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Home My WebLink About198-111WELL LOG TRANSMITTAL #905514153 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVE MAY 15 2019 RE: Leak Detect Log: 1D-134 AOGCC Run Date: 3/5/2019 1901 j1 30724 May 13, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS ANC@halliburton.com 1D-134 Digital Data in LAS format, Digital Log file 1 CD Rom 50-029-22892-00 `if(.IhLNII (yU.�. IV ��C C_PS,e,,1 ' Z l:ii j j� GYMS PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: V (�I �� Signed: ZiURFERSEDEDL LOG TRANSMITTAL #905514153 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 1D-134 Run Date: 3/5/2019 1981 11 30 72 4 April 30, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1D-134 Digital Data in LAS format, Digital Log file 50-029-22892-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com RECEIVED MAY 0 8 2W AOGCC Date: Signed: VS -11. PmAcTivE DiAgNosTic SERVICES, INC. WELL LOG TRANSMITTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue 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 : 1) Caliper Report 2) Signed Print Name: ProActive Diagnostic Services, Inc. Attn: Diane Williams 130 West International Airport Road Suite C Anchorage, AK 99518 pdsanchoraaeo-memorvlop com RECEIVED MAR 2 2 2019 AOGCC 22 -Feb -19 1D-134 1 Report /CD 50-029-22892-00 1981 11 30486 Date: 2"/ o PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)2458952 E-MAIL: PDSANCHORAGEGDMEMORYLOGCOM WEBSITE: WWW.MEMORYLOG.COM D:':Achives\M1faskYfemplateFtilex\Template\DistribuRon;TransmitfalShaeti ConoarPlWlipa Trznsmi[doez 198111 Memory Multi -Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1D-134 Log Date: February 22, 2019 Field: West Sak Log No.: 14369 State: Alaska Run No.: 1 API No. 50-029-22892-00 Pipe Description: 3.5 inch 9.3 Ib. L-80 EUE 8RD MOD Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 5,453 Ft. (MD) Inspection Type: Corrosive and Mechanical Damage Inspection COMMENTS: This caliper data is tied into the top of GLM 3 at 5,344 feet (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage prior to patching operations. The caliper recordings indicate the 3.5 inch tubing logged appears to range from good to poor condition with multiple possible holes in joint 105 (3,326 ft) and a possible hole in joint 136 (4,266 ft). Additional wall penetrations ranging from 20% to 75% wall thickness are recorded in 67 of the 185 joints logged. Recorded damage appears as deep isolated pitting and a line of pits. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. A 3-D log plot of the caliper recordings from 3,000 feet to 4,500 feet is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: MultiplePossible Holes 89 105 3,326 Ft. (MD) Possible Hole 85 136 4,266 Ft. (MD) Line of Pits 75 134 4,211 Ft. (MD) Line of Pits 75 133 4,173 Ft. (MD) Line of Pits 75 117 3,687 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 9%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. C. Goerdt C. Waldrop S. Ferguson ProActive Diagnostic Services, Inc. / F.O. Box, 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 F -mail: PDSAnalysis@memorylog com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 I "�"' I I :N Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (40.6-5,4527) Well: 1D-134 Field: West Sak Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: February 22, 2019 ■ Approx. Tool Deviation ■ Approx. Borehole Profile i 44 25 776 50 1,546 75 2,312 Ll GLM 1 Z' GLM 2 2 a p —' 100 3,158 25 3,927 150 4,691 GLM 3 172.2 5,443 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 172.2 ts� Well: ID -134 Field: West Sak Company: ConocoPhillips Alaska, Inc. Country: USA Pipe 3.5 in. 9.3 ppf L-80 EUE 8RD MOD PDS Report Overview Body Region Analysis Survey Date: February 22, 2019 Tool Type: UW MFC 24 No. 214320 Tool Size: 1.69 inches No. of Fingers: 24 Analyst: Waldrop Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 DDf L-80 EUE 8RD MOD 2.992 in. 41 ft , 4,1 ft Damage Configuration (body) Ev M. 40 20 0 Isolated General Line Other Hole/ Pitdng Corrosion Corrosion Damage Pos. Hole 18 0 62 0 2 Damage Profile (%wall) Penetration body Metal loss body 0 50 100 GLM 1 (4:30) GLM 2 (11:00) GLM 3 (3:00) Bottom of Survey = 172.2 Penetration (%wall) 150 100 50 0 0 to 20% 20 to 40 to over 40% 85% 85% Number of ioints analy7 116 29 38 2 Damage Configuration (body) Ev M. 40 20 0 Isolated General Line Other Hole/ Pitdng Corrosion Corrosion Damage Pos. Hole 18 0 62 0 2 Damage Profile (%wall) Penetration body Metal loss body 0 50 100 GLM 1 (4:30) GLM 2 (11:00) GLM 3 (3:00) Bottom of Survey = 172.2 Ji4-S Well: Field: Company: i D-134 West Sak ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: February 22, 2019 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 FUE 8RD MOD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 41 ft 5,453 ft. Joint )t. Depth Pen. No. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments 0 Damage Profile (% wall) 50 100 0.1 41 0 0.03 11 4 2.95 Pu 44 0 0.04 17 2 2.91 Shallow Line of Pits. Lt. Deposits. 2 75 0 0.01 5 1 2.94 3 106 0 0.02 7 3 2.92 Lt. De osi s. 4 135 0 0.02 8 2 2.92 Lt. Deposits. 5 166 0 0.01 5 1 2.92 Lt. Deposits. 6 197 0 0.01 5 1 2.93 Lt. Deposits 0 0.02 2.92 . De osits. 258 0 0.02 8 2 2.94 0 0.01 1 2. 2 sits. 319 0 0.02 7 1 2.92 Lt. De o. its. 350 0 0. 1 i1 2. . De osits. J7227 1 0 0.01 6 1 2. 3 e osits. 