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186-179
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3Q-16 KUPARUK RIV UNIT 3Q-16 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 3Q-16 50-029-21667-00-00 186-179-0 W SPT 6422 1861790 3000 2930 2930 2930 2930 100 120 120 120 REQVAR P Josh Hunt 8/28/2024 This is a 2 year MIT-IA required by AIO 02B.082. This well was tested to a starrting pressure of 3500 psi. 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 3Q-16 Inspection Date: Tubing OA Packer Depth 290 3500 3400 3380IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240828164307 BBL Pumped:2.8 BBL Returned:2.7 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 999 9 99 9 9 9 9 9AIO 02B.082. James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 14:26:23 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 30, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3Q-16 KUPARUK RIV UNIT 3Q-16 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 3Q-16 50-029-21667-00-00 186-179-0 W SPT 6422 1861790 3000 2857 2857 2858 2856 210 240 240 240 REQVAR P Bob Noble 8/13/2022 MITIA as per AIO 2B.082, to max injection pressure. 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 3Q-16 Inspection Date: Tubing OA Packer Depth 925 3500 3415 3410IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN220814155547 BBL Pumped:2.2 BBL Returned:2 Tuesday, August 30, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.30 15:39:47 -08'00' MEMORANDUM State of Alaska Packer Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Tuesday, August 18, 2020 P.I. Supervisor e � ��' SUBJECT: Mechanical Integrity Tests w TVDp ConocoPhillips Alaska, Inc. Tubing2863 3Q-16 FROM: Brian Bixby KUPARUK RIV UNIT 3Q-16 Petroleum Inspector 'Type Test SPT Test SI Src: Inspector I IA � 710 Reviewed By ---- P.I. Supry J�;r— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-16 Insp Num: mitBDB200816081002 Rel Insp Num: API Well Number 50-029-21667-00-00 Inspector Name: Brian Bixby Permit Number: 186-179-0 Inspection Date: 8/15/2020 ✓ Tuesday, August 18, 2020 Pagel oft Packer Depth Pretest Initial 15 Min 30 Min Min 60 Min Well Type Inj -- w TVDp 6422 Tubing2863 2864' — 2864 2864- r45 PTD 1861790 'Type Test SPT Test SI 3000 I IA � 710 43 3480 3430 - 3420 ---- BBL Pumped: r 25 BBL Returned: 2.5 OA 240 280" 280 -1 -- 280 Interval REQVAR IP/F P ✓ - — - Notes: MITIA as per AIO 28.082 V Tuesday, August 18, 2020 Pagel oft • • --" S WELL LOG TRANSMITTAL p. DATA LOGGED Z Al/2011 PROACTIVE DIAgNOSTIC SERVICES, INC. M.K.SENDER RECEIVED JUL 1 3 2017 To: AOGCC Makana Bender AOGCC 333 West 7th Avenue AO Suite 100 Anchorage, Alaska 99501 (907) 793-1225 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 attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED AUG 1 02017, 1) Caliper Report 14-Jun-17 30-17 1 Report /CD 50-029-21795-00 2) Caliper Report 15-Jun-17 3Q-16; 1 Report /CD 50-029-21667-00 Signed : ,,it.(fZ•ct�ha� G ��;,G�;e Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFi les\Templates\Distribution\TransmittalSheets\ConocoPhillipsTransmit.docx k'C G 1°)i$ECEIVE S's5 JUL t 3 2017 Memory Multi-Finger Caliper tit 1110 AOGCC Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3Q-16 Log Date: June 15, 2017 Field: Kuparuk Log No.: 14259 State: Alaska Run No.: 1 API No. 50-029-21667-00 Pipe Description: 2.875 inch 6.5 lb. L-80 EUE 8RD ABMOD Top Log Interval: 43 Ft. (MD) Pipe Use: Tubing Bottom Log Interval: 6,915 Ft. (MD) Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS : This caliper data is tied into the top of GLM 6 at 6,869 feet(Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 2.875 inch tubing logged appears to be in good condition, with the exception of a 24%wall penetration at an isolated pit in joint 214 (6,857 ft). No other significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. Although no significant I.D. restrictions are recorded, the caliper recordings indicate slight cork-screwed tubing from—4,300 feet to 6,915 feet(end of log). A 3-D log plot overlay of the centered and un-centered caliper recordings across the tubing logged is included in this report. MAXIMUM RECORDED WALL PENETRATIONS : .'escrip otl -'ttt f-f V,,ial Htrat;;iii Isolated Pitting 24 214 6,857 Ft. (MD) No other significant wall penetrations(> 17%) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (>5%)are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. SCANNED AUG 0 3 2017, C. Goerdt C. Waldrop J. Fama F leld Lngineef'(5) Ana yst(s) 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: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • CIS PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3Q-16 Date : June 15, 2017 Description : Overlay of Centered and Un-Centered Caliper Recordings From Surface to 6,915 Feet. Nominal I.D./O.D. 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M illliiifi111tliiffi11111!! 6450 . .: - 1 f!!!lE7REi!!! !elf MUNIIlAiI®! - Nf>i1!!MIfil■m� 4 fififlta� !!•6500 fi—fif111111 i�f1�f1•!fi ,� A� -- ® !l �f•fiwMii!! _ ! iiE,[IIIIIINI �i!! - . fi !!'!iffiiifi!6550 - _ iIi � iM _ 11111!ltL111111!!!11111 f1■ffif11121111: �: ! fif�iii�lillfi 6600 - li lam!! _ _ ® � a� neQ� ���r��� !E�lIFEtiM![��mm 11111211111111111%111111111011111= ..-_ 7 iommllira— i i 6650m 1111111119111=1111111111114X2111111111111k T �5�!l1�i���lfi if•f�fif•181 fif�IIIIMElli • ___ .. �,. 6700 - ,..-ili i ......... i - �{iil1ir�llllllim . . 6750 ' '., - !!!#i - ,,...!illi!:1' ..... - !!Mhi ®! � ^'' 6800 W... _.- - 6850 --- - ■■situ e • 7.. is $ !lEl111i 6900 • I Minimum Radius 1 inches 1.5 Maximum Radius 1 inches 1.5 Minimum I.D. I I 2 inches 3 Maximum I.D. I I 2 inches 3 Nominal I.D./O.D. Depth 3-D Log(Un-Centered) Image Map(Un-Centered) 3-D Log(Centered) Image Map(Centered) ' 1:900 2 3 348° 0° 90° 180°270° 0° 0° 0° 90° 180°270° 0° • • Correlation of Recorded Damage to Borehole Profile • Pipe 1 2.875 in (42.5'-6,915.0') Well: 3Q-16 Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: June 1 5,2017 ■ Approx.Tool Deviation ■ Approx. Borehole Profile 1 43 25 797 50 1,591 '4410 75 2,405 GLM 1 100 J 3,203 � - c Z L 125 3,994 fl- '5 Q GLM 2 150 4,791 GLM 3 175 5,589 GLM 4 GLM 5 200 6,387 GLM 6 214.4 6,906 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=214.4 • • PDS Report Overview Body Region Analysis Well: 3Q-16 Survey Date: June 15,2017 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 2.875 in. 6.5 ppf L-80 EUE 8RD ABMOD Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 2.875 in. 6.5 ppf L-80 EUE 8RD ABMOD 2.441 in. 43 ft. 6,915 ft. Penetration(%wall) Damage Profile(%wall) 250 mi Penetration body mow Metal loss body 0 50 100 1 200 150 100 50 51 0 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analyzed(total=216) GLM 1 (11:00) 215 1 0 0 98 Damage Configuration(body) 30 GLM 2 (3:30) 20 147 10 GLM 3 (5:00) 0 GLM 4(10:00) 195 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole GLM 5 (4:00) Number of joints damaged(total=32) GLM 6 (10:30) 23 0 9 0 0 Bottom of Survey=214.4 • • PI PDS Report Joint Tabulation Sheet Well: 3Q-16 Survey Date: June 15,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 2.875 in. 6.5 ppf L-80 EUE 8RD ABMOD Tubing 2.441 in. 0.217 in. 43 ft 6,915 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 1 43 0 0.02 9 2 2.37 Lt. Deposits. 2 68 0 0.02 9 2 2.39 3 100 0 0.03 14 2 2.37 Lt. Deposits. ■ 4 132 0 0.03 14 2 2.39 5 163 0 0.02 10 2 2.39 6 195 0 0.02 7 2 2.39 7 227 0 0.02 11 2 2.37 Lt. Deposits. ■ 8 259 0.03 0.02 11 3 2.39 9 290 0 0.02 10 3 2.35 Lt. Deposits. 1 10 322 0 0.03 13 3 2.39 ■ 1 11 354 0 0.03 12 2 2.35 Lt. Deposits. ■ 12 385 0 0.02 10 4 2.38 ■ 13 417 0.04 0.03 15 3 2.37 Shallow Line of Pits.Lt. Deposits. ■ 14 449 0 0.03 12 4 2.37 Lt. Deposits. ■ 15 480 0 0.02 11 3 2.37 Lt. Deposits. 16 512 0 0.02 10 2 2.39 17 544 0 0.03 14 2 2.38 Lt. Deposits. ■ 18 575 0 0.02 11 2 2.39 19 607 0 0.02 10 4 2.39 20 639 0 0.03 15 4 2.36 Shallow Pitting. Lt.Deposits. a 21 670 0 0.02 10 2 2.38 22 702 0 0.02 10 2 2.39 ■ 23 734 0.03 0.03 15 3 2.38 Shallow Pitting. Lt.Deposits. ■ 24 766 0 0.03 12 2 2.37 Lt. Deposits. 25 797 0 0.02 9 2 2.39 26 829 0 0.03 14 2 2.38 ■ 27 861 0 0.02 11 3 2.35 Lt. Deposits. ■ 28 892 0 0.03 13 3 2.35 Lt. Deposits. III 29 924 0 0.02 10 2 2.40 J 30 956 0 0.03 15 2 2.37 Shallow Pitting. Lt.Deposits. ■ 31 988 0 0.02 11 2 2.38 ■ 32 1019 0 0.03 15 4 2.37 Shallow Pitting. Lt.Deposits. ■ 33 1051 0 0.03 12 3 2.36 Lt. Deposits. ■ 34 1083 0.03 0.03 14 4 2.39 35 1115 0 0.02 3 2 2.40 36 1146 0 0.02 9 2 2.40 I] 37 1178 0 0.02 10 2 2.40li 38 1210 0 0.02 10 2 2.39 39 1242 0 0.02 3 4 2.39 40 1274 0 0.03 12 2 2.39 ■ 41 1305 0 0.03 12 2 2.39 ■ 42 1337 0 0.03 15 2 2.39 Shallow Line of Pits. 43 1369 0 0.02 3 3 2.39 44 1401 0 0.02 3 3 2.39 45 143 3 0 0.02 11 3 2.40 46 146 5 0 0.02 10 2 2.40 0 47 1496 0 0.03 12 3 2.37 Lt. Deposits. 48 1528 0 0.02 8 2 2.39 49 1560 0.04 0.04 16 3 2.39 Shallow Line of Pits. ■ 50 1591 0 0.04 16 2 2.40 Shallow Line of Pits. IPenetration Body Metal Loss Body Page 1 • • PDS Report Joint Tabulation Sheet Well: 3Q-16 Survey Date: June 15,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 2.875 in. 6.5 ppf L-80 EUE 8RD ABMOD Tubing 2.441 in. 0.217 in. 43 ft 6,915 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 51 1623 0 0.02 8 2 2.40 52 1655 0 0.02 8 2 2.40 53 1687 0 0.03 12 2 2.38 54 1718 0 0.02 8 3 2.39 55 1750 0 0.03 12 3 2.38 Lt. Deposits. 111 56 1781 0 0.02 10 2 2.39 111 56.1 1813 0 0.01 6 1 2.41 Pup 56.2 1823 0 0 0 0 2.33 BAKER SSSV 57 183 5 0 0.02 8 4 2.40 58 1866 0 0.02 9 3 2.37 Lt. Deposits. 59 1898 0 0.02 11 5 2.38 ■ 60 1930 0 0.03 . 12 2 2.41 ■ 61 1961 0 0.02 11 2 2.39 ■ 62 1993 0 0.04 17 3 2.38 Shallow Pitting. Lt.Deposits. ■ 63 202 5 0 0.03 12 3 2.39 64 2056 0 0.02 8 2 2.39 65 2088 0 0.03 12 2 2.40 ■ 66 2120 0 0.03 12 2 2.41 ■ 67 2152 0 0.02 11 4 2.40 ■ 68 2183 0 0.02 9 1 2.40 ■� 69 2215 0 0.02 10 3 2.38 Lt. Deposits. 70 2247 0 0.02 8 3 2.38 71 2278 0 0.02 9 2 2.41 72 2310 0 0.03 14 4 2.37 Lt. Deposits. ■ 73 2341 0 0.02 11 3 2.39 ■ 74 2373 0 0.03 12 2 2.37 Lt. Deposits. 75 2405 0 0.02 9 2 2.38 Lt. Deposits. 76 243 6 0 0.02 10 2 2.40 77 2468 0 0.02 11 2 2.40 ■ 78 2500 0 0.03 12 2 2.37 Lt. Deposits. 79 2532 0.04 0.02 9 2 2.40 r 80 2563 0.03 0.03 14 2 2.40 ■ 81 2595 0 0.02 11 4 2.38 • 82 262 7 0 0.02 10 1 2.38 83 2658 0 0.02 9 3 2.40 84 2690 0 0.03 15 2 2.38 Shallow Pitting. Lt.Deposits. 84.1 2722 0 0 0 0 2.38 GLM 1 (LATCH @ 11:00) 85 2728 0 , 0.03 14 4 2.39 ■ 86 2760 0 0.03 14 2 2.40 87 2792 0 0.02 8 2 2.40 88 2823 0 0.04 17 2 2.38 Shallow Line of Pits. ■ 89 2855 0 0.02 10 4 2.38 Lt. Deposits. ■ 90 2886 0 0.03 12 2 2.38 ■ 91 2918 0 0.02 11 2 2.39 92 2950 0 0.02 8 4 2.39 93 2982 0 0.02 10 2 2.40 ■ 94 3014 0 0.03 14 5 2.38 Lt. Deposits. ■ 95 3045 0 0.02 11 2 2.39 ■ 96 3077 0 0.02 11 2 2.40 ■ 97 3108 0 0.02 11 2 2.39 IPenetration Body Metal Loss Body Page 2 • • PDS Report Joint Tabulation Sheet WelE 3Q-16 Survey Date: June 15,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 2.875 in. 6.5 ppf L-80 EUE 8RD ABMOD Tubing 2.441 in. 0.217 in. 43 ft 6,915 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 98 3140 0 0.02 10 2 2.40 J 99 3172 0 0.03 12 4 2.38 ■ 100 3203 0 0.02 10 4 2.39 101 323 5 0 0.02 9 2 2.40 102 326 7 0 0.03 12 2 2.40 103 3298 0 0.02 10 3 2.39 104 3330 0 0.02 8 2 2.40 3 105 3362 0 0.03 13 4 2.38 106 3394 0 0.02 8 3 2.39 107 3425 0 0.03 12 3 2.38 ■ 108 3457 0 0.03 14 2 2.37 Lt. Deposits. ■ 109 3489 0 0.03 13 3 2.36 Lt. Deposits. 110 3520 0 0.02 10 2 2.40 111 3552 0 0.02 10 2 2.37 Lt. Deposits. 112 3583 0 0.02 10 3 2.40 113 3615 0 0.03 14 5 2.39 114 3646 0 0.02 11 2 2.38 ■ 115 3678 0 0.03 14 2 2.40 ■ 116 3710 0 0.02 10 4 2.39 ■ 117 3741 0 0.03 12 2 2.39 ■ 118 3773 0 0.03 15 3 2.38 Shallow Line of Pits.Lt. Deposits. ■ 119 3804 0 0.03 15 4 2.39 Shallow Pitting. ■ 120 383 6 0 0.03 13 2 2.40 ■ 121 3868 0.04 0.03 14 4 2.40 122 3899 0 0.02 9 2 2.39 123 3931 0 0.03 12 3 2.37 Lt. Deposits. ■ 124 3963 0 0.03 13 2 2.38 ■ 125 3994 0 0.03 14 2 2.39 ■ 126 4026 0.03 0.03 14 3 2.39 ■ 127 4057 0 0.03 15 2 2.40 Shallow Pitting. ■ 128 4089 0 0,03 15 4 2.38 Shallow Pitting. ■ 129 4120 0 0.03 14 3 , 2.39 ■ 130 4152 0 0.03 14 2 2.38 Lt. Deposits. 131 4183 0 0.02 9 3 2.38 132 4215 0 0.02 10 2 2.33 Lt. Deposits. 133 4247 0 0.02 10 3 2.40 134 4278 0 0.03 12 3 2.38 Lt. Deposits. ■ 135 4310 0 0.02 11 2 2.39 ■ 136 4342 0 0.02 11 2 2.38 ■ 137 4373 0 0.03 12 3 2.38 ■ 138 4405 0 0.03 15 2 2.37 Shallow Pitting. Lt.Deposits. 139 4437 0 0.02 9 3 2.38 Lt. Deposits. 