well: Development Exploratory Stratig raphic Service feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 93', Pad I~lev. 56' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3F-16 9. Permit number 85-294 10. APl number 50-029-21502 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool feet Junk (measured) feet Casing Length Size Structural Conductor 8 0' i 6" Surface 3849' 9- 5/8 ' Intermediate Production 8538' 7 ' Liner Perforation depth: measured 8369'-8381 ', 8273'-8322', true vertical 6102'-6110', 6032'-6071', Cemented 328 Sx AS II 1125sxPF E& 425 sx Class G 250 sx Class G & 180 sx PFC 8014'-8112' 5845'-5916' Tubing (size, grade, and measured depth) 3-1/2", J-55, @ 8203' MD Packers and SSSV (type and measured depth) Baker 'FHL' @ 7937'r Baker 'FB-I' @ 8181', Camco 'TRDP-1A' SSSV @ 1814' 115' 115' 3884' 3046' 8573' 6246' RECEIVED AUG 1 9 1996 Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal ~X Contact William Isaacson at 263-4622 with any questions. 14. Estimated date for commencing operation August 25. 1996 16. If proposal was verbally approved Detailed operation program__ BOP sketch 15. Status of well classification as: Oil X Gas __ Suspended Name of approver , Date approved Service 117. I hereby certi~ that the/~oregoing is true and correct to the best of my knowledge. ISic~ned J[~'~C, Title Drill-Site Development Supv I - L'""N~t~ FOR COMMISSION USE ONLY Conditions of approval: ify Commission so representative may witness I Plug integrity ..L,,/ BOP Test ~ Location clearance__ Mechanical Integrity Test_ Subsequent form require Original Signed By I Approved by the order of the Commission Tuckerman'Babcock Commissioner Date ~'"( ('"'---f,~, IIAppr°val No~- /')1 Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Returne~o-1 ,, , · WELL PERMIT CHECKLIST COMPAN ., c'"Z--r ) FIELD & POOL ~'~;;'4:3,,'~,~ C"~ INIT CLASS ,~~ /-,~ ~/ ~DMINISTRATION ........ WELL NAME,/'~~- ,-~ -/~""//~-¢~PROG~: exp [] der [] reddl .~. ~rv [] wellbore seg [] ann. disposal para req [] GEOL AREA .~,c~ UNIT# 7,//~'¢ ON/OFF SHORE 1. Permit fee attached ....................... /Y'] N 2. Lease number appropriate ................... l!' N 3. Unique werl name and number ................. N 4. Well located in a defined pool .................. N 5. Well located proper distance from ddg unit boundary ...... N 6. Well located proper distance from ol~er wells ......... N 7. Sufficient acreage available in drilling unit. .......... N 8. If deviated, is wellbore plat included .............. ~ N 9. Operator only affected party ................... I N 10. Operator has appropriate bond in force ............ t N 11. Permit can be issued wf'd~out conservalJon order ...... ~ N 13. Can permit be approved before 15-(:lay wait. ........ [~ N _ _ , ..................... ENGINEERING REMARKS APPR D,~TE 14. Conductor s~ng provided ................... Y N 15. Surface casing protects ail known USDWs .......... Y N/~ ( ~-- 16. CMT vol adequate to circulate on conductor & surf csg .... Y NI~ 17. CMT vol adequate to lJe-in long sl~'ing to surf csg ....... Y_.. N/ . 18. CMT will cover all known productive horizons ......... 19. Casing designs adequate for C, T, B & permafrost. ..... Y(~N _ 20. Adequate tankage or reserve pit. ............... {~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved .... ~c,~N _ ___ 22. Adequate wellbore separation proposed ............ 23. If diverter required, is it adequate ................ -.-Y--N'--~ 25. 27. N ,t~--'P~- I.~' 28. 29. Drilling fluid program schematic & equip list adequate .... BOPEs adequate ........................ BOPE press ra~Jng adequate; test to '~ ~"0"-0 psig. Choke manifold complies w/APl RP-53 (May 84) ....... i Work will occur wibhout operation shutdown .......... Is presence of H2S gas probable ............... "GEOLOGY ..................... ~ 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N/ ~ ,,~ 31. Data presented on potential overpressure zones ....... Y 32. Seismic analYSis of shailow gas zones ............. / N / - ~' ' : 33. Seabed condition survey (if off-shore) ........... ./Z. Y N A~PPR D/~TE ~ 34. Contact name/phone for weekly progress reports .... /.. Y N ~ _~_/~¢.,~ , ~exp~ratory only] GEOLOGY: ENGINEERING: COMMISSION: BEW DWJ JDH .