412 0 0.02 7 2 2.93 442 0 0.02 1 2. t. De osits. 47 0.01 5 1 2.93 osits. 504 0 0.01 4 1 2.92 Lt. Deposits. 17 534 0 0.02 7 1 2.93 Lt. DeDosits- 18 565 0 0.01 5 2 2.93 19 596 0 0.01 5 2 2.93 Lt. Deposits. 20 627 0 0.01 5 1 2.93 Lt. Depo its. 21 657 0 0.02 6 1 2.93 22 687 0 0.01 6 3 2.93 Lt. De osits. 23 718 0 0.01 5 2 2.93 L. Deposits. 24 748 0 0.01 5 1 2.92 Lt. Deposits. 25 778 0 0.02 6 2 2.93 Lt. De osits. 26 809 0 0.01 5 2 2.93 27 839 0 0.01 6 1 2.94 28 870 0 0.01 5 2 2.92 Lt U=osits. 9 901 0 0.02 6 2 2.92 Lt. Deoosits. 30 932 0 0.02 1 7 1 2 2.93 Lt. Deposits. 1 962 0 0.01 5 1 2 2.93 Lt. Deposits. 32 993 0 0.02 7 2 .9 Lt. e si s. 33 1024 0 0.02 6 2 2.93 Lt. Deposits. 4 1 5 0 0.02 7 2.93 osits. 35 1085 0 0.01 5 1 .93 Lt. sits. 36 1115 0 0.02 7 3 2.92 Lt. Deposits 37 114 0.01 4 1 2.92 Deposits. 38 1177 0 0.02 9 3 .92 Lt. Deposits. 39 1208 0 0.01 6 1 2.92 Lt. Deposits. 4 12 0 0.01 5 2 2.93 Lt Deposits. 41 1269 0 0.01 5 2 1 2.93 Lt. Deposits. 42 1300 0 0.02 7 2 2.92 Lt. Depsits. 43 1331 0 0.01 5 1 2.22 1 Lt. Deposits - 44 1362 0 0.01 6 2 2.93 1 Lt. De sits. 5 1392 0 0.01 5 1 2.92 Lt. Deposits. 14 0.01 4 1 2. Lt. Deposits. 1454 0 0.01 5 1 2.92 Lt. De osits. 1484 448 0 0.01 6 1 3 Lt. De si .1519 0 0. 1 5 1 2. 3 t. osits. Penetration Body Metal Loss Body Page 1 ji-�sPDS Well: 1 D-134 Field: West Sak Company: ConocoPhillips Alaska, Inc. Report Joint Tabulation Sheet Survey Date: February 22, 2019 Analyst: Waldrop Pipe Descripdon 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 41 ft 5,453 ft. Joint Jt. Depth No. (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen, % Metal Loss % Min. I.D. (in.) Damage Profile Comments (% wall) 0 50 100 51546 0.02 6 2 2.93 Lt. Deposits. 51 1577 0 0.02 8 1 2.91 Lt. DeDOSIN. 52 1606 0 0.02 6 1 2.93 Lt. Deposits. 53 1636 0 0.01 4 1 2.92 U.75eposits. 54 1667 0 0.02 7 2 291 Lt. osits. 55 1698 0 0.02 6 1 2.93 1 Lt. De osits. 6 17 02 7 2 2 93 Lt. DepQsits. 7 1760 0 0.02 6 1 2. 2 Lt. De it . 58 1790 0 0.02 7 2 2.92 Lt. Deposits. 59 1821 0 2 8 4 Lt. its. 60 1852 0 0.02 7 1 2.92 Lt. Deposits. 61 18 2 0 0.0 8 2.91 Lt. s. 191 2 0 0.01 5 1 2. Lt. Deposits. 63 1943 0 0.02 7 1 2.93 Lt. Deposits. 4 1974 0 . 1 5 1 2.92 Lt. Deposits. 65 2004 0 0.0 11 2. 2 Lt. De . 66 2035 0 0.02 6 1 2.93 Lt. Deposits. 7 2066 0. 2 7 2. 2 L De i s 6 0 7 0 0.02 1 2.91 t. e osi s. 69 2128 0 0.03 13 2 2.91 Lt. De osits. 7 2158 0.02 9 2 2. t. De osi 71 2189 0.02 7 1 2.92 t. De osits. 72 2220 0 0.02 1 2.93 Lt. Deposits. 7 2250 0 0.02 7 2 2. 1 Lt. De si 74 81 0 0.02 7 2 .92 t. Deposits. 75 2312 0 0.02 9 1 2.91 Lt. Deposits. 2342 0 0.03 10 1 2.92 Lt. e osits, 77 2373 0 0.04 15 1 2.92 Shallow Pittin . Lt. De os its. 8 404 0 0. 2 6 1 2.9 Lt. Deposits. 7 2434 0.04 14 2 2.93 t. Deposits, 80 2465 0 0.03 11 6 2.92 Lt. Deposits. 1 2494 0 0.02 8 2 2.92 Lt. De o. 2 2525 0.03 12 3 2.92 I. Deposits. 83 2556 0 0.03 11 3 2.92 Lt. De osits. 84 2587 0 0. 13 22. 2 t. e s. 85 2618 0 0.03 13 2 2.93 Lt. De osit . 86 2649 0 0.06 22 3 2.91 Isolated Pitting, Lt. De osits. 87 2679 1 0 6.04 15 1 2.93 Shallow Pi On . Lt. Deposits. 88 2710 0 0.04 15 1 2.92 Sh Ilow Pittinsz. Lt. D sits. 89 2741 0 0.08 30 2 2.93 Isolated Pitting. Lt. Deposits. 90 2772 0 0.12 47 2 2.92 Isola[ d Pitting. I L Deposits. 91 2802 0 0.04 14 3 2.93 I.t. osits. 91.1 2832 0 0.07 28 4 2.93 PuQ Isolated Pitting. 91.2 2842 0 0 0 0 2.90 GLM 1(LATCH 44-30) 91.3 2849 0 0.02 8 4 2.93 Pup Lt. Deposits. 92 2859 0 0.03 12 6 2.93 Lt. Deoosits. 93 2890 0 0.02 7 1 2.92 Lt Deposits. 94 2921 0 0.01 6 1 2.93 Lt. Deposits. 94.1 2952 0.0 1 .92 Puu Shallow Pitting. Lt. D2posits. 94.2 1 2967 2.91 ESP FEFD THRU PACKER Penetration Body Metal Loss Body Page 2 Ji -4s PDS Report Joint Tabulation Sheet Well: 1D-134 Survey Date: February 22, 2019 Field: West Sak Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description 3.5 in. 9.3 ppf L-80 EUE BIRD MOD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 41 ft 5,453 ft. Joint No. Jt. Depth (Ft) Pen. Upset (in.) Pen. % Metal Loss % Min. I.D. (in.) Damage Profile Comments (%wall) 0 50 100 4.3 2 0 19 3 .94 u Shall w Line of Pits. 5 2977 0 22 2 1 Line of Pits. t. Deposits. 96 3008 0 23 2 2.92 Line of Pits. Lt. De osits. 0 30 JB 2.92 i of Pits. e osit .97.1 3069 0.05 38 5 1 Pu ine of Pits. t. a osits. 79 0 0 0 2.88 GLM 2 LATCH & 11 :0030(1.10 46 2. 1 Pu ine of Pit . . De o s. 98 8 2 2.92 Line of Pits. Lt. De its. 99 47 3 2.92 Line of Pits. Lt. De osits. 100 45 4 2. Line of Pits. Lt. osits. 101 7 53 4 2.93 Line of Pits. 102 g328OO 4 0.1 51 4 2.92 Lin Pits. Lt. Deposits. 103 0.15 60 4 2. Line of Pits. Lt. Deposits. 104 0.14 56 5 2.92 Line of Pits. Lt. De osits. 105 0.23 89 6 2. 1 Multi I Possibl oles! Lt e osits. 1060.17 8 5 2.92 Line of Pit, I t. De sits. 107 1 3372 0.05 1 0.12 49 4 2.93 Line of Pits. Lt. Deposits. 108 1 3404 0.110.76 3 4 2.93 Line of Pits. It. Deposits. 109 3434 0.07 0.1 51 5 2.92 Line Qf Pits. Lt. De osits. 110 1 3465 0 1 0.10 39 3 2.91 Line of Pits. Lt. Deposits. 111 34 6 0 0.10 2 2.92 solated Pitting. Lt. sits. 11 352 0 43 4 2.93 Lint Qf Pits. 113 3557 0 0.07 29 4 2.93 Isolated Pittin Lt. Deposits. 14 1 3588 0.05 0.14 55 3 2.92 Line of Piti. Lt. De it . 115 1 3619 0.06 0.12 48 4 2.91 Is ted Pilling. Lt. Deposits. 116 L3650 0 0.19 74 4 2.93 Line of Pits. 117 1 3680 0 0.19 75 4 2.92 Line of Pits. Lt. Deposits. 118 1 3711 0 0.10 38 3 2.92 Isolated Pitting. Lt. De osits. 