139.1 4469 0 0 0 0 2.37 GLM 2(LATCH C, 3:30) 140 4475 0 0.02 10 2 2.38 Lt. Deposits. ■ 141 4506 0 0.03 15 2 2.38 Shallow Pitting. ■ 142 4538 0 0.03 13 3 2.38 Lt. Deposits. ■ 143 4570 0.04 0.03 16 3 2.40 Shallow Pitting. ■ 144 4601 0 0.03 15 2 2.38 Shallow Pitting. Lt.Deposits. ■ 145 4633 0 0.03 14 3 2.39 ■ 146 4665 0 0.03 14 2 2.39 IPenetration Body Metal Loss Body Page 3 • S 1110. PDS Report Joint Tabulation Sheet Well: 3Q-16 Survey Date: June 1 5,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 2.875 in. 6.5 ppf L-80 EUE 8RD ABMOD Tubing 2.441 in. 0.217 in. 43 ft 6,915 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 147 4696 0 0.02 11 3 2.39 ■ 148 4728 0 0.03 12 4 2.37 Lt. Deposits. ■ 149 4760 0 0.03 15 4 2.35 Shallow Line of Pits.Lt. Deposits. ■ 150 4791 0 0.03 14 2 2.37 Lt. Deposits. ■ 151 4823 0.04 0.03 15 4 2.39 Shallow Line of Pits. ■ 152 4854 0.04 0.03 14 2 2.37 Lt. Deposits. ■ 153 4886 0 0.02 11 2 2.37 Lt. Deposits. ■ 154 4918 0 0.03 16 5 2.37 Shallow Pitting. Lt.Deposits. ■ 155 4949 0 0.03 12 4 2.38 ■ 156 4981 0 0.02 10 3 2.38 Lt. Deposits. ■ 157 5013 0 0.03 15 2 2.38 Shallow Pitting. Lt.Deposits. ■ 158 5044 0 0.03 14 2 2.37 Lt. Deposits. 159 5076 0 0.02 10 3 2.40 ■ 160 5108 0 0.02 11 2 2.39 ■ 161 5139 0 0.02 10 2 2.39 ■ 162 5171 0 0.03 12 3 2.35 Lt. Deposits. ■ 163 5203 0 0.02 11 3 2.39 164 5234 0 0.02 9 4 2.38 Lt. Deposits. I 165 5266 0 0.03 14 3 2.38 166 5298 0 0.02 9 3 2.39111 167 5329 0 0.02 9 4 2.39 • 168 5361 0 0.02 11 2 2.39 ■ 169 5393 0 0.02 11 2 2.38 ■ 170 5424 0 0.03 12 3 2.39 ■ 171 5456 0 0.02 10 2 2.40 ■j 172 5488 0 0.03 12 5 2.37 Lt. Deposits. ■ 173 5519 0 0.03 14 2 2.37 Lt. Deposits. ■ 174 5551 0.03 0.03 15 2 2.38 Shallow Pitting. 174.1 5582 0 0 0 0 2.38 GLM 3(LATCH @ 5:00) 1 175 5589 0 0.02 10 3 2.35 Lt. Deposits. ■ 176 5621 0 0.02 10 3 2.36 Lt. Deposits. ■ 177 5652 0 0.03 13 3 2.38 . ■ 178 5684 0 0.03 14 2 2.39 ■ 179 5715 0 0.03 15 2 2.36 Shallow Pitting. Lt.Deposits. ■ 180 5747 0 0.03 12 3 2.40 ■ 181 5779 0 0.02 11 3 2.39 ■ 182 5810 0 0.03 12 2 2.38 Lt. Deposits. 183 5842 0 0.02 8 2 2.38 184 5874 0 0.03 13 2 2.40 ■ 185 590 5 0 0.03 12 2 • 2.40 ■ 186 593 7 0 0.02 11 3 2.38 Lt. Deposits. ■ 187 5968 0 0.03 , 12 3 2.39 ■ 188 6000 0 0.03 12 3 2.38 ■ 189 6032 0 0.03 15 3 2.39 Shallow Pitting. ■ 190 6063 0 0.02 11 5 2.39 ■ 191 6095 0 0.03 14 4 2.37 Lt. Deposits. ■ 192 612 7 0 0.03 14 4 2.39 192.1 6158 0 0 0 0 2.37 GLM 4(LATCH @ 10:00) 193 6165 0 0.03 15 2 2.36 Shallow Pitting. Lt.Deposits. ■ 194 6197 0 0.03 13 2 2.38 IPenetration Body Metal Loss Body Page 4 • IIII PDS Report Joint Tabulation Sheet Well: 3Q-16 Survey Date: June 15,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 2.875 in. 6.5 ppf L-80 EUE 8RD ABMOD Tubing 2.441 in. 0.217 in. 43 ft 6,915 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 195 6228 0 0.02 9 3 2.39 L 196 6260 0 0.03 12 2 2.39 197 6292 0 0.03 13 4 2.37 Lt. Deposits. 198 6323 0 0.03 12 3 2.37 Lt. Deposits. 199 6355 0 0.02 11 3 2.39 200 6387 0 0.03 13 4 2.35 Lt. Deposits. 201 6418 0 0.03 13 3 2.35 Lt. Deposits. 202 6450 0 0.03 15 3 2.36 Shallow Line of Pits.Lt. Deposits. 203 6482 0 0.02 11 3 2.37 Lt. Deposits. 203.1 6514 0 0 0 0 2.36 GLM 5(LATCH @ 4:00) 204 6520 0 0.03 12 2 2.37 Lt. Deposits. 205 6552 0 0.04 16 2 2.39 Shallow Pitting. 206 6584 0 0.03 12 3 2.38 11111 207 6616 0 0.03 12 2 2.40 208 6647 0 0.03 15 2 2.39 Shallow Pitting. 209 6679 0 0.03 13 3 2.40 210 6710 0.03 0.03 15 3 2.38 Shallow Pitting. 211 6742 0 0.03 13 3 2.38 212 6774 0 0.03 13 5 2.37 Lt. Deposits. 213 6806 0 0.03 13 4 2.39 214 6838 0.03 0.05 24 5 2.39 Isolated Pitting. 214.1 6869 0 0 0 0 2.35 GLM 6(LATCH @ 10:30) 214.2 6878 0 0.03 12 1 2.40 Pup ill 214.3 6888 0 0 0 0 2.30 CAMCO PBR 214.4 6906 0 0 0 0 2.39 CAMCO HRP PACKER IPenetration Body Metal Loss Body Page 5 S PDS Report Cross Sections Well: 3Q-16 Survey Date: June 15,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 2.875 in. 6.5 ppf L-80 EUE 8RD ABMOD Analyst: C.Waldrop Cross Section for Joint 214 at depth 6,857.140 ft. Tool speed=49 Nominal ID=2.441 Nominal OD=2.875 Remaining wall area=95% Tool deviation=28° // Finger= 19 Penetration=0.051 in. Isolated Pitting 0.05 in.=24%Wall Penetration HIGH SIDE=UP KUP INJ1111, 3Q-16 COt10CQP1illip$ ='all Well Attributes Max Angle&MD TD Alaska,Inc- '6 Wellbore APIIUWI Field Name Wellbore Status ncl TI MD(ftKB) Act Btm(ftKB) , ,,,<,,.,,rhilhp, "- 500292166700 KUPARUK RIVER UNIT INJ 29.17 5,600.00 7,300.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-16.9/1820143:35:48 PM SSSV:LOCKED OUT _ Last WO: 42.51 11/20/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ........................_..__............................ Last Tag:SLM 7,115.0 9/16/2014 Rev Reason.TAG lehallf 9/18/2014 7 II Casing Strings J�If Casing Description OD lint ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 011 CONDUCTOR 16 15.062 36.0 110.0 110.0 62.50 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread HANGER;34.0 �l)(.,. SURFACE 95/8 8.765 35.1 3,928.8 3,747.5 36.00 J-55 BTC Hr Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread F- ■■■1 PRODUCTION 7 6.276 34.7 7,277.0 6,745.0 26.00 J-55 BTC Tubing Strings '"'""'°"'""""""""""'""'"'"'"""'^'"'"'""' ' uuu.Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)I...Wt(Ihlft) Grade Top Connection YV WF `TUBING 27/8 2.441 34.0 6,936.2 6,443.1 6.50 L-80 EUEBr4ABMOD CONDUCTOR;36.0-110.0-' ' Completion Details Nominal ID I Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) 34.0 34.0 0.01 HANGER Cameron 3,5"Tbg Hgr w/3.5 9.36 J-55 PUP 8 XO 2.992 SAFETY VLV;1,822.3 Coupling ;' 1,822.3 1,755.3 23.61 SAFETY VLV Baker'FVL'Subsurface Safety valve(LOCKED OUT 2.310 1 12/16/2009) II 6,888.3 6,400.6 27.55 PBR CAMCO'OEJ'4.7500D,2.3121D 2.312 GAS LIFT,2.720.6 6,905.8 6,416.1 27.56 PACKER CAMCO'HRP'Packer pinned 56K 5.937 OD,2.347 ID 2.347 I 6,923.6 6,431.9 27.55 NIPPLE 2 7/8"CamcoAMCO'D'Landing Out Nippleub w/2.25"Profile 3.665 OD 2.250 6,935.5 6,442.4 27.54 SOS 2 7/8"Cr S 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fiSheash,etc.) Top(ND) Top Ieel Top(ftKB) (ftKB) 1") Des Com Run Date ID(In) SURFACE;36.1-3,928.e 7,186.0 6,664.5 27.76 Fish 1 1/2"DMY Lost in Rathole 2/22/1987 2/22/1987 Perforations&Slots GAS LIFT;4.467.6 is a Shot Dens Top(ND) Btm(TVD) (shots Top(ftKB) Btm(fin) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT;6,582.0 1. 6,985.0 6,993.0 6,486.3 6,493.4 A-3,3Q-16 10/1/2000 4.0 APERF 2-1/8"Enerjet;0 deg phasing. 6,993.0 6,995.0 6,493.4 6,495.2 A-3,3Q-16 10/1/2000 4.0 RPERF 2-1/8"Enerjet;0 deg GAS LIFT;6,158.4 phasing. 6,993.0 6,994.0 6,493.4 6,494.3 A-3,3q-16 3)1/1987 4.0 IPERF 2-1/8"Enerjet;0 deg phasing. 7,002.0 7,012.0 6,501.4 6,510.3 A-2,3Q-16 10/1/2000 4.0 APERF 2-1/8"Enerjet;0 deg • GAS LIFT;6,514.1 phasing. 7,012.0 7,017.0 6,510.3 6,514.7 A-2,3Q-16 10/1/2000 4.0 APERF 2-1/8"Enerjet;0 deg phasing. GAS LIFT;6,869.2 I 7,012.0 7,013.0 6,510.3 6,511.2 A-2,3Q-16 10/1/2000 4.0 RPERF 2-1/8"Enerjet;0 deg phasing. 7,012.0 7,013.0 6,510.3 6,511.2 A-2,30-16 3/1/1987 4.0 IPERF 2-1/8"Enerjet;0 deg phasing. PM;6,668.3 ;01.11 7,028.0- 7,048.0 6,524.5 6,542.2 A-1,3Q-16 9/30/2000 4.0 APERF 2-1/8"Enerjet;0 deg PACKER,6905.8phasing. 7,048.0 7,052.0 6,542.2 6,545.8 A-1,3Q-16 9/30/2000 4.0 RPERF 2-1/8"Enerjet;0 deg phasing. NIPPLE;6,923.6 7,048.0 7,052.0 6,542.2 6,545.8 A-i,30-16 3/1/1987 4.0 (PERF 2-118"Enerjet;0 deg phasing. 7,052.0' 7,058.0 6,545.8 6,551.1 A-1,3Q-16 9/30/2000 4.0 APERF 2-1/8"Enerjet;0 deg .._..., phasing. Mandrel Inserts St atl on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (RKB) Make Model OD(in) Sem Type Type (in) (psi) Run Date Com fi 2,720.6 2,579.0 Merle BK-2 1 GAS LIFT DMY BK 0.000 0.0 6/14/1998 2 4,467.6 4,263.1 Marla BK-2 1 GAS LIFT DMY BK 0.000 0.0 6/4/1988 APERF;6,985.0-6,993.0-, - 3 5,582.0 5,246.1 Merla BK-2 1 GAS LIFT DMY BK-2 0.000 0.0 1/14/1987 (PERF;6,993.0-6,994.0 4 6,158.4 5,754.0 Marla BK-2 1 GAS LIFT DMY BK 0.000 0.0 6/4/1988 RPERF;6,9930-6,995.0 5 6,514.1 6,068.7 Merla BK-2 1 GAS LIFT DMY BK-2 0.000 0.0 1/14/1987 - 6 6,869.2 6,383.7 OTIS LB 1 1/2 GAS LIFT DMY RM 0.000 0.0 12/4/2013 - Notes:General&Safety End Date Annotation 1/2/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 APERF;7,002.0-7,012.0--.--. - IPERF;7,012.0.7,013.0 ie.. 1/29/2014 NOTE:WAIVERED 7 x IA COMMUNICATION,WATER INJECTION ONLY RPERF;7,012.0-7,013.0 APERF;7,012.0.7,017.0 .-- APERF;7.028.0.7,048.0 IPERF;7,048.0.7,052.0 ^- RPERF;7,048.0-7,062.0 - - APERF;7,052.0-7,058.0-- Fish;7.1860.----41 PRODUCTION;34.7-7,277.0 -.SING / TUBING I LINER r tea. DRIL. .E 3c`i? _-- ARCO Alaska, Inca • DATE - ��1 ----- Subsidiary 01 AnantIcRichflsldCompany Page - 01 1 -pages #ITEMS COMPLETE DISCRIPTION OF EQUIPMENT RUN LENGTH DEPTH 14 ro DoYoM 341, 00 CRm�R 3kz'Tp,G 9,34-r 5s Pu+P 4 x o 7?l_I r3 G '/,/ 38, 141 _T 54 res F2 116,5t4.-80 4.6 MoD eue 8' ,° r-irt.tBING " 177'/,1 ^ /8 /Z.yZy 2V "'6,5' 4.48o P0,0 77~ /0.// /8,z ,95 BK +Q `FVL' Sk3 SuRPACw S4FF77VACV. 2 ig° 51 33,94/ zarTs zYSr� 5**rw®/Ne.; daoec� - -._ 886,64 _2-r o,6,a Z4 s 1"efri6q‘ 1-,A) pumn)y A34-2, 4,fredi. 6,79 2727, 39 55 rrs 2 • 4,a*a r'yi3i1t c Certs -9,63.01/5) - _ 174/0, 26, #47,6.5 2'/x/ .mi��A 64.01 wj pommy -__ G r75 4N7Y,V0 .36 v-rs 23* 6,5"*` res,E3tv'G 69:1 4Bo✓6� 1/07,63 6532 /03 2'/8 n/ 'C'17 .-let-,4 41-m "/ D urni»r - - --_ 612 65 ,1 ,79 /f rrs .2W 615*rti4/NG (1-5 /Move � 549,62. 4158,1 z4 x/" Rl.,4Ca/ r' w/ Dtimmy e.0, 8! 6.14.5. 2-a I/ rrs 24'6,5 it rif4/NG 6.1_5 yo v 3418, /69 _ec_5mi /! ,z74'/x/I/ma/ 6 4.01 C0,60 4 5 b.19 J ll rr's 2 6.5' 7"4?B/N6. s 41301*--) _ - 98&3-5 8 Q, 2 G 2'/8 / "orfs cLK wf L%. CNA,CK T_2 t-Arai#_ q, 00 6,874, 2C - Z7/$ 6,5#48D 6RD Re MOD, Pi-bp J`7 /4,42 ‘8.6t28 C4inco ' 04 J" -- 7.x-0 op ,2..., / � /7,5 - � 4'9 ,8 _-_ -- C 9mc 0 s /R f Pel E KG-R 14/4(,_ of s 4_< !'9,17 QP .jta W., _27,7 t9 G g1 e_5 X81 L.-$0 6,54°. 146 8120?l+P Trr /0A Z4 CAr,cv LANDAIG AoppLe 44/ ,z.5 PRopii,.a3"�,asr /,8y . Z 5.4l7 27431.14, 6**c 4;8 no PUT? T� l - /D, 4"6 f. 3 5,53 C#?n76v 5N i92 otir scab .Cool rtathva r4/ C'm _._ G9 34, 22. BOTTOM OF TUBING TAIL Remarks RA4 a r 214 -r-s T_ti_i Mig. 2'/L vo 3 _- _-- VSD rA 8 moD Dope s per i -.L-1ss fl 312-5_L U .,A gest. WW1>.S � _ . .- - ACO PM 118 ,.Ib_ Supervisor i/ / 1 II • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: J Begg / DATE: Monday,August 08,2016 P.I.Supervisor {`� v 1 I i/, SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-16 FROM: Bob Noble KUPARUK RIV UNIT 3Q-16 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ,_W--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-16 API Well Number 50-029-21667-00-00 Inspector Name: Bob Noble Permit Number: 186-179-0 Inspection Date: 8/2/2016 Insp Num: mitRCN160804105318 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3Q-16 Type Inj W' TVD 6422 . Tubing 2900 2900 . ! 2900. ' 2900 - PTD 1861790 Type Test SPT Test psi 3000 , IA 1040 3600 - 3520 . 3500 - Interval P/F P '' OA 260 l REQVAR 460 460 1 460. . Notes: MIT-IA per 2B..082 per max anticipated injection pressure. Monday,August 08,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I la, DATE: Wednesday,January 06,2016 �� 1 '� SUBJECT: Mechanical Integrity Tests P.I.Supervisor �� ��� � CONOCOPHILLIPS ALASKA INC 3Q-16 FROM: Bob Noble KUPARUK RIV UNIT 3Q-16 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv (�- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-16 API Well Number 50-029-21667-00-00 Inspector Name: Bob Noble Permit Number: 186-179-0 Inspection Date: 1/2/2016 Insp Num: mitRCN160103161855 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min I 3Q-16 . Type Inj W 1TVD 6422 - Tubing r 2827 2827 - 2827 - 2827 - r Well� _ PTD 1861790 - JType Testi SPT Test psi 3000 IA 460 3450= 3360 - 3340 - Interval 1REQVAR P/F P OA 200 295 - 295 - 295 - I Notes: MITIA per AIO 2B-082 to maximum anticipated injection pressure of 3000 lbs. SCANNED r; Wednesday,January 06,2016 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. I ~ ~- J_ r~OL Well History File Identifier RESCAN Color items: [] Grayscale items: [] Poor Quality Originals: ,o,^, P^GES: ~"~ ORGANIZEDBY:~"BEVERLY.~REN VINCENT SHERYL MAR~ Project Proofing DIGITAL DATA [] Diskettes, No. [] Other, No/Type LOWELL OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DATE: /0"' ~'0~'"'" ,$, ~ By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si PAGES: ~ O (atthe time of scanning) SCANNED BY'. BEVERLY BREN VINCE~ARIA LOWELL DATE: /~7~/ ReScanned (done) RESCANNED BY; BEVERLY E~REN VINCENT SHERYL MARIA LOWELL DATE: tsl General Notes or Comments about this file: PAGES: Quality Checked (done) Rev1 NOTScanned,v4x:l Wallace, Chris D (DOA) From: Wallace, Chris D(DOA) Sent: Thursday, October 10, 2013 3:28 PM To: 'NSK Problem Well Supv'; Regg, James B (DOA) Cc: Dethlefs, Jerry C Subject: RE: KRU witnessed MITIA's Proceed with the change out of the IA fluid. 