~"~ JDN~ TAB ~ Comments/Instructions: HOW/I~ - A~OR~ist rev ,V96 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. Sperry-Sun Drilling Services LIS Scan Utility Thu Mar 13 16:26:55 1997 Reel Header Service name ............. LISTPE Date ..................... 97/03/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 97/03/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific ROFILM Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY 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: MWD RUN 1 AK-MW-60128 STEVE NEUBAU DON WESTER 3F-16A 500292150201 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 13-MAR- 97 MAR 20 ]991 TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 12N 09E 82 227 88.O0 .00 56.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 7015.0 6.125 8580.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUN 1 IS DIRECTIONAL WITH SCINTILLATION TYPE (NGP) GAMMA RAY. 4. KICK OFF POINT AT 7015'MD, 5134'TVD THROUGH WINDOW IN 7" CASING. 5. THIS WELL RE~CHED A TOTAL DEPTH (TD) OF 8580'MD, 6300'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/13 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: .5000 FI LE SUMMARY PBU TOOL CODE START DEPTH GR 6945.0 ROP 7016.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 6950.0 6945. 6993.0 6988. 7026.5 7021. 7055.0 7052. 7086.0 7079. 7088.0 7083. 7091.5 7087. 7101.0 7095. 7103.5 7097. 7119.5 7114. 7131.0 7125. 7138.0 7132. 7140.0 7134. 7142.5 7136. 7215.0 7207. 7218.0 7212. 7268.5 7261. 7271.0 7264. 7316.5 7311. 7329.5 7323 7331.0 7325 7340.0 7333 7362.5 7356 7387.5 7382 7394.5 7389 7409.5 7406 7412.0 7407. 7430.0 7426. 7438.0 7434. 7464.5 7461. 7473.5 7469. 7479.5 7477. 7488.5 7485. 7499.0 7496. 7514.0 7510. 7528.0 7524. STOP DEPTH 8507.5 8578.5 EQUIVALENT UNSHIFTED DEPTH -- 7542.5 7553 5 7560 0 7571 0 7582 5 7586 5 7598 0 7611 0 7622 5 7629 0 7633 5 7640 5 7644 5 7663.5 7673.5 7679.5 7687.0 7697.0 7702.0 7709.5 7715.5 7722.5 7728.5 7732.5 7769.0 7773.5 7806.5 7891.5 7908.0 7915.5 7928.0 7957.5 7992.0 8031.0 8096.5 8100.5 8194.0 8223.5 8235.0 8238.0 8262.0 8266.0 8276.0 8289.5 8296.5 8316.5 8368.0 7539.0 7550.5 7557.5 7567.5 7579.5 7584.5 7595.0 7607.0 7619.0 7626.5 7631.0 7637.5 7642.0 7661.5 7671.0 7677.5 7685.0 7694.5 7699.5 7707.5 7713.5 7720.5 7727.0 7730.5 7766.0 7770.5 7803.5 7889.0 7906.5 7913.5 7927.0 7957.0 7992.0 8031 5 8097 5 8101 5 8194 0 8223 5 8234 5 8237 5 8262 0 8266 0 8276.0 8289.5 8295.5 8315.0 8366.5 8371.5 8370.0 8375.5 8374.0 8580.0 8578.5 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 REMARKS: MERGED MAIN PASS. $ MERGE TOP MERGE BASE 7020.0 8580.0 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 ~ 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 6945 8578.5 7761.75 3268 6945 RO? 2.24 1044 49.8725 3126 7016 GR 34.94 461.94 111.463 3126 6945 Last Reading 8578.5 8578.5 8507.5 First Reading For Entire File .......... 6945 Last Reading For Entire File ........... 8578.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/13 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 ....... 97/03/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 P~AW 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 DE~TH STOP DEPTH GR 6950.0 8509.0 ROP 7021.0 8580.0 $ LOG HEADER DATA DATE LOGGED: 18-SEP-96 SOFTWARE 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: 39.6 MAXIMUM ANGLE: 45.1 TOOL STRING (TOP TO BOTTOM) MSC V.1.32 DEP V.2.04/NGP V.5.74 MEMORY 8580.0 7020.0 8580.0 VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 94 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.130 6.1 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: Low Solids 11.10 46.0 9.5 80O 4.4 .000 .000 .000 .000 17.4 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .6 REMARKS: OBJECTIVE : Kickoff cement plug, turn well and drill to TD RESULTS : TD @ 8580'MD 6300'TVD. $ 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 GRD1 MWD 1 AAPI 4 1 68 4 2 ROP1 MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 6950 8580 7765 3261 6950 GRD1 34.94 461.94 111.449 3118 6950 ROP1 2.24 1044 49.8359 3119 7021 Last Reading 8580 8509 8580 First Reading For Entire File .......... 6950 Last Reading For Entire File ........... 8580 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/03/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 97/03/13 Origin ................... STS Scientific Technical Services Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File