119 1 37420 .11 44 4 2.92 Line of Pits. Lt. De its. 120377 0.04 6 62 4 2. 1 Line of Pits. t. Deposits. 121 3804 0 0.17 68 4 2.92 Line of Pits. Lt. Deposits. 122 3 4 0.05 0.16 63 4 2.92 Line of PiU. Lt. De its. 1 3865 0.06 24 2.91 Isolated Pitting. Lt. Deposits. 124 3896 0.04 0.13 524 2.92 Lin of Pits. Lt. De osits. 125 27 0 .10 2 2.92Line of Pits. Lt. De sAt. 126 3956 0 0.1 50 2 2.91 Isolated Pitting, It. D. 127 3987 0 0.07 28 4 2.91 Isolated Pitting,Lt. Des. 128 41167 0.07 13 5 4 2.93 in of Pi t. Deposits. 129 404 0 .t 49 4 2.93 in Pits. t. e os 130 4079 0 0.16 63 6 2.91 Line of Pits. Lt. Deposits. 131 411 0 0.15 5 4 2.92 Line of Pits. L Deposits. 132 4140 0.05 0. 3 51 4 .92 ine of Pits. t De os 133 4171 0 0.19 75 5 2.93 Line of Pits. Lt. Deposits. 134 4 02 0 0.19 75 5 2.9 Line of Pi . Deposits. 135 4232 0 0.15 58 4 2.91 Line of Pits. Lt. Deposits. 1 4263 0.22 85 7 2. 3 Pos I Hole! De 1 7 4294 0 0.14 6 2 Line of PitsLtD os138 4324 0 0.10 38 4 2.91 Line of Pits. Lt. De os353 0. 4 0.1 57 5 . 1Lin f PitsLt e os140 4 84 0 0.12 46 4 2. Line of Pi . Lt. os Penetration Body Metal Loss Body Page 3 ji4s� PDS Report Joint Tabulation Sheet Well: 1D-134 Survey Date: February 22, 2019 Field: West Sak Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 41 ft 5,453 ft. Joint No. )t. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Damage Profile Comments (%wall) 0 50 100 147 1 4414 1Q44 . 2.92 Line of Pits. . Deposits. 142 4445 0 0.09 6 4 2. 0 Line of Pits. Lt. Denosits. 143 4476 0 0.13 53 5 2.92 Line of Pits. Lt. Deposits. 144 1117 0.0 0.08 0 4 .91 Line of Pits. . Deposits. 145 453 0.04 0.10 38 5 2-93 Line of Pits. Lt. Deposits. 146 4567 0.04 0.11 44 4 2.91 Line of Pits. Lt. Deposits. 147 4598 0.04 0.15 57 5 2.92 Line of Pits. Lt. Deposits. 148 4630 0 7 27 3 2 q9 I inp of Pits. It. Deoosits. 149 4661 0 0.08 30 4 2.92 Line of Pits. Lt. Deposits. 150 46 1 0o n7 27 4 191 Lin f Pits. Lt. Denosit5. 151 1 4722 0 0.06 24 4 2.92 Line of Pits. Lt. Deposits. 152 1 4753 0 0.08 31 3 2.92 Linef Pits. Lt. Deposits. 153 1 4784 0 9 34 4 . 2 Lin f Pits. Lt. -sits. 154 4814 0 0.07 29 3 2.92 Line of Pits. Lt. Deposits. 155 4845 0 0.06 25 4 2.90 LinQ Qf Pits. Lt. Deoosits. 156 4876 0 0.06 24 4 2.91 Line of Pits. Lt. Deposits. 157 4907 0 1 0.06 25 4 2.91 1 Line of Pits. Lt. De -sits. 1 4937 0 5 18 Shall w Line f Pits. Lt. Denosits. 159 4968 0 0.04 14 2 2.93 1 Lt De sits. 160 4998 0 0.04 76 2 2.91 Shallow Line of Pits. Lt. Deposits. 161 5028 0 0.05 19 2. 3 Shal wPitting. Lt. Deposits. 162 5059 0.03 12 2 2.93 Lt. De sits. 163 50901 0 0.03 12 2 2.93 Lt. Deposits. 164 5120 1 0 0. 4 15 2 2. hallow Pitfin Deposits. 165 5150 1 0 0.04 15 2 2.92 Shallow Pitting. Lt. e sits. 166 5181 0 0.03 11 2 2.93 Lt. Deposits. 167 5212 0 0.03 10 2 2.92 t. D sits. 168 5243 0 0.02 9 2 2.92 Lt. Deposits. 1 5273 0 0. 3An t. sits. 170 5303 0.02 9t. De its. 170.1 5334 0 0.04 16u Shallow Line of Pits. Lt. De osits. .2 44 0GLM ATCH :00 170.3 5351 0 0.03 1 u 171 5361 0 0.02 6t De -sits. 7 I A 539 0. 18u allow Lin of Pits. . De osits. 177.2 5396 0 0 0.WET LIFT DISCHARGE GAUGE 171.3 5399 0 2.94 Pu 172 5403 0 2. Lt. Deposits. 172.1 54 3 40394� 2.91 Pu Lt. Deposits. 172.2 5443 0 2.92 Pu Lt. De -sits. Penetration Body Metal Loss Body Page 4 ji: S 1 D-134 Field: West Sak Company: Conoco Phillips Alaska, Inc. Country: USA Tubing: 3.5 in. 9.3 ppf L-80 EUE PDS Report Cross Sections Survey Date: February 22, 2019 Tool Type: UW MFC 24 No. 214320 Tool Size: 1.69 No. of Fingers: 24 Cross Section for Joint 105 at depth 3,326.340 ft. Tool speed = 50 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 95% Tool deviation = 67° Finger = 12 Penetration = 0.225 in. Multiple Possible Holes 0.23 in. = 89% Wall Penetration HIGH SIDE = UP jiS Field: Company: Country: 1D-134 West Sak ConocoPhillips Alaska, Inc. USA 3.5 in. 9.3 ppf L-80 EUE PDS Report Cross Sections Survey Date: February 22, 2019 Tool Type: UW MFC 24 No. 214320 Tool Size: 1.69 No. of Fingers: 24 Cross Section for Joint 136 at depth 4,265.810 ft. Tool speed = 53 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 94% Tool deviation = 46° Finger = 10 Penetration = 0.217 in. Possible Hole 0.22 in. = 85% Wall Penetration HIGH SIDE= UP AjkjKUP PROD WELLNAME 'ID -1% WELLBORE 1D-134 ConoCoPYtillip5 unnouns Mu Angls&MD TD N2WN. hlc. %F. w.m..GnlNn vnwor. vel.. b5N'I uD mxB) Msunpxd NF.SI SAI: 5W}9Y2CJ2Wlti4til E4NU Canm'x Nig pp+nl 5)SY:NUNE 10 aw RnrcNfbn EM du KB -0N lel Ra RMnx do ffiIdIN12 Ldil till. M2NLU1'[ d(el Irl➢G11•J1! +D.v nrraDNer DTAN Leat iaD Ya.:'.+.uY'-Y P¢m9.lmn dgE mm Beale w.Ee¢n I.el we av uv leu-. a.<wu - xxlti Iu.tsE Lws.J N.NoaS.n"- Last Rev Rawson CmfVle W.Fy. 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They are available in the original file and viewable by direct inspection. / ~ ~"- / / / File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: ~'~ [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: Beverly Mildred Daretha(~Lowell Is~ TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Dare~owell Is~ 6<9 \\\I y7 ,� THE STATEZ11 �J F .. u - / * tit - , __ — — — 333 �V S� enih Avenue .