30 days water only injection approved for additional diagnostics and monitoring. I see our records reflect the failed tests(Lou Grimaldi) of 8/23/2013, and the passing MITIA of Bob Noble 8/25/2013 to test pressure 3186 psi. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue s�.ANN �.i Anchorage,AK 99501 !•� (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Sunday, September 15, 2013 8:57 PM To: Regg,James B (DOA); Wallace, Chris D (DOA) Cc: Dethlefs, Jerry C Subject: RE: KRU witnessed MMA's Chris,Jim CPAI proposes to circulate out 30-16's(PTD 186-179) inner annulus fluid with fresh fluid (corrosion-inhibited brine with a diesel cap for freeze protection). This is being proposed in order to circulate out any residual gas entrainment,which is suspected to have migrated into the annulus while the well was on MI injection. After the well is circulated,we request permission to resume water injection,for 30 days,to continue the diagnostic monitoring in preparation for submittal of an AA for water only injection. After the well is stabilized,a witnessed MITIA would be performed with maximum injection pressure set for the test pressure, in anticipation of the AA requirements. As directed per the attached email, 30-16 was shut in on August 29, 2013. Since that time,the IA pressure has not shown evidence of repressurization. (See the attached 90 day TIO plot). Please let me know if you have questions. Brent Rogers I Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager(907)659-7000 pgr 909 1 From: Regg, James B (DOA) [mailto:jim.regg@)alaska.gov] Sent: Wednesday, August 28, 2013 4:50 PM To: NSK Problem Well Supv Cc: Brooks, Phoebe L(DOA); Wallace, Chris D (DOA) Subject: [EXTERNAL]RE: KRU witnessed M1TIA's 3Q-08A(PTD 1971930)MIT 8/23/13 - 10-404 (sundry rpt) dated 7/29/2002 indicates well has"no packer" - MIT dated 8/8/2004 indicates packer at 6468 ft TVD - MIT dated 9/25/2008 indicates packer at 5388 ft TVD - MIT due 9/2012 was apparently deferred since well SI from March 2012 until (?) - How do you perform an MITIA without a packer? If there is a packer, paperwork needs to be updated. - Perhaps you have a better well schematic than what is in our well records(rec'd with 2002 sundry rpt) 3Q-16(PTD 1861790) MITs 8/23/13 and 8/25/13 - Well is a WAG'd (last injection was MI); shut in November 2012;AOGCC authorized (via email 8/9/13) up to 60days injection to evaluate well for continued water injection (to perform diagnostics for Admin Approval application) - Inspector rpt attached; comment about gas (rich smell) in IA appearing each t i me after e r bleed i n g IA pressure. I have changed test result on Inspector's report to "Fail"—there is evidence of loss of mechanical integrity or possibly lack of confinement of injected fluids - Unclear why 8/25/13 retest was performed to 3400psi and wonder if MIT would pass if tested to 1750psi (required test was 1600 psi) or the max anticipated water injection pressure; as shown the retest on 8/25/13 indicates a pressure loss of 214 psi (175psi first 15 min; 39psi 2"d 15 min) - This well is currently under enforcement proceedings (reconsideration hearing scheduled for 9/11/13); unless you can show there are additional diagnostics to be performed, 3Q-16 should be shut in until enforcement decision and mechanical integrity concerns are resolved to AOGCC's satisfaction Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n16170conocophillips.com] Sent: Monday, August 26, 2013 8:27 PM To: Wallace, Chris D (DOA); Brooks, Phoebe L(DOA); Regg, James B(DOA); DOA AOGCC Prudhoe Bay Cc: Dethlefs, Jerry C Subject: KRU witnessed M1TIA's Please find the attached forms for recently performed MIT's at KRU. Please let me know if you have any questions. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 Pager(907)659-7000 pgr. 909 2 . • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,August 29,2013 TO: Jim Regg P.I.Supervisor TP elq. Z4 (13 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-16 FROM: Lou Grimaldi KUPARUK RIV UNIT 3Q-16 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry g- NON-CONFIDENT1AL Comm Well Name KUPARUK RIV UNIT 3Q-16 API Well Number 50-029-21667-00-00 Inspector Name: Lou Grimaldi Permit Number: 186-179-0 Inspection Date: 8/23/2013 Insp Num: mitLG130825173505 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well, 3Q-16 . Type Ind f W TVD 1 6422 - 1 IA 1 1508 3390 3249 • 11 3205 3180 Type Test a PTD 1861790 ' SPT Test psi 1606 - OA 479 817 • 772 741 717 YP - I Interval OTHER P/j+ I F ✓ .Tubing 2678 - 2630 2599 2595 2594 l MIT for AA request.Large amounts of gas(rich smell)in IA. g Notes: 9 g g � � )� Bled twice to fluid with gas appearing again both times.I consider this a"No Test"as there was too much gas in the annulus to perform valid test.CPAI rep tested well with this understanding.Above readings were after pumping 9 bbl's of diesel to bring to pressure noted.Afterwards IA was bled to production so return volume was not obtained.Suggest leaving IA open to atmospheric bleed system to allow MI to"cook off'.Per J.Regg-test determined to be a"Fail". 'T--Z P SSI,/k,,e s P 0 ',e,( scow DEC 3. 0 2.313 Thursday,August 29,2013 Page 1 of 1 S • dweijamoq o o o co 0 .r_ P .1. lo c\1 LO 1- Co N— I..r) I V\ .11 {'•"- rit ,! i41 / i1 / 111 ,11) iic...., n , 0 _ tc ' '''' , ---------7.-- ,-- t 'N • CN.1 • . 01 . ..-...:-..ta...,..:L..... . ,,,,,......,..----=...........-•- • . . .-‘,----.—.. -- CD .... • . : .,'. ■ = - . . < • . . '`.. • t a . 00 . • • . -- -° - ' ' • . --- -4-- . • • .-• • • . •, , 1 • .-- c--. • . ,.. . • . . . • . • (,,,,,: .2 co . . . . ' Ce) . . CO - • . 9r- ,t• • • I i c5 - ' • I . • • 1 - • • • • . co , . 1 ; . • N.-- 0 4., - • • CU 0 . . . ' . • CO 0 . • • N-• 0. . • . . i • ' 0 - • • . • • —) . . . • • • li— • . • . . . co . • . . . . : . . . • ' . . . . . = . . . ") . . . 1,1... • • • • • . N- • . • • " • . . , • . . • 1 : • CO . . •t"— • . • . . . • ■ . • = CL a. • - -, i--- < - . . i • • ; . . • • 0,, ' . • • • • i • • LL1 r r I, r r r i i l l 1 t t i l l I I I co ..Q 0 F_ CI- = F- < 0 0 0 0 ci 0 0 CNI 1 I ISd 1 ...„ o_ . c,5-....) --- • MEMORANDUM 0 State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,August 29,2013 TO: Jim Regg ----7‘ Mechanical Integrity Tests P.I.Supervisor ���` i (Z4 I t CONOCOPHILLIPS ALASKA INC 3Q-16 FROM: Bob Noble KUPARUK R1V UNIT 3Q-16 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvJ --- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-16 API Well Number 50-029-21667-00-00 Inspector Name: Bob Noble Permit Number: 186-179-0 Inspection Date: 8/25/2013 Insp Num: mitRCN130826135403 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min yp J . - 3Q 16 IA i 986 3400 3225 1 3186 Well 1861790 Type In sPT I:TVDp 1606 i w , 6422 OA g 400 640 630 620 1 OTHER 1 — t PTD Type Test 'Test st Interval P/F P v Tubin I 2650 ' 2675 2675 1 2675 ■ Notes: AA Prep.Fluid level was shot before test and it was down 30'.5.1 bbl were pumped to pressure IA up. c IA s; -k*Q Qxe Sr, 4,sr oiwi j 4'-st C )75---p5; i-r i5 A-1ptu () scow DEC 10 2U13 Thursday,August 29,2013 Page 1 of 1 • A OF 7.4, • y . ,, . �j, THE STATE Alaska Oil and Gas ��, it '� O f Conservation Commission , its =_ L A s KA GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF r R Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 January 16, 2013 Jerry Dethlefs Well Integrity Director SCANNED 201 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Notice of Proposed Enforcement Action Failure to complete a Mechanical Integrity Test (MIT) Failure to report to AOGCC a pressure communication Kuparuk River Unit 3Q -16 (KRU 3Q -16) (PTD 1861790) Request for Informal Review Dear Mr. Dethlefs: On December 21, 2012 the Alaska Oil and Gas Conservation Commission (AOGCC) notified ConocoPhillips Alaska, Inc. (CPAI) of a Notice of Proposed Enforcement Action. CPAI responded on January 14, 2013 requesting an informal review under 20 AAC 25.535 (c). The informal review meeting is scheduled for January 30, 2013 at 9:00 a.m. in the AOGCC's Anchorage office at 333 West 7 Avenue. As part of the informal review process, the AOGCC is providing CPAI an opportunity to submit documentary material and make written and oral statements regarding failure to complete a Mechanical Integrity Test (MIT) and failure to report to AOGCC a pressure communication for KRU 3Q -16. Copies of all written submissions and a summary of any oral statements planned by CPAI should be provided to the AOGCC no later than January 24, 2013 so we can make best use of the informal review. Sincerely, Cathy P. oerster Chair, Commissioner ~J COI'10C ~ ~ ~ oPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 ~ . ~'~~` Mr. Tom Maunder ~ („ Alaska Oil & Gas Commission ~ ~`~ 333 West 7~' Avenue, Suite 100 '' ~~ Anchora e AK 99501 ~ ~ g , ,, ~~~~s~~~ ., :a : ~~.. v .~. ~ ~ .: . . . ~ . haMS~.:" ~. Dear Mr. 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. These voids were filled with cement if needed and corrosion inhibitor, 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 treatrnents took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30th 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9~' and 10~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~G~ MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ ~ •~ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field DBte 08/11/09 ~r_ ~u air 4_ ~n o.,,~ Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top o date Corrosion inhibitor Corrosion inhibitod sealant date bbls al 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" n/a 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n!a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8/2009 3H-10B 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" . n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF n/a 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8/8/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 50029216770000 1861890 7" n/a 7" n/a 2.97 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'5" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7/30/2009 8.5 8/8/2009 MEMORANDUM To: Jim Regg ~ P.I. Supervisor ~~~~/~'/ ~d11 (~~ FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 01, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-16 KUPARIJK RIV UNIT 3Q-16 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~~2- Comm Well Name: KUPARUK RN UNIT 3Q-16 API Well Number: 50-029-21667-00-00 Inspector Name: Bob Noble IIISp Num' mitRCN080927184733 Permit Number: 186-179- 0 / Inspection Date: 9i25izoo8 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 3Q-16 Type Inj. G ~ TVD 6423 ' I IA ~ 1800 i 2540 c 2520 2520 P.T. 1s6179o 'TypeTest SPT ~ Test psi zsao ;/ OA zo zo zo i zo ~ Interval 4YRTST p~F P ~ TUbing 3440 3440 3440 3440 Notes: Wednesday, October Ol, 2008 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: JimRegg Ð l I P.I. Supervisor f'.,~1 <.ì 7A 0+ DATE: Wednesday, August 11,2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-16 KUPARUK RIV UNIT 3Q-16 FROM: JCr Petroleum Inspector Sre: Inspector Reviewed By:~ P.I. Suprv -..J BIz- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3Q-I6 API Well Number: 50-029-21667-00-00 Inspector Name: JCr Insp Num: mitJCrO40810 182715 Permit Number: 186-179-0 Inspection Date: 8/8/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Q-16 Type Inj. S TVD 6764 IA 750 2960 2800 2770 P.T. 1861790 TypeTest SPT Test psi 1605.75 OA 0 0 0 0 Interval 4YRTST P/F P Tubing 1850 1850 1850 1850 Notes: Wednesday, August 11, 2004 Pagel of 1 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) Phillips Alaska, Inc. Development__ RKB 60 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service__x Kuparuk Unit 4. Location of well at surface 8. Well number 2300' FNL, 1964' FEL, Sec. 17, T13N, R9E, UM (asp's 516372, 6025772) 3Q-16 At top of productive interval 9. Permit number / approval number 1269' FSL, 324' FEL, Sec. 17, T13N, R9E, UM 186-179/ `At effective depth 10. APl number 50-029-21667 ,At total depth 11. Field / Pool 4127' FNL, 229' FEL, Sec. 17, T13N, R9E, UM (asp's 518117, 6023948) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7300 feet Plugs (measured) true vertical 6765 feet Effective depth: measured feet Junk (measured) true vertical Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 110' 16" 18754f Po~eset 110' 110' SUR. CASING 3869' 9-5/8" 1200 sxAS III & 250 sx Class G 3929' 3748' PROD. CASING 7217' 7" 300 sx Class G & 175 sx AS I 7277' 6745' Perforation depth: measured.~.-~_-.~i._~i~!.~..~~ ........................................................................... R E i:~:E:i:?!:i:!:!:!:!:i:~:~:~:i:!:!:~:f:!:i:!:!:i:!:i:!:E:E:!:i:!:i:!:{:i:!:i:E:i:!:i:i !:!:::~:i'!:!:!:i:~:i:i:!:~:!:!:i:?i:!:!:!:i.! {:i:i:i:i:}:i:i:!:i:i:i:i:i:i:~ i:!:!:! ::::::::::::::::::::: i! ~:f:!:i'!': i::'i:i:!.i?! i !:i:i ::i': f:'~ :!:i i:i:!?i ::i, ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: i:?i:!:i:!:!'!:!:?i:i:!: ;:i:i:!:!: E:!:i:;:i: i:!:i: ;::i: ;:: i: }:i:::: ::::::::::::::::::::::::::: :: ::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~:::::::::::: ::::::::::::::::::::::::::::::: :::::5 ::::::::::::::::::::::: :::':::':: ::' :.: .:': ::::: ' :':::'::: :;>:: :7:: L: ,.] hN Tubing (size, grade, and measured depth) Anchorage Packers & SSSV (type & measured depth) :-:-:-:-:': :' ':-- - :-:-: ::: -:-:':-:-:- -:' -:';-;';; :-i-~ :-:-: :-:-:-:' ':; ;-;-;-;; :':': :':::::: ;'~-:':':':-;':':-: :':';: :':::: :':: :': :':':':-: :':':'; ;';';-;' ';; ' ;';';';,;: :'.':::: :':: :: :':::::: :': - :': :':: :': · 7:::: : : :. :.: :.: : ..:.: :: 13. Stimulation or cement squeeze summary Intervals treated (measured) ::::: ::':: :.:::::;:::: :::'::: :::': ::: '::: :::::::: '.: '.:'::: :.::: :': ::': ':' :.': ::::':: ': :' :': :: ':' ::::: :' :.: ::' :'(' :' :" :' Treatment description including volumes used and final pressure :iii: i:i:ii:ii::i?::!: !-!!i:~:!:::i:' ~::i!:¥ ~:i !??::!::-!::.i:¥~::i:i :.!::!: !.: :::i'!::i: ::.:.:.: ;;;:;.:. :;::::.: :;: :: :..:..:::;:. :;:;.:. ;. ;. ;.: :. ::.:: ;..:. :.. :. :. :.:..;;;. :. :. ;. ;. :. ;. :. :..: ...:.. ::.:...;:.;.:;.::.;:::...- -.. 14. Representative Daily Avera.qe Production or Injection Data OibBbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure ...................... :_: ........ :_ :-..::.... ..... :.::.::.: ........ :_:.:.:.....:..:.:.;:.::. :.::.:.:.:.:.:.:.:.:...:. :.:..::..:. :. :. :.::.: ...::.....:... ......... :....:............:. :......:..:..... :<:<:.: .: .:. Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X !ii i~il i!i~i~ii!!ili! il i i il !:ii~ il i~ !i i: ii! :~-~~ ? ii!I :::' !i:: :'~'~i~ .i::X.::W~il :::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::: ::-:i:::!=============================== ::!:':: - ::-:: - ~'::: :' ::: :'; :::' :! :' :' ::'::: ':': ::' :.'~-:::: :':': :' :-' ::'.: ::; :" ::': :: ::" :."::':: · ::;': -':::::" :::::::.:::::-:: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Cai~Jeff Spencer659-7226 Signed cer~~, 4,,.~~,./,I,-~_~~ Title P+eduction Engineering Supervisor Date Jeff A. Spen Prepared by Robert Christensen 659-7,5,35 ?B.n s BFL Form 10-404 Rev 06/15/88 o R tGIN A L SUBMIT IN DUPLICATE 3Q-16 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pedorate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2301' FNL, 1965' FEL, Sec.17, T13N, R9E, UM At top of productive interval 1269' FSL, 324' FEL, Sec.17, T13N, R9E, UM At effective depth At total depth 1152' FSL, 222' FEL, Sec.17, T13N, R9E, UM 5. Type of Well: Development __ Exploratory__ Stratigraphic__ Service__X (asp's 516370, 6025773) (asp's 518020, 6024067) (asp's 518122, 6023951) 6. Datum elevation (DF or KB feet) RKB 60 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3Q-16i 9. Permit number / approval number 186-179 10. APl number 50-029-21667 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 1 10' SURF CASING 3869' PROD CASING 7217' 7300 feet Plugs (measured) 6765 feet 7178 feet Junk (measured) 6657 feet Size Cemented 16" 1875# Poleset 9~5/8" 1200 Sx AS III 8, 250 G 7" 300 Sx CIG & 175 AS I Tagged PBTD (9/15/00) @ 7178' MD. Measured Depth True vertical Depth 110' 110' 3929' 3748' 7277' 6745' Perforation depth: measured 6985 - 6995'; 7002 - 7017'; 7028 - 7058' true vertical 6486 - 6495'; 6501 - 6515'; 6524 - 6551' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 2.875", 6.5#, L-80, Tubing @ 6937' MD. Camco 'HRP' Packer @ 6914' MD. Baker 'FVL' @ 1834' MD. RECEIVED MAR 2 7 2001 Alaska Oil & I~as Cons. Commissior~ Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl - Representative Daily Average Productionorlnjection Data Gas-Mcr Water-Bbl 2400 2400 Casing Pressure Tubing Pressure - 2750 275O 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __ Gas __ Suspended __ Service __.(WAG)__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~ .~~,f.~ Title: Form 10-404 Rev 06/15/88 · Prepared by John Peirce 26~6471 SUBMIT IN DUPLICATE 3Q-16i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 9/15/00: RIH & tagged PBTD @ 7178" MD. 9/30/00: MIRU & PT equipment. Added perforations: Reperforated: RIH w/perforating guns & shot 30' of perforations as follows: 7O28 - 7O48' MD 7052 - 7058' MD 7O48 - 7O52' MD Used 2-1/8" carriers & shot the perfs at 4 spf. POOH w/guns. Rigged down. 10/1/00: MIRU & PT equipment. Added perforations: RIH w/perforating guns & shot 30' of perforations as follows: 6985- 6993' MD 7002- 7017' MD Reperforated: 6993 - 6995 MD Used 2-1/8" carriers & shot the perfs at 4 spf. POOH w/guns. Rigged down. Returned the well to water injection and obtained a valid injection rate. MEMORANDUM TO' THRU: Julie Huesser, Commissioner Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission / DATE: December 1, 2000 FROM: SUBJECT: Chuck Scheve; :Petroleum InspeCtor Safety Valve Tests Kuparuk River Unit 3Q Pad : : Fridayl December 1, 2000: I traveled to 3Q Pad in the Kuparuk River Field and witnessed the safety valve system testing~on 4 miscellaneous WAG injectors. As the attached AOGCC Safety Valve sYstem Test Report indicates I witnessed the testing of 4 wells and 8 compOnents with one failure observed. The pilot on well 3Q- 21, which had just been brought line and was not fully up to operating temp, tripped well below the required triP pressure. This pilot was retested upon completion of today's testing and operated properly. Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with Summary: I witnessed the SVS testing of 4 WAG injectors at 3Q Pad in the Kuparuk RiVer Field. KRU 3Q Pad, 4 wells, 8 components, 1 failure Attachment: SVS KRU 3Q Pad 12-1-00 CS X UnclasSified Confidential (Unclassified if doc. Removed) SVS KRU 3Q Pad 12-1-00 CS.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips SUbmitted By: Chuck Scheve Date: 12/1/00 Operator Rep: Ernie Bamdt Field/Unit/Pad: Kupamk / KRU / 3Q Pad AOGCC Rep: Chuck Scheve Separator psi: LPS HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number NUmber PSI PSI TriP Code Code Code Passed GAS or CYCLE 3Q-01 1911250 3Q-02 1870040 3700 2000 1750 P P WAG 3Q-03 1911260 3Q-04 1911240 3Q-06 1861950 3Q-07 1861940 · 3Q-08A 1971930 3Q-09 1861860 ' 3Q-10 1861870 3Q-11 1861880 3Q-12 1861890 3700 2000 1900 P P WAG 3Q,14 1861770 3Q-22 1951860 3Q-16 1861790 3700 2000 2000 P P WAG 3Q-21 1951930 3700 2000 1200 3 P 12/1/00 WAG Wells: 4 comPonents: 8 Failures: 1 Failure Rate: [] 9o var Remarks: Misc tests on Wag wells 12/4/00 Page 1 of 1 SVS KRU 3Q Pad 12-1-00 CS.xls MICROFILMED 9/28/OO DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~uSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other ~ 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage~ AK 99510-0360 4. Location of well at surface 2301' FNL, 1965' FEL Sec. 17 T13N R9E UM At top of productive interval ' ' ' ' 1269' FSL, 324' FEL, Sec. 17, T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 60 6. Unit or Property name Kuparuk River Unit 7. Well number 3Q-16 i~u .~ ~;-,~- 8. Approval number #8-30 At effective depth 1191' FSL, 256' At total depth 1152' FSL, 222' FEL, Sec. 17, 11. Present well condition summary Total depth: measured 7300' true vertical 6764' FEL, Sec. 17, T13N, R9E, UM T13N, R9E, UM 9. APl number 5o- 029-21667 10. Pool Kuparuk River Oil Pool MD feet TVD feet Plugs (measured) None Feet Effective depth: measured 7189 ' true vertical 6669' Casing Length Structural 80' Conductor Surface 3894' Production 7242' xxL~Arxx X XX X PeFfoFation depth: measured MD feet Junk (measured) None feet TVD Size Cemented Measured depth i6" 1875 # Poleset 110' MD 9-5/8" 1200 SX ASIII & 3929' MD 250 SX Class G 7" 300 SX Class G 7277' MD & 175 SX AS I 6993', 7012', 7048'-7052' MD ~ue Vertical depth 110' TVD 3747' TVD 6744' TVD true vertical 6492', 6509' , 6541'-6545' TVD Tubing (size, grade and measured depth) 2.875", L-80, tubing w/tail @ 6936' kid Packers and SSSV (type and measured depth) HRP packer 0 6914' MD & FVL SS.qV fa lg34' Mil 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 350 120 0 1200 140 Subsequent to operation 0 0 2000 800 1500 14. Attachments Converted from oil producer to water injector on 6/6/88. Daily Report of Well Operations Q~ Copies of Logs and Surveys Run / 15. I hereby certify that the foregoing is true and correct to the best of my knowledge V~,,,,~!.. Signed Form 10-40~4 Rev. 12~-85 Title Sr. Operations Engineer Date ,., Submit in Dupl~a~,,,_ ARCOAiaska, Inc '~ Subsidiary of Atlantic Richfield Company WELL SERVICE REPOR'I WELL CONTRACTOR , ~E. MARKS OPERATION AT REPORT TIME .,~ ~ [-~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Report Temp. °F Chill Factor0FIvisibility miles I Wind Vel. OIL AI~ GAS OOH~£.VATIt]g FEIZ{{ANICA1. t~lLl *S --- ~ 1,m Siz£/t~r/¢~ $1E 1¥:~? CfC { { lg ~-I~ ~ ,'~.~~ ~ ~~ ~-~ ~' ~,~. ~~ ~,~ ~~...~,~. .... ~~ ..... ~ .. ..~ ..... ..... _ ...... _ _ - - .... , , ...... ; ~ i . ..... ....... . ~, i , ,~ , ~ . ...... - . , - ~- - .. , , ,, .~ ....... . .... , .............................................. STATE OF ALASKA ALAS. . OIL AND GAS CONSERVATION COM~..,JSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing Fi Amend order [] Perforate © Other 99510 2. Name of Operator ARCO Alaska, Inc 5. Datum elevation (DF or KB) RKB 60 feet 6. Unit or Property name K~lDar~lk River [init , 7. Well number 3Q-16 8. Permit number Permit #86-179 9. APl number 50-- 029-21667 10. Pool I<~Jnar~ll< River fl!l Pool ! Plugs (measured)None 3. Address PO Box 100360, Anchorage.. AK 4. Location of well at surface 2301' FNL. 1965' FEL Sec. 17 T13N, R9E tiM At top of productive interval' ' ' 1269' FSL, 324' FEL, Sec. 17, T13N, R9E, UN At effective depth 1191' FSL, 256' FEL, Sec. 17, T13N, R9E, UM At total depth 1152' FSL, 222' FEL, Sec. 17. T13N, 11. Present well condition summary Total depth: measured 7300' MD feet true vertical 6764' TVD feet Junk (measured) None Effective depth: measured 7189' MD feet true vertical feet 6669' TVD Length Size Cemented Measured depth 80' 3894' 7242' 16" 1875 # Poleset 110' MD 9-5/8" 1200 SX ASIII & 3929' MD 250 SX Class G 7" 300 SX Class G 7277' MD & 175 SX AS I 6993', 7012', 7048'-7052' MD measured Casing Structural Conductor Surface X X X J4~ ~A'qX(XcJ~C~t e Production xxx krk xxxx Perforation depth: ~ue Vertical depth 110' TVD 3747' TVD 6744' TVD true vertical6492, 6509' 6541'-6545' TVD BOP sketch Tubing (size, grade and measured depth) 2.875", L-80, tubing w/tail ¢ 6936' MD Packers and SSSV (type and measured depth) HRP par. k~r fa 6c)~4' fv!D &_ FVL SSSV ~ !834' MD 12.Attachments Description summary of proposal [] Convert to water injection. 13. Estimated date for commencing operation January 15, 1988 Detailed operations program Date approved 14. If proposal was verbally approved Name of approver Date12/22/87 15. I hereby cortify that the foreg,~ing is true and correct to the best of my knowledge ./J¢(~¢,. .~,,,,~¢_/...,.._.~.~.