-,-,,,:..7-1-70-- ;7, �� i, i L t Ancnora e XcsKQ 9990 521 (r t,RNOR Sl ,,N E rlRNE1,t_ Moir, 507 '//9 1 433 �, w��z,,� 'c r 9 ;/. '101 .4;, MA\( 1620k Martin Walters SC)"0 Well Integrity Project , 1, 1, 1 ConocoPhillips Alaska, Inc. 1 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1D-134 Sundry Number: 314-066 Dear Mr. Walters: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, c'i Cathy P. Foerster Chair DATED this day of February, 2014. Encl. STATE OF ALASKA RECEIVED AL A OIL AND GAS CONSERVATION COMIV. ,ON • • , APPLICATION FOR SUNDRY APPROVALS FEB 0 4 2014 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Ch41,0(3100gram r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: SC Repair r • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r' . 198-111 • 3.Address: Stratigraphic r Service r— 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-22892-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 1 D-134 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025650 • Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6224 ' 4241 • Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121`` 121' 1640 630 is PRODUCTION 6168 7-5/8 6209' 4226' 6890 4790 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5551-5822 • 3586-38493.5 L-80 5455 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-WEATHERFORD HYDROW II DUAL-STRING PACKER MD=2964 TVD=2000 • 12.Attachments: Description Summary of Proposal •Fil 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r— Exploratory r Stratigraphic r Development r • Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/15/2014 Oil J • Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Martin Walters Email: n1878@cop.com Printed Name Martin Walt rs Title: Well Integrity Project Signature „."7---( 1/rPhone:659-7043 Date:2/1/14 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness .3`'-•• O(p(.a Plug Integrity r BOP Test) r Mechanical Integrity Test r Location Clearance r p p Other: }7i)0 0 • D G' U YYl C)'t i- /-� Gt/ ;-. RBDMS� HY e7 2014 Spacing Exception Required? Yes D No Subsequent Form Required: /O _ 4,0 4" U APPROVED BY Approved by: 4,7 Y�Y� COMMISSIONER THE COMMISSION Date: z -.7 -14( pproved appli ation is valid for 12 months from ther date of approval. ',I4 ;44/1 Form 10-403(Revise 10/2012) ORIGINAL 55 L 4j)✓)%S Submit Form and Attachments in Duplicate VLF 21511'4- 9/(P/M ,,Ott"4/ N RECEIVED ConocoPhillips Alaska FEB 0 4 2014 P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 ,„ February 1, 2014 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 1D-134, PTD 198-111 surface casing inspection and repair. Please contact MJ Loveland or me at 659-7043 if you have any questions. Sincerely, /11/(1- /14(117(‘S— Martin /Z Martin Walters ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska,Inc. Kuparuk Well 1D-134 (PTD 198-111) SUNDRY NOTICE 10-403 APPROVAL REQUEST February 1, 2014 This application for Sundry approval for Kuparuk well 1D-134 is for the inspection and repair of surface casing with significant metal loss. During the course of routine work to cut windows and remove cement for application of corrosion inhibiting sealant, it was discovered that this well had approximately 60% wall loss on the surface casing. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with a plug(s)and/or BPV. 2. Remove the floor grate,well house,flow lines,and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and build—9' cellar or excavate if necessary. 4. Install nitrogen purge equipment for the conductor so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection(complete). Remove additional conductor as necessary.Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform MITOA 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s)and/or BPV and return the well to production. 13. File 10-404 with the AOGCC post repair. Well Integrity Project Supervisor 2/1/2014 • . .,, KUP 1 D-134 ConocoPhillips Well Attributes • Max Angle&MD TD Wellbore APW WI Field Na e - Alaska Incme Well Status Incl(°) MD(ftKB) Act Btm(ftKB) Cora,�.Rwkps`.4. 500292289200 WEST SAK PROD 67.99 3,633.30 6,224.0 Comment H2S(ppm) Date Annotation End Dale KB-Ord(ft) Rig Release Date ••• Well Conap -10.131,f0120132.28:24PM SSSV:NONE 10 8/14/2012 Last WO: 4/26/2012 42.41 11/12/1998 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: 5,408.0 6/92006 Rev Reason:PULLED PCESP/SLIP STOP/PACK OFF haggea 6/3/2013 -- Casing Strings HANGER,37 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H-40 WELDED 1 '' Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt String... String Top Thrd PRODUCTION 7 5/8 6.750 40.9 6,209.0 4,226.4 29.70 L-80 ABM-BTC Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth If...Set Depth(ND)...String Wt...String... String Top Thrd TUBING 31/2 2.992 37.1 5,485.4 3,522.4 9.30 L-80 EUE8RDMOD CONDUCTOR, Completion Details 42-121 Top Depth (ND) Top Incl Nomi... 1.1 Top(ftKB) (RKB) 11 hem Description Comment ID(in) 37.1 37.1 -0.63 HANGER VETCO GRAY TUBING HANGER 2.950 ESP 2,964.1 1,999.9 66.68 PACKER ESP FEED-THRU PACKER,WEATHERFORD HYDROW II 2.950 MANDREL,3- -- DUAL-STRING PACKER 5,396.2 3,436.0 14.83 DISCHARGE WELLLIFT DISCHARGE GAUGE UNIT(Sift 12129922) 2.950 111 5,452.9 3,490.9 14.65 INTAKE TTC RECEIVING XO COUPLING w/PERFORATED INTAKE 2.995 (S/N:11990191) III 5,457.7 3,495.5 14.64 SEAL TANDEM SEAL SECTION(S/N:12064708/12064528) PACKER,2,964 - -_J 5,471.5 3,508.9 14.60 GEARBOX GEAR REDUCTION UNIT(S/N:12177753)11.42:1 L_' 111 5,473.3 3,510.6 14.59 MOTOR ESP MOTOR 562MSP1,60 hp/1240V29(S/N:12057557) 5,481.6 3,518.7 14.57 GAUGE WELLLIFT MOTOR GAUGE UNIT(S/N:192-00821) lik5,483.5 3,520.5 14.56 Centralizer MOTOR CENTRALIZER(P/N:C63569) • ertorations&Slots s:, Eel, ESP ( Shot MANDREL-- {! Top(TVD) Btm(TW) Dens 3,077 Top(ftKB)Bbn(ftKB) (ftKB) (ftKB) Zone Date Oh- Type Comment _ 5,551.0 5,576.0 3,585.9 3,610.1 WS D,1D-134 8/14/1998 5.0 IPERF 2 1/8"EJ,0 deg phase/orient,no stim 5,624.0 5,640.0 3,656.6 3,672.3 WS B,1D-134 8/11/1998 5.0 IPERF 2 1/8"EJ,0 deg phase/orient,no slim- . - 5,712.0 5,720.0 3,742.1 3,749.8 WS A3,1D-134 11/9/1998 5.0 APERF 2 1/8"EJ,0 deg phase/orient,no slim ESP .