~ Title Sr. Operations Engineer Signed Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by Form 10-403 Rev 12-1-85 \/ ORIGINAL SIGNED BY I tlNNIIE C. SMITH ___ ..,pproved Copy Returned .... by order of Commissioner the commission Date Submit in triplicate STATE:OF ALASKA ALASKA OIL AND GAS CONSERVATION C~JMMISSION ~/ WELL COMPLETION OR RECOMPL'ETION REPORT AND LOG Form 10-407 WC2: :W :DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO A]aska, Inc. 86-179 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-21667 4. Location of well at surface 9. Unit or Lease Name 2301' FNL, 1965' FEL, Sec.17, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1269' FSL, 324' FEL, Sec.17, T13N, R9E, UM 3Q-16 At Total Depth 11. Field and Pool 1152' FSL, 222' FEL, Sec.17, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool RKB 60'I ADL 25512 ALK 2553 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 1,5. Water Depth, if offshore 16. No. of Completions 11/13/86 11/19/86 03/01/87'I N/A feet MSL 1 17, Total Depth (MD+TVD) 18. Plug Back Depth (MD+ IA/D) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7300'MD 6764'TVD 7189'MD 6666'TVD YES [~ NO []I 1822 feetMD 1600' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP/LSS, LDT/CNL/NGT/EPT/Cal, SHDT, D I L/SFL/SP/Cal/GR/FDC/CNL, GCT, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 1875# Pol eset 9-5/8" 36.0# J-55 Surf 3929' 12-1/4" 1200 sx AS Ill & 250 s:~ Class G 7" 26.0# J-55 Surf 7277' 8-1/2" 300 sx Class G & 175 s:~ 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) 6993 'MD 6493 'TVD 2-7/8" 6936' 6906 ' 7012 ' MD 6510 ' TVD 7048'-7052'MD 6541 '-6545'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached addendJm, dated 5/16/87 0° phasing Perforated w/4 spf, . for fracture tata 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ FlowTubing Casing Pressure CALCULATED.k, 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. None ~ · . · NOTE: Drilled RR 11/20/86. Tubing run 01/14/87. Perforated we]] 03/01/87, .... 30. GEOLOGIC MARKE~-S I-0RMATION TESTS -.. NAME Inclu de interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6966' 6468' N/A Base Kupaurk C 6976' 6477' Top Kuparuk A 6976' 6477' Base Kuparuk A 7089' 6578' ,_ 31. LIST OF ATTACHMENTS Addendum, (dated 05/16/87). 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ' Title Associate Engineer Date '~----~-'~-)/ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 3/1/87 4/12/87 3Q-16 RU Schl, tst lubr & BOP to 1000 psi; OK. RIH, perf w/4 SPF, 0° phasing @ 6993', 7012' & 7048'-7052' in 2 rns, RD Schl. Release well to Production. Frac Kuparuk "A" sand perfs 6993', 7012' and 7048'-7052' in 13 stages per procedure dated 4/9/87, as follows: Stage 1: 40 bbls 140° diesel w/5% Musol @ 5 BPM, 3850 - 3150 psi Stage 2: 180 bbls gel diesel @ 12.5 - 20 BPM, 6200 - 5500 psi Stage 3: 100 bbls gel diesel @ 20 BPM, 5940 - 6270 psi Stage 4: 19 bbls gel diesel 1 ppg 100 mesh @ 19.5 BPM, 6270 - 5740 psi Stage 5: 300 bbls gel diesel @ 21BPM, 5740 - 4060 psi Stage 6: 37 bbls gel diesel 1.5 ppg 20/40 @ 21BPM, 4060 - 4080 psi Stage 7: 35 bbls gel diesel 2.5 - 4 ppg 20/40 @ 21BPM, 4080 - 4130 psi Stage 8: 34 bbls gel diesel 4 ppg 20/40 @ 21BPM, 4130 - 4060 psi Stage 9: 33 bbls gel diesel 5 ppg 20/40 @ 21BPM, 4060 psi Stage 10:31 bbls gel diesel 6 ppg 20/40 @ 21BPM, 4060 - 4010 psi Stage 11:15 bbls gel diesel 7 ppg 20/40 @ 21BPM, 4010 - 4020 psi Stage 12:15 bbls gel diesel 8 ppg 20/40 @ 21BPM, 4020 - 4010 psi Stage 13:42 bbls gel diesel flush @ 21BPM, 4010 - 4490 psi Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 881 bbls 100 Mesh & 36,950# 20/40 carbo prop 270# 2O/4O 4100 psi Turn well over to Production. STATE OF ALASKA ALASKA-ulL AND GAS CONSERVATION Ct.,,¢iMISSION ~'~.~ 'i~V , WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well '///~ OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-179 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21667 4. Location of well at surface 9. Unit or Lease Name 2301' FNL, 1965' FEL, Sec.17, T13N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1269' FSL, 324' FEL, Sec.17, T13N, R9E, UM 3Q-16 At Total Depth 11. Field and Pool 1152' FSL, 222' FEL, Sec.17, T13N, R9E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 60' ADL 25512 ALK 2553 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 11/13/86 11/19/86 03/01/87'I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. PIug Back Depth (MD+ l-VD) 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 7300'MD 6764'TVD 7189'MD 6666'TVD YES~] NC) []I 1822 feet MD 1600' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP/LSS, LDT/CNL/NGT/EPT/Cal, SHDT, DIL/SFL/SP/Cal/GR/FDC/CNL, GCT~ CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 ~urf 110' 24" 1875# Pol ese1; 9-5/8" 36.0# J-55 ~urf 3929' 12-1/4" 1200 sx AS Ill & 250 s; Cla~ G 7" 26.0# J-55 Surf 7277' 8-1/2" 300 sx Class G & 175 ~ 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) 6993 'MD 6493 'TVD 2-7/8" 6936' 6906' 7012 'MD 651 0' TVD 7048'-7052'MD 6541 '-6545'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Perforated w/4 spf, 0° phasing. N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED 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. None *NOTE: Drilled RR 11/20/86. Tubing run 01/14/87. Perforated well 03/01/87. Form 10-407 Rev. 7-1-80 WC2:37 :DAN I CONTINUED ON REVERSE SIDE Submit in duplicat~l// 29. ( 30. ~ '-. GEOLOGIC MARKER~' FORMATION TESTS ":' .: . NAME Include interval tested, pressure data, all fluids recovered and gravity, :MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ". Top Kuparuk C . 6966' 6468' N/A Base Kupaurk C 6976' 6477' Top Kuparuk A 6976' 6477' Base Kuparuk A 7089' 6578' 31. LIST OF ATTACHMENTS Addendum, (dated 03/24/87), 32. I hereby certify that the foregoing is true and correct to the best of my knowledge , 4 ° Signed "-~,'t.(.??",/~'"~" ~-~Lv-.--x..,t, Title Associate Engineer Date 4 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 3/1/87 3Q-16 RU Schl, tst lubr & BOP to 1000 psi; OK. RIH, perf w/4 SPF, 0° phasing @ 6993', 7012' & 7048'-7052' in 2 rns, RD Schl. Release well to Production. SUB-SURFACE DIRECTIONAL SURVEY r-~ UIDANCE r~ONTINUOUS ~-~'100 L Company Well Name Field/Location ARCO ALASKA, INC. 3Q-16(2301' FNLt 1965' KUPARUK, NORTH SLOPE~ FEL~SEC ALASKA 1 7~T1 3N, R9E, UM) Job Reference No. 72159 Log(3ed By: WEST Date 21-DEC-86 Computed By: KRUWELL GCT DIRECTIDNAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA~ INC. ~ ~r~ ~' ¥' ".~ .... 3Q-16 KUPARUK NORTH SLOPE,ALASKA SURVEY DATE: 21-DEC-86 ENGINEER: T. WEST METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH ~ DEG 22 MIN EAST ARCO ALASKA, INC. 3Q-16 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 8-JAN-87 PAGE 1 DATE DP SURVEY: 21-DEC-86 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DE¥IATIDN AZIMUTH DEPTH DEPTH DEPTH DEG MIN OEG MIN 0.00 0.00 -60.00 0 0 N 0 0 E 100.00 100.00 40.00, 0 2 S 74 23 E 200.00 200.00 140.00 0 6 S 34 27 E 300.00 300.00 240.00 0 5 S 49 5 E 400.00 399.99 339.99 0 6 S 50 6 E 500.00 499.99 439.99 I 24 S 59 I E 600.00 599.84 539.84 4 48 S 49 12 E 700.00 699.16 639.16 8 4 S 44 6 E 800.00 797.75 737.75 11 16 S 45 0 E 900.00 895.46 835.46 13 10 S 46 5 E VERTICAL DOG=LEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E 0.43 0.21 0.09 S 0.52 E 0.52 0.44 0.18 S 0.56 E 0.67 0.02 0.28 S 0.67 E 0.83 0.14 0.39 S 0.79 E 1.40 4.43 0.66 S 1.33 E 6.71 4.52 3.91 S 5.60 E 18.20 3.50 11.95 S 13.82 E 34.83 2.96 23.88 S 25.40 E 56.10 2.56 38.82 S 40.54 E 1000.00 992.27 932.27 16 1 1100.00 1087.14 1027.14 20 11 1200.00 1180.52 1120.52 21 23 1300.00 1273.10 1213.10 22 51 1400.00 1365.19 1305.19 22 58 1500.00 1457.41 1397.41 22 44 1600.00 1549.68 1489.68 22 18 1700.00 1642.30 1582.30 22 2 1800.00 1734.61 1674.61 23 30 1900.00 1826.04 1766.04 23 59 S 45 3 E 81.10 8.92 $ 44 45 E 112.64 3.21 S 42 52 E 148.40 1.19 S 41 51 E 186.16 0.38 S 42 32 E 225.10 0.14 S 42 22 E 263.77 0.28 S 41 32 E 302.29 0.94 S 40 53 E 339.93 0.76 S 40 38 E 378.31 1.46 S 39 59 E 418.70 0.60 2000.00 1917.27 1857.27 24 20 I~88 88 08.30 1948.30 24 21 : 2300.00 2191.50 2131.50 22 52 2400.00 2283.73 2223.73 22 48 2500.00 2375.83 2315.83 23 2 2600.00 2467.78 2407.78 23 15 2700.00 2559.56 2499.56 23 19 2800.00 2652.09 2592.09 ZO 36 2900.00 2746.27 2686.27 18 42 459.49 0.53 500.71 1.57 541.14 0.46 580.82 0.67 619.46 0.30 658.43 0.19 697.71 0.25 737.40 0.67 775.27 3.04 808.86 2.85 S 38 59 E S 39 4 E S 43 10 E S 43 8 E S 42 59 E S 42 55 E S 42 $3 E S 42 46 E S 42 53 E S 42 50 E 3000.00 2841.73 2781.73 16 31 3100.00 2937.88 2877.88 15 16 3200.00 3034.58 2974.58 13 42 3300.00 3132.23 3072.23 11 55 3400.00 3230.08 3170.08 11 58 3500.00 3327.85 3267.85 12 10 3600.00 3425.58 3365.58 12 14 3700.00 3523.30 3463.30 12 16 3800.00 3621.03 3561.03 12 13 3900.00 3718.77 3658.77 12 16 S 44 35 E 838.59 S 43 21 E 866.06 S 43 15 E 891.52 S 45 41 E 913.05 S 45 36 E 933.67 S 44 44 E 954.65 S 44 13 E 975.81 S 43 56 E 997.05 S 43 43 E 1018.24 S 43 53 E 1039.41 0.00 N 0 0 E 0.53 S 80 34 E 0.59 S 72 42 E 0.73 S 67 14 6 0.88 S 63 33 E 1.48 S 63 36 6.83 S 55 5 L 18.27 S 49 8 E 34.87 S 46 46 E 56.13 S 46 14 E 56.20 S 58.52 E 81.14 S 46 '9 E 78.09 S 81.25 f 112.69 S 46 8 E 103.87 S 106.04 E 148.43 S 45 35 E 131.92 S 131.35 E 186.17 S 44 52 E 160.77 S 157.56 E 225.10 S 44 25 E 189.30 S 183.69 E 263.78 S 44 8 E 217.94 S 209.50 E 302.30 S 43 52 f 246.26 S 234.36 E 339.96 S 43 34 E 275.43 S 259.43 f 378.37 S 43 17 E 306.26 S 285.68 E 418.82 S 43 0 E 337.88 S 311.70 E 459.69 S 42 41 E 370.20 S 337.59 E 501.01 S 42 21 E 400.63 S 364.30 E 541.50 S 42 16 E 429.54 S 391.51 E 581.19 S 42 20 E 457.78 S 417.89 E 619.83 S 42 23 E 486.30 S 444.45 E 658.81 S 42 25 E 515.08 S 471.20 E 698.10 S 42 27 L 544.20 S 498.Z0 E 737.81 S 42 28 E 571.99 S 523.94 f 775.68 S 42 29 E 596.63 S 546.79 E 309.29 S 42 30 E 0.78 0.98 3.21 0.37 0.33 0.22 0.16 0.10 0.12 0.27 618.08 S 567.38 E 839.01 S ~Z 33 E 637.75 S 586.55 E 865.47 S 42 36 E 656.42 S 603.88 E 891.94 S 42 36 E 571.74 S 619.00 E 913.45 S 42 39 E 686.13 S 633.78 E 934.05 S 42 43 E 700.90 S 648.68 E 955.02 S 42 47 E 716.02 S 663.50 E 976.17 S 42 49 E 731.28 S 678.26 E 997.40 S 42 50 E 746.56 S 692.95 E 1018.59 S 42 52 E 761.88 S 707.56 E 1039.76 S 42 52 E ARCO ALASKA, INC. 3Q-16 KUPARUK NORTH SLDPE~ALASKA COMPDTATION DATE: 8-JAN-87 PAGE DATE OF SURVEY: 21-DEC-86 KELLy BUSHING ELEVATION: ENGINEER: T, WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH' DEG MIN DEG MIN 60, O0 FT 4000.00 3816,43 3756,43 12 34 4100,00 3913,94 3853,94 13 16 4200.00 4010.77 3950.77 15 53 4300.00 4106,19 4046,19 18 48 4400°00 4200..07 4140,07 21 26 4.500.00 4292.25 4232.25 24 16 4600,00 4382,20 4322,20 27 22 4700.00 4470.27 4410.27 28 32 4800.00 4558.15 4498.15 28 26 4900,00 4646,15 4586,15 28 20 S 44 11 E 1060,89 S 44 12 E 1083,05 S 44 1 E 1107,99 S 44 27 E 1137,85 S 43 22 E 1172.27 S 41 59 E 1210,99 S 43 25 E 1254,61 S 44 40 E 1301.96 S 44 49 E 1349,68 S 44 55 E 1397,17 0.36 1.52 3.08 2.57 2.82 2.86 3.02 0.06 0.46 0.15 777,28 S 722.53 E 1061.24 S 42 54 E 793,18 S 737,97 E 1083,39 S 42 56 E 811.11 S 755.31 E 1108.33 S 42 57 E 832.44 S 776.20 E 1138.18 S 42 59 E 857,16 S 800,14 E 1172.59 $ 43 1 E 885,72 S 826,32 E 1211.33 S 43 0 F . 917,97 S 855,74 E 1254.97 S 42 59 k 951.83 S 888.84 E 1302.31 S 43 2 E 985.73 S 922.43 E 1350.01 S 43 5 E 1019.38 S 955.93 E 1397.48 S 43 9 E 5000.00 4734.21 4674.21 28 14 5100.00 4822.31 4762.31 28 15 5200.00 4910,39 4850.39 28 18 5300.00 4998.33 4938.33 28 32 5400.00 5086.09 5026.09 28 45 5500.00 5173.65 5113.65 29 2 5600.00 5261.01 5201.01 29 10 5700,00 5348,24 5288,24 29 10 5800.00 5436.03 5376.03 27 57 5900.00 5524.45 5464.45 27 48 S 44 56 E 1444.54 S 44 52 E 1491,86 S 44 53 E 1539,21 S 44 54 E 1586,82 S 44 57 E 1634.76 S 44 58 E 1683.05 S 44 55 E 1731.73 S 45 2 E 1780.51 S 44 52 E 1828,48 S 44 53 E 1875.20 0,10 0,06 0,23 0,20 0,30 0,46 0,34 0,61 0,51 0,16 1052.90 S 989.42 E 1444.84 S 43 13 E 1086.43 S 1022.81 E 1492.13 S 43 16 E 1119.98 S 1056.23 E 1539.47 S 43 19 E 1153.71 S 1089.83 E 1587.07 S 43 22 E 1187.65 S 1123.69 E 1634,99 S 43 2~ E 1221,79 S 1157,84 E 1683.26 S 43 27 E 1256,26 S 1192,22 E 1731,92 S 43 30 E 1290,82 S 1226.79 E 1780.79 S 4.3 32 E 1324.68 S 1260.63 E 1828.65 S 43 34 E 1357.79 S 1293,59 E 1875.36 S 43 36 E 6000.00 5612.94 5552.94 27 42 6100.00 5701.47 5641.47 27 46 6200.00 5789.87 5729.87 27 56 6300.00 5878.22 5818.22 27 59 6400.00 5966.56 5906.56 27 41 6500.00 6055.21 5995.21 27 36 6600.00 6143.86 6083.86 27 29 6700.00 6232.56 6172.55 27 32 6800.00 6321.23 6261.23 27 25 6900.00 6409.95 6349.95 27 34 S 44 54 E 1921.77 S 44 57 E 1968.28 S 44 56 E 2015.02 S 45 7 E 2061.86 S 45 25 E 2108.72 S 45 46 E 2154,97 S 45 34 E 2201.24 S 44 42 E. 2247.41 S 43 31 E 2293.64 S 41 26 E 2339.75 0.26 0.12 0.07 0.33 0.67 0.23 0.39 0.45 0.80 0.70 1390.79 S 1326,47 E 1921.93 S 43 38 E 1423,72 S 1359.30 E 1968.42 S 43 40 E 1456,79 S 1392,34 E 2015,15 S 43 42 E 1489.91 S 1425.47 E 2061.99 S 43 44 E 1522.93 S 1458.72 E 2108.83 S 43 45 E 1555.28 S 1491.80 E 2155.08 S 43 48 E 1587.55 S 1524.97 E 2201.33 S 43 50 L 1620.13 S 1557.70 E 2247.49 S 43 52 E 1653.27 S 1589.92 E 2293.72 S 43 52 E 1687.29 S 1621.09 E 2339.85 S 43 51 E 7000.00 6498.64 6438.64 27 29 7100.00 6587.26 6527.26 27 37 7200.00 6675,82 6615.82 27 47 7300.00 6764.28 6704.28 27 47 S 41 14 E 2385.89 S 40 56 E 2432.13 S 40 42 E 2478.50 S 40 42 E 2525.03 0,35 0.68 0.00 0.00 1722.03 S 1651.56 E 2386.01 S 43 48 E 1756.92 S 1682.02 E 2432.27 S 43 45 E 1792.12 S 1712.35 E 2478.68 S 43 41 E 1827.47 S 1742.75 E 2525.24 S 43 38 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN COMPUTATION DATE: 8-JAN-87 PAGE 3 ARCO ALASKA, INC. 3Q-16 KUPARUK NORTH SLOPE~ALASKA DATE OF SURVEY: 21-DEC-86 KELLY BUSHING ELEVATION: ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH D:EG.MIN DEG MIN 0.00 0.00 -60.00 0 0 1000.00 992.27 932.27 16 2000.00 1917.27 1857.27 24 20 3000.00 2841.73 2781.73 16 31 4000.00 3816.43 3756.43 12 34 5000.00 4734.21 4674.21 28,14 6000.00 5612.94 5552.94 27 42 7000.00 6498.64 6438.64 27 29 7300.00 6764.28 6704.28 27 47 60. O0 FT VERTICAL DOGLEG RECTANGULAR CODRDINATES HORIZ. DEPARTURE SECTION SEVERI'TY NORTH/SOUTH EAST/WEST DIS'T. AZIMUTH FEET DEG/IO0 N 0 0 E 0.00 S 45 3 E 81.10 S 38 59 E 459.49 S 44 35 E 838.59 S 44 11 E 1060.89 S 44 56 E 1444.54 S 44 54 E 1921.77 S 41 14 E 2385.89 S 40 42 E 2525.03 0.00 8.92 0.53 0.78 0.36 0.10 0.26 0.35 0.00 FEET FEET FEET DEG MIN 0.00 N 0.00 E 0.00 N 0 0 E 56.20 S 58.52 E 81.14 S 46 9 E 337.88 S 311.70 E 459.69 S 42 41 E 618.08 S 567.38 E 839.01 S 42 33 E 777.28 S 722.53 E 1061.24 S 42 54 E 1052.90 S 989.42 E 1444.84 S 43 13 F 1390.79 S 1326.47 E 1921.93 S 43 38 t 1722.03 S 1651.56 E 2386.01 S 43 48 E 1827.47 S 1742.75 E 2525.24 S 43 38 E COMPUTATION DATE: 8-JAN-87 PAGE 4 ARCO ALASKA, INC. DATE OF SURVEY: 21-DEC-86 3Q-16 KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: T. WEST 60.00 FT INTERPOLATED VALUES FOR'EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST' AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -60.00 0 0 N 0 0 E 60.00 60.00 0.00 0 9 S 80 10 E 160.00 160.00 100.00 0 3 S 7 33 E 260.00 260.00 200.00' 0 4 S 51 19 E 360.01 360.00 300.00 0 6 S 42 46 E 460.01 460.00 400.00 0 13 S 69 15 E 560.07 560.00 500.00 3 20 S 52 34 E 660.50 660.00 600.00 7 0 S 44 54 E 761.59 760.00 700.00 9 53 S 44 5 E 863.64 860.00 800.00 12 29 S 45 23 E 0.00 0.00 0.00 N 0.00 E 0.37 1.65 0.07 S 0.45 E 0.47 0.03 0.13 S 0.54 E 0.61 0.13 0.24 S 0-63 E 0.76 0.31 0.34 S 0.74 E 0.97 0.88 0.47 S 0.91 E 3.97 1.55 2.17 S 3.46 E 13.03 3.01 8.26 S 10.19 E 27.76 3.61 18.84 S 20.44 E 48.07 1.45 33.21 S 34.80 E 0.00 N 0 0 E 0.46 S 80 40 E 0.56 S 76 54 E O. 67 S 68 45 E 0.82 S 64 59 E !. 02 S 62 31 ~ 4.08 S 57 52 ~. 13.12 S 50 58 E 27.80 S 47 19 E 48.10 S 46 20 E 966.58 960.00 900.00 14 58 1071.18 1060.00 1000.00 19 10 1177.97 1160.00 1100.00 21 11 1285.78 1260.00 1200.00 22 47 1394.36 1360.00 1300.00 22 58 1502.81 1460.00 1400.00 22 44 1611.16 1560.00 1500.00 22 12 1719.09 1660.00 1600.00 22 7 1827.73 1760.00 1700.00 23 48 1937.17 1860.00 1800.00 24 6 S 45 54 E 72.41 4.32 S 45 30 E 102.94 3.97 S 43 23 E 140.40 1.30 $ 41 47 E 180.6~ 0.66 S 42 31 E 222.90 0.14 S 42 22 E 264.86 0.23 S 41 26 E 306.51 0.66 S 40 43 E 347.07 0.96 S 40 33 E 389.43 0.73 S 39 31 E 433.78 0.79 49.96 S 52.48 E 72.45 S 46 24. E 71.24 S 74.37 E 102.99 S 46 13 E 98.02 S 100.57 E 140.44 S 45 44 E 127.81 S 127.67 E 180.65 S 44 58 E 159.15 S 156.07 E 222.90 S 44 26 E 190.10 S 184.43 E 264.86 S 44 7 E 221.10 S 212.30 E 306.52 S 43 50 E 251.68 S 239.04 E 347.11 S 43 31 E 283.89 S 266.69 E 389.51 S 43 12 E 317.89 S 295.36 E 433.92 S 42 53 E 2046.92 1960.00 1900.00 24 29 2156.64 2060.00 2000.00 23 47 2265.81 2160.00 2100.00 23 17 2374.27 2260.00 2200.00 22 45 2482.81 2360.00 2300.00 23 0 2591.53 2460.00 2400.00 23 14 2700.48 2560.00 2500.00 23 19 2808.45 2660.00 2600.00 20 19 2914.45 2760.00 2700.00 18 16 3019.05 2860.00 2800.00 16 22 S 38 36 E S 41 43 E S 43 14 E S 43 I E S 42 55 E S 42 53 E S 42 46 E S 42 54 E S 43 8 E S 44 36 E 478.80 0.35 523.74 2.94 567.53 2.02 609.52 0.19 651.70 0.17 694.37 0.25 737.59 0.69 778.23 2.54 813.37 3.05 844.00 0.84 353.00 S 323.84 E 479.04 S 42 31 E 387.87 S 352.47 E 524.10 S 42 15 E 419.83 S 382.41 E 567.89 S 42 19 E 450.50 S 411.11 E 609.88 S 42 22 E 481.37 S 439.87 E 652.08 S 42 25 E 512.64 S 468.93 E 694.76 S 42 27 F 544.34 S 498.33 E 738.00 S 42 28 L 574.16 S 525.95 E 778.65 S 42 29 E 599.93 S 549.86 E 813.80 S 42 30 E 621.92 S 571.19 E 844.42 S 42 33 E 3122.91 2960.00 2900.00 15 3 3226.12 3060.00 3000.00 12 54 3328.38 3160.00 3100.00 11 53 3430.60 3260.00 3200.00 12 3 3532.89 3360.00 3300.00 12 11 3635.21 3460.00 3400.00 12 15 3737.55 3560.00 3500.00 1Z 14 3839.87 3660.00 3600.00 12 12 3942.21 3760.00 3700.00 12 22 4044.65 3860.00 3800.00 12 45 S 43 2 E 872.04 S 43 59 E 897.52 S 45 48 E 918.89 S 45 27 E 940.05 S 44 29 E 961.59 S 44 5 E 983.27 S 43 53 E 1005.02 S 43 36 E 1026.68 S 44 11 E 1048.41 S 44 8 E 1070.68 0.82 3.04 0.13 0.33 0.15 O.ZO 0.09 0.07 0.34 0.44 642.12 S 590.64 E 872.45 S 42 36 E 660.79 S 608.00 E 897.94 S 42 37 E 675.81 S 623.20 E 919.29 S 42 40 E 690.60 S 638.34 E 940.42 S 42 44 E 705.85 S 653.55 E 961.95 S 42 47 E 721.37 S 668.69 E 983.63 S 42 49 E 737.02 S 683.79 E 1005.37 S 42 51 E 752.67 S 698.77 E 1027.03 S 42 52 E 768.35 S 713.82 E 1048.76 S 42 53 E 784.30 S 729.35 E 1071.02 S 42 55 E ARCO ALASKA, INC. 3Q-16 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 8-JAN-87 PAGE DATE OF SURVEY: 21-DEC-86 KELLY BUSHING ELEVATION: ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 4147.41 3960.00 3900.00 14 20 4251.37 4060'00 4000.00 17 27 4357'12 4160.00 4100.00 20 17 4464.78 4260.00 4200.00 23 15 4575.02 4360.00 4300.00 ,26 40 4688.31 4460.00 4400.00 28 31 4802'10 4560.00 4500.00 28 25 4915.73 4660.00 4600.00 28 19 5029.27 4760.00 4700.00 28 14 5142.79 4860.00 4800.00 28 15 5256.39 4960.00 4900.00 28 27 5370.25 5060.00 5000.00 28 41 5484.38 5160.00 5100.00 28 59 5598.85 5260.00 5200.00 29 10 5713.48 5360.00 5300.00 29 5 5827.11 5460.00 5400.00 27 53 5940.19 5560.00 5500.00 27 46 6053.14 5660.00 5600.00 27 43 6166.19 5760.00 5700.00 27 53 6279.38 5860.00 5800.00 27 57 6392.59 5960.00 5900.00 27 44 6505.40 6060.00 6000.00 27 36 6618.19 6160.00 6100.00 27 29 6730.95 6260.00 6200.00 27 33 6843.66 6360.00 6300.00 27 27 6956.44 6460.00 6400.00 27 30 7069.22 6560.00 6500.00 27 37 7182.12 6660.00 6600.00 27 47 7295.16 6760.00 6700.00 27 ~7 7300.00 6764.28 6704.28 27 47 60. O0 FT FEET OEG/IO0 FEET FEET FEET' DEG MIN S 44 5 E 1094.30 S 44 26 E 1122.67 S 44 3 E 1157.01 S 42 16 E 1196.83 S 42 46 E 1243.17 S 44 38 E 1296.38 S 44 49 E 1350.69 S 44 57 E 1404.63 S 44 53 E 1458.39 S 44 52 E 1512.12 S 44 54 E 1566.01 S 44 56 E 1620.47 $ 44 59 E 1675.46 S 44 55 E 1731.16 S 45 2 E 1787.20 S 44 51 E 1841.15 S 44 53 E 1893.93 S 44 55 E 1946.46 S 44 57 E 1999.18 S 45 4 E 2052.20 S 45 22 E 2105.27 S 45 47 E 2157-48 S 45 25 E 2209.63 S 44 24 E 2261.73 S 42 40 E 2313.73 S 41 16 E 2365.81 S 41 5 E 2417.86 S 40 42 E 2470.19 S 40 42 E 2522.78 S 40 42 E 2525.03 2.81 3.01 2.66 2.93 3.51 0.17 0.48 0.15 0.10 0.03 0.22 0.15 0.62 0.33 1.03 0.20 0.16 0.12 0.20 0.24 0.71 0.19 0.43 0.62 1.13 0.32 0.32 0.00 0.00 0.00 801.24 S 745.81 E 1094.64 S 42 56 E 821.63 S 765.55 E 1123.00 S 42 58 E 846.15 S 789.58 E 1157.33 S 43 1 E 875.21 S 816.83 E 1197.16 S 43 1 E 909.63 S 847.90 E 1243.53 S 42 59 E 967.86 S 884.91 E 1296.73 S 43 1 r 986.44 S 923.13 E 1351.02 S 43 6 ~ 1024.66 S 961.21 E 1404.94 S 43 10 E 1062.70 S 999.20 E 1458.68 S 43 14 E 1100.78 S 1037.1i E 1512.39 S 43 1T E 1138.96 S 1075.14 E 1566.26 S 43 20 E 1177.53 S 1113.60 E 1620.70 S 43 24 E 1216.42 S 1152.48 E 1675.67 S 43 27 f 1255.86 S 1191.82 E 1731.36 S 43 30 E 1295.47 S 1231.46 E 1787.38 S 43 32 E 1333.67 S 1269.56 E 1841.32 S 43 35 E 1371.07 S 1306.81 E 1894.09 S 43 37 E 1408.28 S 1343.90 E 1946,61 S 43 39 E 1445.58 S 1381.15 E 1999.32 S 43 41 E 1483.09 S 1418.63 E 2052.33 S 43 43 E 1520.51 S 1456.27 E 2105.39 S 43 45 E 1557.03 S 1493.60 E 2157.58 S 43 48 E 1593.44 $ 1530.96 E 2209.72 S 43 51 E 1630.33 S 1567.75 E 2261.82 S 43 52 E 1667.93 S 1603.66 E 2313.81 S 43 52 E 1706.93 S 1638.28 E 2365.92 S 43 49 E 1746.14 S 1672.63 E 2417.99 S 43 46 1785.81 S 1706.91 E 2470.35 S 43 42 E 1825.76 S 1741.28 f 2522.98 S 43 38 E 1827.47 S 1742.75 E 2525.24 S 43 38 E VERTI'CAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH COMPUTATION DATE: B-JAN-BT PAGE 6 ARCO ALASKAs INC. 3Q-16 KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD DATE OF SURVEY: 21-DEC-B6 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB FROM KB SURFACE LOCATION AT ORIGIN: 2301 FNLs 1965 EEL, SEC 17, T13N, RgE~ UM TVO RECTANGULAR COORDINATES SOB-SEA NORTH/SOUTH EAST/WEST 6966.00 6976.00 6976.00 7089.00 7189.00 7300.00 6468.48 6408.48 1710.24 S 1641.20 6477.34 6417.34 1713.71 S 1644.26 6477.34 6417.34 1713.71 $ 1644.26 6577.52 6517.52 1753.06 $ 1678.66 6666.08 6606.08 1788.24 S 1709.00 6764.28 6704.28 1827.47 S 1742.75 COMPUTATION DATE: 8-JAN-87 PAGE 7 ARCO ALASKA, INC. 3Q-16 KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTO TD ,O,******~, STRATIGRAPHIC MEASURED DEPTH BELOW KB 6966.00 6976.00 6976.00 7089°00 7189.00 7300.00 DATE OF SURVEY: 21-DEC-86 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: T. WEST SUMMARY ORIGIN= 2301 TVD FROM KB SUB-SEA FNL, SURFACE LOCA AT 1965 FEL, SEC 17, RECTANGULAR CO0 NORTH/SOUTH E TION T13N~ RgE~ RDINATES AST/WEST UM 6468.48 6408.48 6477.34 6/+17o34 6477.34 6417,34 6577.52 6517.52 6666.08 6606°08 6764.28 6704.28 171 171 171 175 178 182 · 3. 3. 3. 8. 7. 2/+ 71 71 O6 24 47 16 16 16 16 17 17 41.20 E 4/+.26 E 44.26 E 78.66 E 09. O0 E 42.75 E FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPA-RTURE DISTANCE AZIMUTH FEET DEG ,MIN 7300.00 6764.28 6704.28 2525.24 S 43 38 E SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3[~- 16 F ! ELD KUPARUK COUNTRY USA RUN 1 DATE LOOOED 21 - DEC - _86 REFERENCE 721S9 WELL' 3Q-16 HORIZONTAL PROJECTION (2301' FNL, 1965' FEL, SEC 17, T13N, R9E,UM) NORTH ISO0 REF 721S9 SCALE : I/S00 IN/FT ~ 000 800 - ! 000 - ] 800 -2OOO -.?'..4..-~..4q-~--.-~.-.~--.~ ...... L.~-.L.L.L.L.4...L.~ ...... -L4...,L.L.L.L-L4..-i ...... L.L-L.L. uL-L.-VL..:.~.,_L4...L: ~.~ ~ ~ · ~ ~ ~ ~ , ~ ~ ~ ~ F~ ..... ..... -.~-~.-~-.~--~--~..-~--~.--~-..-.~..~-~.4-.N-+;~:~: :N:~T;~]LT]:];~ :L~Li~.:EN]~; -'t-V'"~?'-~t; --t-'?--t---~--t---t--tt~ ...... H"'f-f'-f-f-'f--H--t-'-H---f--H-f-.-H--~ : · : : ] : : i : ~ : : ~ : : ~ : : : : ] : : : ~ : ~ ~ t ~: ? .?.~.~.~_?..~..~__~~'~-?'"~?'?-?~-~ ~-~-'~'"~ '-t ....... t"'t-'-?'?'~--~ ....... ?-'r'~-~ .... ~-~ ...... ~--~-+--~--~-¢..4-~-.-~-4-~-4..~-~-~¢-~-~4-~-~-: : : : : ~ : : : ~ii ~/,'!~= ~i~,i~:~ 11~ ,~ :. i :. ~ ~ ~ :. ~1:.~i~ ~i~ --h?-?-.~--l--+..~-.~-~ .... H-.-H-.f-+-++~ ..... ~.-~-¢+.++.+-~-~-.4--~..~r+4-~-.-~--;--~.-1~..~..~4~. -N-+.4 .... kNq-- ..~--~...~.-~-....]~-.~".~]]]~:,]~]~]:ZZ Z~]]] ]Z~Z~ZZ v~ "~-'~'- ~ T'~t'"'-i J ~-'t- ~iq ~ -4.4q-$- 44-~-4--$44-k U.N44_ ~.Wo~4.-.L~... L..~N~ ~-L~.-. ~4-~-~-~-LLL_j ~ L ii ~ ~ ~ ~ ~ ~ ~-.L.L.-4-.~4M_,~.4 .... M-i ~ ~ ~ i i .4_~_. ~ ~ ~ i i i ~ ~ ~-~'"~'~-~ ..... ~i4-~.~4_.~_.]_~ ~ ~_~ .... ~ ,_~ ~ ~ ~ ~ ~j ~ i i i i::~i-' T'~ i Hi ~'~-~T~-~'-i~'"~ff?'-i--~-+-t--~-~.~- "t~"rl .... N-'~--'r'~-'r'~-~-1-1- 'I'-~?" ~ff"-f--~-- ?ff~-' -~e~ ~ i fi-f- e-~+i--, q~.-!--.~-.f--i+4- 4...M-4.- I ' , , i · ~ : i , i i = , i~ I i i ii i i ................... -.-j..-fd--i ...... t-.fi.hi ..... f-.f-.,-i ...... H-..ff-i-..-.+-f++- -~-~-lq---j~-l-..~A[--~-i.-p -i-Pi--~q.44-.i ...... 1.44..4 ..... . ,~--~-~-~-?-,-~?+-~--+-~-+-~ ! ~ ~ ~ ~ ~~-~4 ~ ~---*-~-~-~ ~-4- -~-~ · 4-4-.j-.~ ..... ~-4.4.-i .... L.;-,~-..~-~...i-~: ~ I_.~ ~ , L_~ ~ ~ ~__~ L~ ~ ,_~ ~ ~ ~ L4.J ~ ~ ~ ~ ~ ~ ~i i ~-t-.~.-.~,l-.;.,l ..... i-;~-4 ....i-4-,-.i--..4-4-;4 ...... ;-i4,4--~4-i i i i-; : '-' '~-: ' 4-:- :;' : : : : ' ; ~ , , : /: : ~ : ~ : : : · ~ i : : · : ~ :: ~ , ~ : 1! Pt ? I-, T ! : P~'-~'1-~-t' ~TH -~00 -?-+--f-+t~ .--i---~-.t-.+ ........ ...... ~-i-.+-.i ..... ~-+..+--i-~ ....... -.i--f-~-.+-,: -~-i-~. ...... -4-.~41 i ~-'~'~":: ~ : .~"~-i-;'~ ~ ~ 4..~4.-,....~ ~ : i : "4-;4'-'~1"'i'4'"i"4~ ~ ~ ~ , : ~ ~ ~ i-.;~ ~ - 1000 -~00 0 ~00 1000 1 ~00 2000 WEBT WELL- 3Q-16 VERTICAL PROJECTION (2301' FNL, 1965' FEL, SEC 17, T13N, R9E,UM) NW -500 0 0 500 !000 !500 ....... ~' /muu BOO0 ' I ~ ~ ~ ~ ~ ~ ~ : ~ ~, ~ ~ ~ ~ ~ : ~ ................... / _.. , ~ . . ,_.._.. 1SO0 ]'! ]]?"~ ..... ~'"~-!"'~ ~ ~ i ~ ~ i - TT'T"I-TTTT"-TT"FT'~-T":-T": ....~ T":-:"T"F'f"f"?": ...... f-f--f--f-~'-'f--f--H~-- ~- ~-i ~ -~--~ ~- H~.- '-T"~'F'~-'-T"??? '~-'~-'~ .... ~-+'?~'"-~-~-.H~ ..... ~.4-~-.-~..~...~.~-L~..$.~_~_. ~..~ -IN..H ..... }.+l. --H-HH-H-4-4.-. ..:: ,4 · 'fit % Pi11-i-~ !-t--t-?