-_ 5,732.0 5,738.0 3,761.5 3,767.3 WS A3,1 D-134 11/9/1998 5.0 APERF 2 1/8"EJ,0 deg phase/orient,no slim MANDREL. -- 5,746.0 5,752.0 3,775.1 3,780.9 WS A3,1D-134 11/9/1998 5.0 APERF 21/8"EJ,0 deg phase/orient,no slim 5.344 I5,766.0 5,769.0 3,794.5 3,797.4 WS A3,1D-134 11/9/1998 5.0 APERF 2 1/8"EJ,0 deg phase/orient,no slim 5,786.0 5,822.0 3,813.9 3,848.9 WS A2,1D-134 8/7/1998 5.0 IPERF 21/8"EJ,0 deg phase/orient,no slim - Notes;General&Safety End Date Annotation 1/7/2006 NOTE:ESP WORKOVER DISCHARGE.__ 5.396 : 5/15/2008 NOTE:Original Rig KB Measurement Parker 245 e 37' 5/152008 NOTE:ESP WORKOVER 6/17/2008 NOTE:View Schematic w/Alaska Schematic9.0 INTAKE,5,453 "' SEAL,5,458 GEARBOX, 5,472 it 'Er: MOTOR,5,473 II 7 =I:,:. NES GAUGE,5,482 Cerbalber, P 5,483 5,5515 IPE,57RF,6 i .,. (PERF, I',I. 5,0245,640 APERF, :'i ScSc 5.7125.720 Ii - APERF. 9 M 5.7325,738 ., V. APERF. 9 Mandrel Detelle 5,7465 r,752 Top Depth Top Port 5... (ND) not OD Valve Latch Size TRO Run N...Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type (In) (psi) Run Date Com... APERF. = = 1 2,839.4 1,950.3 65.99 CAMCO KBMG 1 ESP DMY BK 0.000 0.0 4242012 5,766.5,769 - - 2 3,076.6 2,037.1 65.32 CAMCO KBMG 1 ESP OV BK 0.313 0.0 7/15/2012 3 5,343.9 3,385.5 15.11-CAMCO KBMG 1 ESP SOV -BK 0.000 0.0 9/102012 IPERF. i5,7865.822 PRODUCTION, 415,209N A TO 6224 Page 1 of 2 Schwartz, Guy L (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] Sent: Friday, January 04, 2013 2:42 PM To: Schwartz, Guy L (DOA) 44, Subject: RE: McOH treatments for WS ESP wells f D — / 3'1 Guy to D (1 f - 1.11 There are no changes to surface piping, we would just have a tank on site that a pump truck would tie into and pump directly into the wellhead. There will be a PSV on the pump truck. We can provide a drawing of the wellhead, if that would be of use. All 3 wells have shear out valves below the packer. SCANNED APR 1 1 2013 MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 MJ's Celt (907) 943 -1687 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Friday, January 04, 2013 9:52 AM To: NSK Well Integrity Proj Subject: [EXTERNAL]RE: McOH treatments for WS ESP wells Oh forgot to add that a drawing of the surface piping/ safety valves for the injection system should be submitted to the AOGCC. You could just email them to me. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Friday, January 04, 2013 9:49 AM To: 'NSK Well Integrity Proj' Subject: RE: McOH treatments for WS ESP wells MJ, I don't see any reason for requiring sundry approval or reporting for the methanol operation. With inhibitor added I don't see much risk with corrosion on the casing or tubing in the short term. Just to make sure is there still a shear out valve below the packer for this setup in case the ESP overpressures the tubing if there is a surface shut in? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 1/4/2013 Page 2 of 2 • • From: NSK Well Integrity Proj [mailto:N1878 @conocophillips.com] Sent: Thursday, January 03, 2013 5:33 PM To: Schwartz, Guy L (DOA) Subject: FW: McOH treatments for WS ESP wells Guy, Just following up. Please let me know if we need to provide any specific information or 10- 403/404 for this work. Thank you. MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 MJ's CeII (907) 943 -1687 :egrity Proj mber 16, 2012 3:55 PM L (DOA); 'Regg, James B (DOA)' irity Proj; NSK Problem Well Supv; Patterson, Amanda treatments for WS ESP wells Guy, ConocoPhillips plans to replace the packer fluid in West Sak packer ESP wells with corrosion inhibited methanol for the purpose of injecting daily McOH treatments into the production stream to prevent hydrates and freezing issues. The treatments will be approximately 20 bbls per day and enter the tubing via a bellowed gaslift valve placed above the ESP. Methanol related corrosion concerns will be mitigated with a Baker Hughes corrosion inhibiting chemical. Our plan is to try it on the following wells 1 D -108 (PTD 198 -187), 1 D -113 (PTD 198 -178), and 1 D -134 (PTD 198- 111) — Please let me know if there are any AOGCC concerns or questions with the plan. Additionally please advise if there will be any 10- 403/404 Sundry requirements. Thank you MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 MJ's Cell (907) 943 -1687 1/4/2013 STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other r✓ R 6 ' 1 , 4 47:,444.. Alter Casing r Pull Tubing P Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re - enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 198 - 111 3. Address: 6. API Number: Stratigraphic r Service r" P. 0. Box 100360, Anchorage, Alaska 99510 6 50 - 029 - 22892 - - 0 0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 ° 1D-134 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): . none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 6224 feet Plugs (measured) None true vertical 4241 feet Junk (measured) None Effective Depth measured 6071 feet Packer (measured) 2964 true vertical 4092 feet (true vertucal) 2000 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 PRODUCTION 6168 7.625 6209 4226 scAN4'1EDMA 2 2 ZU1L Perforation depth: Measured depth: 5551 -5576, 5624 -5640, 5712 -5720, 5732 -5738, 5746 -5752, 5766 -5769, 5786 -5822 True Vertical Depth: 3586 -3610, 3657 -3672, 3742 -3750, 3762 -3767, 3775 -3781, 3795 -3797, 3814 -3849 Tubing (size, grade, MD, and TVD) 3.5, L -80, 5485 MD, 3522 TVD Packers & SSSV (type, MD, and TVD) PACKER - ESP FEED -THRU PACKER, WEATHERFORD HYDROW II DUAL - STRING PACKER RECE 1 I 1 NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable miAa..1 2012 ` Treatment descriptions including volumes used and final pressure: A) 3CC 13. Representative Daily Average Production or Injection Data {� (, Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation shut -in Subsequent to operation shut -in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory f Development ('' - Service r Stratigraphic r 16. Well Status after work: ' Oil 1; Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Erik Nelson as 263 -4693 -Printed Name Erik elso,D. Title Wells Engineer Signature , Phone: 263 -4693 s Date 7.:_f:/) IBD1V1 S M AY 2 2 2012 S _ Z2 I ' i��-� Form 10-404 Revised 11/2011 ubmit Original Only KU P • 1D-134 ConocoPhillips 0-4 Well Attributes Max Angle & MD TD Alaska Inc, Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) 500292289200 WEST SAK PROD 67.99 3,633.30 6,224.0 GomoilPhi Nips Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date Well conrg: - 10 - 34, snrzolz 3.1442 PM - SSSV: NONE I 0 8/27/2008 Last WO: 5/15/2008 42.41 11/12/1998 schematic - actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 5,408.0 6/9/2006 Rev Reason: WORKOVER ninam 5/1/2012 - -- Casing Strings HANGER. 37 t- ` Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 5/8 6.750 40.9 1 6,209.0 4,226.4 29.70 L - 80 ABM - BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 37.1 5,485.4 3,522.4 9.30 L - 80 EUE8RDMOD CONDUCTOR, Completion Details . 42 -121 Top Depth (TVD) Top Incl Nomi... El Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 37.1 37.1 -0.63 HANGER VETCO GRAY TUBING HANGER 2.950 ESP 2 1,999.9 66.68 PACKER ESP FEED -THRU PACKER, WEATHERFORD HYDROW II 2.950 MAN 2539 DUAL- STRING PACKER 5,396.2 3,436.0 14.83 GAUGE WELLLIFT DISCHARGE GAUGE UNIT (S/N:12129922) 2.950 5,452.9 3,490.9 14.65 INTAKE TTC RECEIVING X0 COUPLING w/ PERFORATED INTAKE 2.995 (S/N:11990191) • III 5,457.7 3,495.5 14.64 SEAL TANDEM SEAL SECTION (SM:12064708/ 12064528 ) K PACKER, 2,964 4 5,471.5 3,508.9 14.60 GEARBOX GEAR REDUCTION UNIT (S/N:12177753) 11.42:1 J 5,473.3 3,510.6 14.59 MOTOR ESP MOTOR 562MSP1, 60 hp/1240V/29 (S/N: 12057557) '-(/A - /✓ 5,481.6 3,518.7 14.57 GAUGE WELLLIFT MOTOR GAUGE UNIT (S/N:192 -00821) i ll 5,483.5 3,520.5 14.56 Centralizer MOTOR CENTRALIZER (P /N: C63569) Perforations & Slots ESP Shot MANDREL. Top (TVD) Btm (TVD) Dens 3,077 Top (ftKB) Btm MKS) (ftKB) (ftKB) Zone Date (nh... Type Comment __ 5,551 5,576 3,585.9 3,610.1 WS D, 1D- 134 8/14/1998 5.0 IPERF 21/8" EJ, 0 deg phase /orient, no slim 5,624 5,640 3,656.6 3,672.3 WS B, 1D- 134 8/11/1998 5.0 IPERF 2 1/8" EJ, 0 deg phase /orient, no stim 5,712 5,720 3,742.1 3,749.8 WS A3, 1D-134 11/9/1998 5.0 APERF 21/8" EJ, 0 deg phase/orient, no stim ESP 5,732 5,738 3,761.5 3,767.3 WS A3, 1D-134 11/9/1998 5.0 APERF 21/8" EJ, 0 deg phase /orient, no stim MANDREL - 5,746 5,752 3,775.1 3,780.9 WS A3, 10-134 11/9/1998 5.0 APERF 21/8" EJ, 0 deg phase/orient, no slim 5.344 5,766 5,769 3,794.5 3,797.4 WS A3, 10-134 11/9/1998 5.0 APERF 2 1/8" EJ, 0 deg phase/orient, no stim 5,786 5,822 3,813.9 3,848.9 WS A2, 1D- 134 8/7/1998 5.0 'IPERF 2 1/8" EJ, 0 deg phase/orient, no stim Notes: General & Safety End Date Annotation 5/15/2008 NOTE: Original Rig KB Measurement Parker 245 = 37' GAUGE. 5,396 . - ®� 6/17/2008 NOTE: View Schematic w/ Alaska Schematic9.0 INTAKE, 5,453 ■- - SEAL, 5,458 _1 L GEARBOX, v 5,472 MOTOR. 5.473 GAUGE. 5.482 Centralizer, 5,483 / IPERF, - 5,551 -5,576 PERF, 5,82 45,640 APERF, 5,7125,720 APERF, 5,732-5,738 2 APERF, Mandrel Details 5,746 -5,752 Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) (') Make Model (in) Sery Type Type (in) (psi) Run Date Corn... APERF, - = 1 2,839.4 1,950.3 65.99 CAMCO KBMG 1 ESP DMY BK - 5 0.000 0.0 4/24/2012 5.7665.768 2 3,076.6 2,037.1 65.32 CAMCO KBMG 1 ESP DMY BK -5 ' 0.000 0.0 4/24/2012 3 5,343.9 3,385.5 15.11 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 4/24/2012 IPERF, - 5,7865,822 PRODUCTION. 475 -- e• • TD, 8,224 1 D -134 Pre -Rig Work DATE SUMMARY 2/11/12 PRE- RWO - -T -POT (PASSED), PPOT (PASSED), FUNCTION TESTED L 'S 3/30/12 PULLED SLIP STOP @ 5439' RKB. ATTEMPTED PULL PACKOFF @ 544T RKB. IN PROGRESS. 3/31/12 PULLED PACKOFF @ 5447' RKB (MISSING 1/3 OF ELEMEN). DEPLOYED CATCHER. REPLACE SOV © 5268' RKB WITH DV. IN PROGRESS. 4/1/12 BAILED MINIMAL SAND OFF ESP. ATTEMPTED BRUSH FISH NECK ID. CONTINUE UNABLE TO LATCH ESP @ 5386' SLM. IN PROGRESS. 4/2/12 ATTEMPTED BRUSH INSIDE ESP FISHNECK @ 5386' SLM. BAILED MINIMAL SAND FROM PUMP, NO METAL MARKS ON BAILER. IN PROGRESS. 4/3/12 MADE MULTIPLE BAILER AND GAUGE RING RUNS TO ESP FISHNECK @ 5386' SLM. RECOVERED SMALL PIECE OF TEFLON RING. ABLE TO SHEAR DOGLESS GS, BUT STILL UNABLE TO LATCH. RAN 2.5" HYDROSTATIC BAILER TO FISHNECK; RECOVERED - 1/2 CUP OF SAND. IN PROGRESS. 