-:'--t-f-t--t -?-~-e~-+4~-.-4-%{-H-,-4-4-.H~ .... ~.-4-.H~-.,~Z 4-44-4-.~4 : :_~ ~ i ~ ~ ~-T~-~~~-fd-t-%~-~-- : T: i ~ ~ ~ i ~ ~ : : :-~ : :~- -~-~ : i ~ ~ ~ ~ ~ ~ ~ 1-t ~ : z : r ~ ~ z~-~-4~-' ' · ~-4.4-4-: ...... -~"~'~'-~-~-~'-~-'t-~--~-~..-~-~-.-~-.~-.,~ ~ ~ ~-4--~ ~-.-4 J ] l ~'~ ¢ i-' -~+- 'T"Y'Y~" -??~-Y' ~"Y '-'*~-'f"'t-- ' ~ ~ : ~-'t~-~-' %-~-H .... {--}-.}-}--~ -4-.~-.~q--' -~--++ ...... .%Hr-': ~+,_~~.'::: _3, ~L.~z...~, . ~,~_~ _~._~ ~ A-_,...,_.,_.,~ T ~- ? ..... - - ,--~--,--,---,F F ~' ~ hT-'?T"~ ...... F~'F%?T"~'~'"~- -? h~- SE PROdECTION ON VERTICAL PLANE SE - NH SCALEO IN VERTICAL BEPTH$ HORIZ SCALE = 1/S00 IN/FT · _ FEB i987 0ii & Gas 0on& 0ommissio:? --- STATE OF ALASKA ALASI%. ,)IL AND GAS CONSERVATION COMIk...SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown © Alter Casing [] Other Stimulate F'., Plugging [] Perforate ~ Pull tubing COMPLETE 2. Name of Ooerator ARCO AlAska, Inc. 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2301' FNL,1965' FEL, Sec.1'7, T13N, R9E, UN At top of productive interval 1269' FSL, 324' FEL, Sec.17, T13N, R9E, UM At effective depth 1191' FSL, 256' FEL, Sec.17, T13N, R9E, UM At total depth 1152' FSL, 222' FEL, Sec.17, T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 60 ' 6. U, nit or ,Pr~operty name ~,uparuK r~3ver Unit 7. Well number 3Q-16 8. Approval number 672 9. APl number 50-- 029-21667 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface 7300'MD 6764'TVD P~oduction 7189'MD 6666'TVD Length Size 80' 16" 3894' 9-5/8" 7242 ' 7" feet feet feet feet Plugs (measured) Junk (measured) None None Cemented Measured depth 1875# Poleset 110'MD 1200 sx AS III & 3929 'MD 250 sx Class G 300 sx Class G & 7277'MD 175 sx AS I Feet Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) 2-7/8", L-80, tbg w/tail ~ 6936' Packers and SSSV (type and measured depth) HRP pkr ~ 6906' & FVL SSSV ~ 1822' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED FEB 1987 ,Aiaska 0il & Anch0ra~e 13. Representative Daily Average Production or Injection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Well Hi story) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ c. YRO 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~' [t'7~/°u/)(-./ ~//~¢t J.Z~ Form 10-404 Rev. 12-1-85 Title Associate Engineer (DANI) 5W0/169 True Vertical depth 110'TVD 3747 'TVD 6744 ' TVD Date Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Inslructions: Prepare and submit the "Final Report" on the first Wednesday alter allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indetinite or appreciable length of time. On workovers when an oHicial test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is availab!e. District County or Parish Alaska North Slope Borough Field Lease or Unit Kuparuk River ADL 25512 Auth. or W.O. no. T tle AFE AKi703 Completion Accounting cost center code State Alaska IWoII no. 3Q-16 Nordic 1 Operator AR,Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun I Date Complete I 1/13/87 Date and depth as of 8:00 a.m. 1/15/87 Complete record for each day reported API 50-029-21~ I otal number of wells (active or inactive) on this Dst center prior to plugging and [ bandonment of this well I our I Prior status if a W.O. I 1700 hrs. 7" @ 7277' 7189' PBTD, RR 6.8 ppg Diesel Accept ri~ @ 1700 hfs, 1/13/87. Rn 214 jts, 2-7/8", 6.5#, L-80 EUE 8RD AB-Mod tbg w/SSSV @ 1822', HRP Pkr @ 6906', TT @~~. Tst pkr to 2500 psi, tst SSSV ; OK. ND BOPE, NU & tst tree to ~~ ~ 250/5000 psi. Displ well w/diesel. RR @ 1645 hrs, 1/14/87. A~s~,(a 0~ & Gas ConS. Anchorage Old TO New TD 7189 ' ?BTD Released rig Date 1645 hrs. Classifications (oil, gas, etc.) 0±1 Producing method Flowing Potential test data PB Depth Kind of rig 1/14/87 Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The aJ;~e i~ correct ,/ / Sigr~ture / ~ ) ~ For form preparat'~nJ and~ dis~ion, ~ see Procedures Ma'n~ual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 22, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5893 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Finals: (1 blueline unless otherwise specified) 3K-12 2" & 5" FDC Raw 11-11-86 7100-7741 2" & 5" FDC Porosity 11-11-86 7100-7741 2" & 5" DIL 11-11-86 3980-7767 Cyberlook 11-11-86 7150-7720 3K-11 2" & 5" FDC Porosity 11-4-86 7000-7782 2" & 5" FDC Raw 11-4-86 7000-7782 2" & 5" DIL 11-4-86 1000-7808 Cyberlook 11-4-86 7000-7750 3Q-16 2" & 5" FDC Raw 11-18-86 5900-?226 2" & 5" FDC Porosity 11-18-86 5900-7226 2" & 5" DIL 11-18-86 3931-7252 Cyberlook 11-18-86 6030-7100 Receipt Acknowledged: DISTRIBUTION: NSK Drilling L. Johnston (vendor Pkg). ~26] .... ~/// Date: Rathmell D & M ~ Vault [film) ARCO Alaska, Inc. is a Subsidiary of AllanlicRichlieldCompany NEW PROJECTS ENGINEERING TRANSMITTAL # 1038 TO: John Boyle State DATE: FROM: H. D. White/P. S. Baxter WELL NAME: 3Q-16 TRANSMITTED HEREWITH ARE THE FOLLOWING: Finals Bluelines and Sepia for each: 3Q-16 2" LDT-CNL-NGT (Raw Data) 3Q-16 5" Natural Gamma Spectroscopy 3Q-16 2" Long Spacing Sonic - GR 3Q-16 5" Dual Induction SFL - GR 3Q-16 2" Natural Gamma Spectroscopy 3Q-16 2" Dual Induction SFL - GR 3Q-16 5" LDT-CNL-NGT Raw & 25" Hi-Res) 3Q-16 Cyberlook 3Q-16 25" Electromagnetic Propagation 3Q-16 2" LDT-CNT-NGT (Porosity) 3Q-16 5" Long Spacing sonic - GR 3Q-16 5" Electromagnetic Propagation 3Q-16 5" Dual Dipmeter 3Q-16 5" LDT-CNL-NGT (Porosity) 11/15/86 run 1 11/15/86 run 1 11/15/86 run 1 11/15/86 run 1 11/15/86 run 1 11/15/86 run 1 11/15/86 run 1 11/15/86 run 1 11/15/86 run 1 11/15/86 run 1 11/15/86 run 1 11/15/86 run 1 11/15/86 run 1 11/15/86 run 1 RECEIPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO: ATTN: P. Susanne Baxter, ATO-527 P. O. Box 100360 Anchorage, Alaska 99510 ~ ' STATE OF ALASKA ALASKA .~;L AND GAS CONSERVATION COMMIL_,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend - Operation Shutdown ~ Re-enter suspended well ~ Alter casing -_ Time extension ~ Change approved program ~- Plugging '~. Stimulate- Pull tubing- Amend order- Perforate- Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2301' FNL, 1965' FEL, Sec. 17, T13N, R9E, UH At top of productive interval 1354' FSL, 375' FEL, Sec. 17, T13N, R9E, UM(Approx) At effective depth 1179' FSL,. 280' FEL, Sec. 17, T13N, R9E, UM(Approx) At total depth 977' FSL, 114' FEL, Sec. 17, T13N, R9E, UM(Approx) 5. Datum elevation (DF or KB) 60 'RKB feet 6. Unit or Property name Kuparuk River Unit 7. Well number 30-16 8. Permit number 86 -179 9. APl number 50-- 029-21667 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 7300 'HD true vertical 7169 'TVD Effective depth: measured 7189 ' MD true vertical 6669 'TVD Casing Length Size Conductor 80' 16" Surface 3894' 9-5/8" Production 7242' 7" feet feet feet feet Perforation depth: measured None Plugs (measured) None Junk (measured) None Cemented Measured depth Conductor Report not Received 1200 sx AS III & 250 sx Class G 300 sx Class G true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 1lO'MD 3929'MD 7277'MD ~ue Vertical depth 110'TVD 3750'TVD 6747'TVD , .. 12.Attachments Well History Description summary of proposal ~ Detailed operations program _% BOP sketch 13. Estimated date for commencing operation January, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed & ~ .~/~j~~ Title Associate Engineer ~ Commission Use Only ( DAM) Conditions of approval Approved by Date /~-/~-~____~ SA/183 Notify commission so representative may witness -- Plug integrity -- BOP Test -- Location clearance . . Commissioner IApproval No. ¢ 7 ,. . ..... ., ,--~.,~_.J-~. ~.-~,,~,,,,,,"~.'~ by order of the commission Date /4. 7 Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company ~, Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" 0,3 the first Wednesday after a ,,veil is spudded or ',vorkover operations are started. Daily work prior to spudding should be summarized or] .'.he form giving inclusive dates only. District Field Auth. or W.O. no. AFE AK1703 Coumy. parish or borough IState Alaska North Slope Borough Alaska Lease or Unit Well no. Kuparuk River ADL 25512 3Q-16 Tte Drill Doyon 9 API 50-029-2~SQ~q. Operator ARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun IDate IH°ur IPr °r status if a W'O' Spudded 11/13/86 0300 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 11/13/86 11/14/86 11/15/86 thru 11/17/86 11/18/86 16" @ 110' 489', (374'), Drlg Wt, 8.7, PV 12, YP 16, PH 9.3, WL 17.2, Sol 3 Accept ri~ @ 1900, hfs, 11/12/86. NU diverter. 0300 hfs, 11/13/86. Drl to 489'. Spud well @ 16" @ 110' 2820', (2331'), Drlg Wt.' 9.3, PV 14, YP 24, PM 8.5, WL 18.6, Sol 7 DD & surv to 2820'. 581', 4.0°, S50.9E, 580.91TVD, 5.27VS, 3.35S, 889', 12.4°, S44.4E, 885.30 TVD, 50.89VS, 36.03S, 1192', 20.6°, S42.3E, 1174.64 TVD, 140.21VS, 100.11S, 1855', 2674', 4.12E 35.96E 98.19E 23.8°, S39.2E, 1783.44 T-V-D, 402.24VS, 297.25S, 271.39E 23.4°, S43.2E, 2537.20 TVD, 722.25VS, 534.82S, 486.17E 9-5/8" @ 3929' 5214', (2394'), Drlg Wt. 8.7, PV 7, YP 4, PH 9.0, WL 12.2, Sol 3 Drl to 3940', short trip, wsh & rm f/1850'-2300'. Make wiper trip. RU Schl, rn DIL/SFL/GR/SP/LSS, LDT/CNL/NGT/EPT/CAL w/hi resolution rm & SHDT, RD Schl. RU & rn 97 jts, 9-5/8", 36#, J-55 BTC cst, FS @ 3929 FC @ 3850'. Cmt w/1200 sx AS III, followed by 250 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. ND diverter, NU & tst BOPE. TIH, DO cmt & flt equip. Conduct formation tst to 12.5 ppg EMW. Drl & surv to 5214'. 2831', 19.7°, S43.5E, 2683.23 TVD, 779.91VS, 576.75S, 525.76E 3600', 12.2°, S43.8E, 3427.92 TVD, 969.02 VS, 711.96S, 657.95E 4032', 12.5°, S43.2E, 3850.16 TVD, 1060.31VS, 778.98S, 719.99E 4349', 20.3°, S43.2E, 4154.85 TVD, 1147.11VS, 842.64S, 779.04E 4728', 28.7°, S41.9E, 4498.52 TVD, 1306,01VS, 962.97S, 883.27E 9-5/8" @ 3929' 6900', (1686'), Drlg Wt. 10, PV 16, YP 10, PH 9.5, WL 6.4, Sol 10 Drl & surv to 6900'. 5294', 28.7°, S43.5E, 4994.98 TVD, 1577.70 VS, 1162.728, 1067.60E 5829', 28.1°, S45.1E, 5465.59 TVD, 1832.16 VS, 1344.83S, 1245.32E 6142', 28.0°, S45.9E, 5741.82 TVD, 1979.32 VS, 1447.99S, 1350.29E The above is correct For form preparation and distribution, see Procedures, Manual, Section 10, Drilling, Pagea 86 and 87. IDate / Title Drilling Supervisor ,HCO Oil and Gas Company,~,'~, Daily Wei~ History- Final Report Instructions: Prepare and submit ~:he "Final Report" o¢ the firs; Wednesday after B'io',vab!e has been assigned or ',',et! is Plugged. Abandoned. or Sold. "Final Report" should be submitted also when operations a,e suscer'ded for an indefinCe or aDpreciable length of time. On wor,~overs when an ol/icial test is not required upon oompietion, report completion and represen:ativ'e :est data ;n blccks provided. The "Final Report" form may be used for reporting the entire operation if seace is ava,labie. District JCounty or Parish Alaska Field ~Lease or Uni', Kuparuk River Auth. or W.O. no. ~Title AFF. AK1703 I North Slope Borough Accounting cost center Code State Alaska ADL 25512 Well no. 3Q-16 Drill Doyon 9 Operator ARCO Alaska, Inc. API 50-029-21309 A.R.Co. W.I. 56.24% Spudded or W.O. begun Date Spudded 11 / 13/86 Date and depth Complete record for each day reported as of 8:00 a.m. 11/19/86 11/20/86 11/21/86 I otal number of wells (active or inactive) on this pst center prior to plugging and J bandonment of this well I our I Prior status if a W.O. 0300 hrs. 9-5/8" @ 3929' 7260', (360'), TIH w/DP Wt. 10.1, PV 22, YP 18, PH 9.0, WL 4.0, Sol 12 Drl & surv to 7260', short trip, CBU, TOH. RU Schl, rn DIL/SFL/SP/CAL/GR/FDC/CNL, RD Schl. 6611', 27.7°, S47.0E, 6156.50 TVD, 2198.27VS, 1598.94S, 1509.08E 7185', 27.9°, S38.3E, 6664.90 TVD, 2464.06VS, 1799.43S, 1684.22E 7" @ 7277') 7.~JOl~' , (0'), NU Lower Tree and test Wt. ].0.2~ NACL NU BHA. RIH. Drlg. 7260 - 7300, Circ. & cond. Spot 10% Diesel pill. POH 2/DDP. RIH w/7" csg. 175 jts. FS @ 7277'. FC @ 7190'. Cement w/100 sx 50/50 pozz & 200 sx ~lass G. Disp. w/274 BBL Brine. Bump plugs (3) w/3500 PSI. Floats OK. CIP @ 032 11/20/86 7" @ 7277' 7260' TD, 7189' PBTD, RR 10.2 ppg NaC1 RR @ 1030 hfs, 11/20/86. Old TO J New TD PB Depth I 7260' TD 7189' PBTD Released rig I Oate J Kind of rig 1030 hrs. 11/20/86 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. 'C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature ~ Date -- I Title ~ _ ~.--'~// / ~.-~,..