4/4/12 RAN 2.5" HYDROSTATIC BAILER TO ESP @ 5389' SLM. PULLED 35' x 3 1/2" TTC ESP FROM 5455' RKB. PUMPED 55 HOT DIESEL DOWN TUBING AND 190 BBLS HOT DIESEL DOWN I /A. FLUID LEVEL NEXT DAY BOTH AT SURFACE, 50 PSI ON TUB & I /A. INSTALLED BPV ON 4/6. COMPLETE. • • ConocoPhiIIips Time Log & Summary WelMew Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 4/20/2012 8:30:00 AM Rig Release: 4/26/2012 12:00:00 AM Time Logs Date From To Our S. Depth E. Depth Phase Code Subcode T Comment 04/20/2012 24 hr Summary Move off 1D-115. Move over well slot 1D-134. Rig up. Pull BPV. Kill Well. ND Tree. Set blanking plug. NU Weatherford Safety Tensioning Adapter and BOPE. Initial BOPE test 250/3000. 07:30 08:30 1.00 MIRU MOVE MOB P Move Rig From 1D-115 to 1D-134. Load Pits and Spot Cutting Box. 08:30 12:00 3.50 MIRU MOVE RURD P RU Treating Iron to kill tank, Load Pits with KWF. Accept Rig at 0830 hours. Spot MI Shack. RU Hoses in Cellar. 12:00 13:00 1.00 MIRU WELCTI PULD P PJSM. Load Lubricator to Rig Floor and Install same op Wellhead and Pull BPV. 13:00 16:30 3.50 MIRU WELCTL PRTS T Fluid Pack and PT Kill Lines to 250/3000 psi. Open well and get Initial Pressure. ITP= 50 psi. Call DSO and Security to make Notification over field radio. Found Frozen Line at the Rig and Iron going to Kill Tank. Lines Free, Fluid Pack And PT Iron Again to 3000 psi. 16:30 18:00 1.50 MIRU WELCTLCIRC P Start Reverse Circulating 8.6 ppg seawater w/ 3% KCL at 3 BPM. ICP 210 psi to load and kill well. Circulate well until returns are clean. Seeing good 8.6 ppg at surface after 5800 strks (274 bbls). FCP =200 psi. 18:00 18:30 0.50 MIRU WELCTL OWFF P Monitor Well for Flow for 30 Minutes. well on vac. 18:30 19:00 0.50 MIRU WELCTL MPSP P Set BPV. 19:00 20:00 1.00 MIRU WELCTL NUND P PJSM, ND Vetco Gray 3 -1/8" 5M Tree, inspect threads and install blanking plug. 20:00 20:15 0.25 MIRU WELCTI SFTY P PJSM- discussed procedure and hazards of Nipple up of Weatherford Safety Tensioning Adapter and BOPE. 20:15 23:00 2.75 MIRU WELCTL NUND P Nipple up Weatherford Safety Ra` Tensioning Adapter and 11" 5M �f Class III stack with 3 -1/2" Solid Pipe Rams in the Upper Gate and the 2 -7/8" x 5" VBRs in the Lower Gate, connect kill and choke lines. Pagel of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 MIRU WELCTL BOPE P Fill 11" 5M Class III stack and lines with water and RU Test equipment. Held PJSM and Test BOPE at 250 / 3,000 psi. 24 Hr Notice was given at 17:00 hrs on 04 -19 -12 and Right to witness was waived by Matt Herrera at 17:30 hrs on 04 -20 -12 04/21/2012 Complete Initial BOPE test 250/3000. Rig up to pull the 3 -1/2" ESP Completion. Pull Tubing Hanger to Floor. Circulate and condition the hole. Single down the 3 -1/2" ESP Completion. PU and TIH with 7 -5/8" Clean Out (� string. (�\ 00:00 05:00 5.00 MIRU WELCTL BOPE P Continue the initial BOPE Test per ConocoPhillips and AOGCC requirements at 250/3,000 psi. The VB Pipe Rams and the Annular were tested with 3 1/2" Test Joint. Perform Koomey Draw Down Test. All pressure test were recorded on a Chart. Rig down test equipment. 24 Hr Notice was given at 07:00 hrs on 04 -19 -12 and Right to witness was waived by Matt Herrera at 17:30 hrs on 04 -20 -12 05:00 05:30 0.50 COMPZ WELCTL MPSP P Pull blanking plug and BPV, install Side Port Isolation Sleeve. 05:30 07:00 1.50 COMPZ WELCTL CIRC P PU and MU Landing Joint, Floor Valve and Circulating Hoses. Circulate 8.6 ppg filtered KWF down the TBG at 5 bpm, ICP =500 , FCP =500 ( 273 bbls) 07:00 07:30 0.50 COMPZ WELCTL OWFF P Monitor Well for Flow. Load Empty Wooden Spool to Rig Floor for spooling heat trace cable. 07:30 08:00 0.50 COMPZ RPCOM SFTY P Hold PJSM with Vetco Gray, Centrilift and Nordic. Discuss Hazard for Un- landing Hanger and pulling to rig floor. 08:00 09:00 1.00 COMPZ RPCOM PULL P Un -land and pull hanger to rig floor. Took 107k to Un -land. hanging Weight was 105k. 27.7 -ft from mark at rig floor to hanger. Hanger was in good condition, lower o -ring was damaged. UD Hanger and Prep ESP cable and heat trace to spool onto reel. 09:00 17:30 8.50 COMPZ RPCOM PULL P TOOH sideways with 3 -1/2" Completion while spooling up ESP cable and Heat trace and keeping hole full from trip tank. Page 2of7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 19:00 1.50 COMPZ RPCOM PULD P Lay down and secure ESP sensor, seals and motor. Clamp Count Recovered; 3 ea. Prtectolizers 2 ea. 6 -ft Flat Guards 1 ea. Dual Channel Shoe Clamp 42 ea. Single Channel X- coupling 91 ea. Dual Channel X- coupling 1 ea. 3 -ft Mid -jt Dual Channel 2 ea. 4 -ft Mid -jt Dual Channel 454 ea. 5 -ft Mid -jt Dual Channel 19 ea. 1 -1/4" SS Bands 19:00 21:00 2.00 COMPZ RPCOM OTHR P Clean and Clear floors, wrap and secure ESP / Heat Trace spools for off loading. Off load ESP de- completion. Change over floors for clean out run. Set Wear Bushing. Load and talley 4 -3/4" drill collars. 21:00 21:15 0.25 0 0 COMPZ RPCOM SFTY P Hold PJSM with Baker and Nordic. Discuss Hazard for MU and running Clean Out Assembly. 