~_~"/o¢"¢ Drilling Supe rvisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 2, 1986 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5838 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3Q-16 OH LIS Tape + Listing 11-18-86 3K-12 OH LIS Tape + Listing 11-11-86 #72087 3895.5-7157 #72055 996.5-7793 Recei pt Acknowl edged' Distribution' state of Alaska · lKKW'pg-0040 (MF) Date- D. Wetherell ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 19, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT. Conductor As-Built Location Plat - 3Q Pad (Wells 1-16) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/dmr Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 8 9 17 16 VICINITY IMP SCALE t I" · 2 IdlLE$ ALL WELLS LOCATED IN SEC. 17, TI:SN, R9E, UMIAT MERIDIAN. a I,,Oa~,,7. soI ~,~, 984.20 $ 16,025,861'28 I 516,~8.42 4 1~,o=~,85~.a~1 ~,~,o~.~ 5 16,025,849.~61 516,056.99 ~ 16,°~s, .~r.~ I ~, ~0~.6~ , 16pas, 8~1.4~ I sl6,1~.Ta ~ I~,Oa~, el~.~1 51~,202.. I0 ~6,025, ~7.25 ~ 51~,226.~ I~ 16,025, 789.31 ~ 51~,299.52 15 /6,025, 777.44~ 16 16,025, T7l."1"6,~.'l LATITUDE NOT~S: I. AU. CO~4e#lA~S M4~ A.S.P., ZC~ 4. 2.AI.L DISTANC(S ~ AI~ $.ELE'MT~S Al~ B.P.M.$.L. 4.1KF. FIELD BOCiK I..N-I~, IN~i 21-22. 5. O. G. ELEVATIONS FROM F. R. BELL & A~X:I&TES. 6.HORIZONTAL PO~ITIOI~ BA,~D ON 1jQ C(~~ I ~/~, ~ IdOKII~NTS PER LHD & AleOC. LONGITUDE 70e 28' 54.758" 1149°52' lO. s12" 70° 2 8' s4.~l" l l4~ s~ c~.798" 7~ 28' 54.639"114~ 52'~.~" 7~ 28' 54.~"114~ 52'08.3T6" 7~ 28' 54.521" 114~52'07.658" 7~ 28' 54.462" I1~ 5Z'06.944" ~ 7~ 28' ~4. ~"11~ ~' 06.220" ~ 7~ 28' 54.34~114~ ~'05.~0" ~ 28'54. I0~" 11~'~.665" T~ 28' ~3.~' 11~5Z'01.2~" 7~ 28' T~ ~' ~. 7~"/14~ 51'5e. I ~.F.~.L.. ! 219t' 23,77' I?.1 2205' 2~' 17.1 221 I' 2S2~' 17. I 2217' 2304' 17.2 2223' 22~' IT.~ 2 2~' 2255' ~. ~ 22~' 2231' 17.3 2241' 220~ 17.4 2~$' 2134' IT. 5 22~' 2110' 17.5 2271' 20~' IT. 5 227T' 2~' 17~ 22i3' 2037' aZif 201~ 22~ 196S' 17~ 2301' 1~65' 17.5 21.? 21.7 21.7 Zl.e 21.e 22.0 21.! 21 .'~ 21.0 21.9 21,,~ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED ANO LICENSED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY M[ OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 11/2/86. WELL CONDUCTOR ASBUILT I 1 """ i c...,, 1 0.~, ,,/,o/# INs, I. ~,7.,~ . I October 31, 1986 Mr. J. B. Kewin Regional Drilling Engineer A_P. CO Alaska, Inc. P. O. Box 100360 ~chorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kupartd~. River TJnit 3Q- 16 ARCO Alaska, Inc. Permit No. 86-179 Sur. Loc. 2301'F~, 1965'FEL, Sec.17, TI3N, R9E, UM. Btmhole Loc. 1238'FSL, 261'FEL, Sec.17, TI3N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for per-mit to drill the above referenced well. The permit to drill does not indenn%ify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field v~ork, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. ; i/1 : C. V. Chatt'er~on Chai~an o f Alaska Oil and Gas Conservation Co~ission BY ORDER OF ~E COI~4iSSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Enviro~nnental Conservation w/o enc!. Mr. Doug L. Lowery STATE OF ALASKA ALASKA C _. AND GAS CONSERVATION COi~,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [~¢x Redrill DJ lb. Type of well. Exploratory Fl, Stratigraphic Test © Development Oil/k~ Re-Entry ~ Deepen []J Service '~ Developement Gas © Single Zone~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 60', PAD 23' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oi 1 Pool P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25512 ALK 2553 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2301 'FNL, 1965'FEL, Sec.17, T13N, R9E, UM Kuparuk River Unit 5tatewide At top of productive interval 8. Well nu .mber Number 1354'FSL~ 375'FEL, Sec.17, T13N, R9E, UM 3Q-16 ~f8088-26-27 At total depth 9. Approximate spud date Amount 1238'FSL, 261'FEL, Sec.17, T13N, R9E, UM 11/03/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in pr(~perty 15. Proposed depthIMDandTVU/ property line Oliktok Point #1 7216'HD feet 261' ¢ total death feet 652' ¢ surface feet 2560 f6713'TVD~ 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depths00 feet Maximum hole angle 1 2 0 Maximum surface 2229 psig At total depth (TVD) 3330 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) 911,, 15,, ~o ~# u_l,n '"C] ~ ................ C, 8-1/2" 7" 26,0# J-55 BTC 7182' 134' 34' 7216' 6713' 200 sx Class Gfminimum HF-ECW TOC 5(10' abov top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor REI:EIVED Surface Intermediate Production OCT 2 9 1986 Liner Alaska 0il & Gas Cons. C0mmissi0rt Perforation depth: measured Anch0rag~ true vertical 20. Attachments Filin~t fee~ Property plat ~ BOP Sketch ~DiverterSketch ~ Drilling program.~.'" Drilling fluid program ,~,._~ Time vs depth plot [] Refraction analysis ~ Seabed report ~ 20AAC25.050 requirements 21. I hereby certif¢/tl~at the foregoing is true and correct to the best of my knowledge / Signed/ ~'"-5" ~'7/~ ,¢] ../~.¢.~/,~ ~~4.~,¢¢~,.(,~/,, Title Regional Dril 1 ing Engineer Date Commission Use Only ( HRE ) PD/01 2 ,/ / Perm t Nu.mb'~r APl number ' -7 Approval date See cover letter - I - c. '? I 10/31/_86 .,] for other requirements Conditions of approval Samples required [] Yes ~,No Mud Icg required ,_! Yes '~ No Hydrogen sulfide measures ~ Yes ~ No Dir,,ectio/n~l survey required /~xYes ~ No/ \ ' Required working,,,pr.~ssu~f~ .~__~2. M~ ~,3M; [] 5M; [] 10M; © 15M Other: / Z..~,///' .,/'/ // //~....~--~ / ~ by order of Approved by< (~/~, (% ~¢,~~ Commissioner the commission Date~_,~.~~ Form 10-401 Rev. 12-1-85 SL triplicate KUPARUK F[ELD,i NOETfl St~OPE.,_ · 7OO11 PER, 100 FT ~1 EOC ,~ TvD-t 252 TMD=I .. AVeRAgE DEG,- AN _~LE 11 !.MIN- --~ANGLf:, DROP_ "TV~TI'ID~~-~ T/ UeHU SNDS TVD=2EHO Tt'lD=2?50 DEP=?3S 1S i*t't.K ~ue ~i i ........ END; ANGLE DROP TVI~=32g$ TMD=3469 DEP=SISO ~ T/ g SAK SND9 TVD.-3320 T1~=~495 DEP-9,56 AVERAG~.ANP.&E. :--- 1{'~2~T,VD~~~374-~DEP.1007 9 $/~'!C$G PT TYD-3760 Tt'ID-3944 DEP-'t049 1 2 DEG KOP TYD=390T Tt,~.4094 DEP, 10~0 BUILD 3- DEG'PER 100. FT EOC TVD.~4~?6 TIND-4594 DEP- 1246 ................ ~ _ A. VE RAC. E_~J~D:~J_E 'p,E£EiYED ~ T/ ZONE C TVD-6393 TIID=6857 DEP"2273 'k T/ :ZONE A TVD'6439 THD"690g DEP=2296 - * ' '"-~ ~'-- TARGET'--CNTR TVD"6487 TMD'6962 DEP'2321 ~ B/ KUP SND~ TVD-6535 TMD-?O16 DEP-2345 TD (LOG PT) TVD-6?13 TMD-?216 DEP-2436 1 000 2000 3000 VERTtCAL SECT tON . HOR I ZON ]E..AL .... P.P~OJEC. Ti ON ...... i .................. SCALE I IN. = l O01!l FEET 1 , , : U AR K [ LD,'NOR HjSLOPE*.' ALtSKA ~ooo p ooo ~ooo S~A~ L~:ATI~ ~1.' FNL.:,,,' ~L ' 2-000 2~4oo _ _ 2GIIO_. _ 2700. _ i t ~2123 \ / J--- / / ....... I ._ / it 2300 22OO _ 27 O0_. 21 O0 2000 t 900 1 800 1700 KUPARUK R I VER UN I T 20" D I VERTER $CHEM~T I C , DESCR I PT I ON ii 1, 16" CONDUCTOR, 2, TANKO STARTER HEAD. 3, TANKO SAVER SUB, 4, TANKO LONER QUICK-CONNECT ASSY, S, TANKO UPPER QUICK-CONNECT ASSY, 6, 20" 2000 PSI DRILLINQ SPOOL N/JO" OUTLETS, 7, 10" i.-ICR BALL VALVES N/JO" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOHNHIND DIVERSION. 20" 2000 PSI ANNULAR PREVENTER. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC25.035 (b) MR I NTENRNCE & OPERAT I ON i 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLON A I R THROUGH O I VERTER L I NES EVERY 12 HOURS. 3, CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF NELLBORE FLUIDS OR ~AS IS DETECTED, OPEN APPROPRIATE VALVE TO ACHIEVE DONNNIND DIVERSION, DO NOT SHUT IN NELL UNDER ANY C I RCUMSTRNCE$. mm i S 1(X)84002 RIO < < L DIAGRAM #1 13-5/8" ,5~ PSI RSRRA BOP STACK ~ I. 16" - 2000 PSI TAPCO STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. II" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8' - 5000 PSI DRILLING SPOOL W/CHOKE A~D KILL LI~ES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/PIPE RAMS ON TOP, BLIN3 ~ ON BOTTGvL ?. 13-5/8" - 5000 PSI A~ ACCLIVlJLATOR CAPACITY TEST 1. CHECK A~D FILL ACOJVlJLATDR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCLIV~TOR PRES~ IS 3000 PSI WITH 1500 PSI DOM~TREAM OF THE REGJLATOR. 3. OBSERVE TIh~, THEN CLOSE ALL UNITS SIMULTA~OI~Y At~D RECORD THE TIh~ A~D PRESSURE RE)V~AINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PLIVP OFF. 4. RECORD ON NADC REPORT, THE ACCEPTABLE LO~ LIMIT IS 45 SECOI~ CLOSING TIE A~D 1200 PSI REMAINING PRESSURE. F I 2 13-5/8" BOP STACK TEST FILL BOP STACK A~ Q--K~KE MANIFOLD WITH ARCTIC DIESEL. CHECK THAT ALL LOCK EX~ SCRE~ IN I~ELLI-F_AD ARE FULLY RETRACTED. SEAT TEST PLUG IN WEi_L~ WITH RUINING JT AI~ RUN IN LO(~ SCREWS. 3. CLOSE AI~ PREVENTER A~D MANUAL KILL A~D CHOKE LI~E VALVES ADJACEhrr TO BOP STACK,. ALL OTHER VALVES AhD CHOKES SHOULD BE OPEN. 4. PRESSURE UP TO 250 PSI Ahl] HOLD FOR I0 MIN. IN- CREASE PRE,S~ TO 3000 PSI AhD HOLD FOR I0 MIN. BLEED PRESSURE TO 0 PSI. 5. OPEN ~ PREVENTER AhD MANUAL KILL AhD CHOKE LIhE VALVES. CLOSE TOP PIPE RAMS AhD HCR VALVES ON KILL AhD CHCKE LIHES. 6. TEST TO 250 PSI AhD 3000 PSI AS IN STEP 4. ?. CONTINUE TESTING ALL VALVES, LIhES, A~D CHCKES WITH A 2.50 PSI LOW Ahi) 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHCKE THAT IS NOT A FULl, CLOSING POSITIVE SEAL CHOKE. ON_Y FUNCTION TEST CHOKES THAT DO NOT FULLY CLOSE. 8. OPEN TOP PIPE RAMS AhD CLOSE BOTTCM PIPE RAMS. TEST BOTTCM PIPE RAMS TO 250 PSI AhD 3000 PSI. 9. OPEN BOTTCI~ PIPE RAMS, BACK OUT RUklqING JT AhD PULL OUT OF HOLE. I0. CLOSE BLINO RAMS AhD TEST TO 250 PSI AhD 3000 PSI. II. OPEN BLIhD RAMS AhD RETRIEVE TEST PLUG. MAKE SURE MANIFOLD AhD LIKES ARE FULL OF NON-FREEZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAhDPIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, ANO INSIDE BOP TO 250 PSI AhD 3000 PSI. 13. RECCRD TEST IhFORMATION ON BLOWOUT PREVENTER TEST FC~, SIGN, AhD SF_I~ TO DRILLING SUPERVISOR. 14. PERFORM CGVI~LETE BOPE TEST AFTER NIPPLING UP ANO WEEKLY THEREAFTER FUNCTIONALLY OPERATE BOPE DAILY. 510084001 REV. 2 MAY 15, 1985 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LWK5 / ih GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. ~ 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and-test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. i3. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE SHAKERS HUD CLEANER --w. STIR _ OCT Z 9 1986 Naska 0il & Sas Cons. C0mm[ssi0. -I~ ,STIR CENTRIFU6EI TYPICAL MUD SYSTEM SCHEMATIC LWK4 / ih LtST FOR NZW rC MtZS I'iZM APPROVE DATE (2) Loc (2' thru 85 (3) Adnttn t ~jl~i~, 9. 13), /~ 10. , /)/..?//.~, 11. (10 and 139 / 12. 13 (4) Casg ,/~,~ (14 thru 22) (5) BOPE (23 thru 28) (6) OTHI~ j/. ~, (29 thru 31) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company.. /~CO j~-(~J,~"'~, .T.,,.% Lease& Is the pe~t fee attached .......................................... ~ Is well to be located in a defied ~ol ........... ] ~ . ...... Is well located proper distm~ce fr~ p~op~Kt~m . ... ..... ~__.. Is ~11 located proper distm~ce fr~n ~~ ~I1~ 7~ .............. Is s~ficient ~dedicated acreage available in this ~1 ............ . Is ~11 to be deviated and is ~llbore plat included ................ ~ Is operator the only affected party .................... Can pen~&t be approved before fifteen-~ny wait ...................... ~ ~es operator have a b~d in force .................................. ~ Is a conse~ation order needed ................................. ' ..... Is ac~istrative approval needed ................................... Is the lease m~er appropriate ..................................... ~ ~es the ~11 ~ve a ~i~e nm~ and n~er .... Is con~ctor string pr~ided ........................................ ~ Will surface casing protect fresh mter zones ....................... ~ Is enough c~mnt used to circulate on conductor and surface ......... ~ Will cennnt tie in surface and inten~mdiate or production str~gs ... ~ Will ce~mnt cover all ~~ productive horizons ..................... ~ Will all casing give adeq~te safety ~ collapse, tension ~d b~st.. ~ Is this ~11 to be ~cked off fr~ ~ ~isting ~llbore ............. Is old wellbore abandom~nt procedure included on 10-403 ............ Is adequate ~llbore separation proposed ............................ ~ For 29. 30. 31. Is a diverter system required ....................................... Is. the drilling fluid program schen~qtic and list of equipment adequate Are necessary diagrmns and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to .~OD psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis clxta presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented · Additional requirements ............................................. Geolo_~: Engineering: JAL rev: 07/18/86 6. 011;!.~ ~ , ',~.' , ,: ~. ~,.,,...~ ,,.:..:.: ~ , ,' ,.,, , ,~!,~,,: :...~... ,: '":: :7 '. 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