21:15 22:45 1.50 0 760 COMPZ RPCOM PULD P PU MU Clean Out BHA ( #1) 6 -3/4" Tri -tip Cone Bit (Nozzles Pulled), Bit Sub, 17 jts. of 3 -1/2" DP, Double Q Pin Sub, 7 -5/8" Casing Scraper, Bit Sub, Bumper Sub, Oil Jar, 6 jts. of 4 -3/4" DC's. 22:45 00:00 1.25 760 3,809 COMPZ RPCOM TRIP P TIH w/ Clean Out BHA on 3 -1/2" DP to 3.809 -ft 04/22/2012 TIH with Cleanout BHA. Circulate Well clean. Trip out. Lay down BHA. Pick up and RIH with RBP and Test Packer. Test Casing. POOH. Lay down RBP and Test Packer. Pull Wear Bushing. Load, Rack and Tally 3 1/2" TGB. 00:00 01:45 1.75 3,809 5,530 COMPZ RPCOM TRIP P TIH w/ Clean Out BHA on 3 -1/2" DP from 3.809 -ft to 5,530 -ft, attempt to rotate Top Drive into DP, Top Drive not rotating, troubleshoot problem, call out electrician 01:45 02:30 0.75 5,530 5,530 COMPZ RPCOM RGRP T PJSM- Found relay loose from vibration, handler on TD also not working, needs spool valve on TD not on site, can continue safely, manually operating handler on TD. 02:30 03:30 1.00 5,530 5,916 COMPZ RPCOM TRIP P PJSM- Continue TIH with Clean Out BHA, Up wt 118k, Dn wt 70k. no problem thru top perfs, fill encountered at 5,916 -ft, Up wt 130k, Dn wt 75k. 03:30 05:00 1.50 5,916 5,983 COMPZ RPCOM CIRC P Bring on pumps 5 bpm @ 650 psi down tubing, wash down to 5,983 -ft, PUH to 5,950 -ft and reverse circulate 4 bpm at 350 psi until returns clean (208 bbls) Page 3of7 Time Logs • • Date From To Dur S. Depth E. Deoth Phase Code Subcode T Comment 05:00 06:00 1.00 5,950 5,984 COMPZ RPCOM CIRC P Prep for stripping in, reverse circulate 4 bpm at 300 psi, Up wt 145k, Dn wt 73k, cleaning out from 5,950 -ft down to 5,984 -ft (slow pump down to 1 bpm, 70 psi and SO wt of 60k to pass greased tool jt thru bag) hard fill at 5,984 -ft, circulate BU until returns clean. BDTD. 06:00 08:00 2.00 5,984 2,628 COMPZ RPCOM TRIP P TOOH from 5,984 -ft, Up wt 145k, Dn wt 75k, standing back DP to 2,628-ft. 08:00 09:30 1.50 2,628 2,628 COMPZ RPCOM OTHR P PJSM with Crane and Nordic crews, Off load old ESP cable and Heat Trace spools, Load new ESP cable spool. 09:30 11:00 1.50 2,628 0 COMPZ RPCOM TRIP P Continue TOOH from 2,628 -ft , Up wt 73k, Lay down Clean out assy. 11:00 12:00 1.00 0 0 COMPZ RPCOM OTHR P Load RBP and Test Packer, wait on Baker Rep stuck behind Rig move. 12:00 12:30 0.50 0 0 COMPZ RPCOM PULD P PJSM- PU MU 7 -5/8" RBP / Test Packer assembly. 12:30 15:00 2.50 0 5,450 COMPZ RPCOM TRIP P TIH with Test Packer BHA and set_ RBP at 5,450 -ft, Release off and PUH, Up wt 118k, Dn wt 66k. 15:00 18:00 3.00 5,450 5,450 COMPZ RPCOM PRTS P Pressure test 7 -5/8" casing to 1500 psi for 30 minutes, failed 3x, PUH and set Test Packer at 5,440 -ft, Test casing to 1500 psi on chart, good. 18:00 19:00 1.00 5,450 5,450 COMPZ RPCOM MPSP P Realease Test Packer TIH and equalize, release RBP, let relax. 19:00 19:30 0.50 5,450 4,906 COMPZ RPCOM TRIP P TOOH single down 17 joints from 5,450 -ft to 4,906 -ft Up wt 118k, Dn wt 75k 19:30 20:00 0.50 4,906 4,906 COMPZ RPCOM OTHR P Load ESP equipment, Packer and GLM mandrels. 20:00 23:00 3.00 4,906 0 COMPZ RPCOM TRIP P Continue TOOH from 4,906 -ft with Test Packer Assembly standing back DP spliting derrick for next job. Lay down Test Packer BHA. 23:00 00:00 1.00 0 0 COMPZ RPCOM RURD P Pull Wear Bushing, Set Test Plug, RU 3 -1/2" test joint and test Annular 250/3000, good. 04/23/2012 Prep to run ESP completion. PU MU service and TIH with ESP completion. Make Splice at Packer. TIH with remainder of completion to 4,891 -ft due to cable spool short 600 -ft. Contact town engineer. Secure well. Wait on remenant spool and crane. 00:00 01:45 1.75 0 0 COMPZ RPCOM OTHR P Complete Annular test. Pull Test Plug. RD test equipment. Change over floors. Off load Test Packer Assembly. 01:45 02:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM with Centralift and Nordic crews, running ESP procedures and hazards. 02:00 06:00 4.00 0 0 COMPZ RPCOM PULD P PU MU and service Lower ESP completion, connect TEC wire to MGU, MLE to Motor, MEG readings on cable not sufficient, troubleshoot cable. Page 4 of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 10:30 4.50 0 0 COMPZ RPCOM PUTB T Found two bad spots on the ESP cable. Had to cut off the motor head connection and remove 200 -ft of ESP cable and splice another motor head. 10:30 14:30 4.00 0 0 COMPZ RPCOM PULD T Found bad spot in cable, cut 120 -ft plus of ESP cable from spool, hotshot to replacement new MLE, splice new MLE to cable and MEG, all good. 14:30 19:00 4.50 0 2,521 COMPZ RPCOM PUTB P Repaires where made and Cable check out good. Continue in hole with 3.5" completion. 19:00 21:00 2.00 0 90 COMPZ RPCOM PUTB P Connect MLE to motor and check electrical integrity, TIH to DGU and connect TEC wire from MGU, Make cable / motor / gauge electrical integrity checks, good. 2,521 2,521 COMPZ RPCOM PULD P At depth with completion to PU & MU Weatherford Packer. Make ESP cable splice at packer. 21:00 00:00 3.00 90 2,536 COMPZ RPCOM PUTB P TIH with 3 -1/2" completion making electrical integrity checks every 1,000 -ft to 2,536 -ft 00:00 03:00 3.00 2,536 2,536 COMPZ RPCOM OTHR P Make splice at Weatherford Hydrow II Feed -thru packer, electrical integrity check, good. 03:00 07:00 4.00 2,536 4,891 COMPZ RPCOM PUTB P TIH with remaining 3 -1/2" completion making electrical integrity checks every 1,000 -ft to 4,891 -ft, ESP cable Reel #78- 442551 600 -ft short, Confer with town engineer. make calls. 07:00 09:00 2.00 4,891 4,921 COMPZ RPCOM WODL T Wrap and clamp off cable, MU 1 joint 3 -1/2" tubing and stage across BOP, install floor valve for well control. Standby with crews while waiting for remnant cable spool from Y -pad. — 2,000 -ft spool #HD78- 44240 delivered, standby for crane to arrive and swap out spools. 04/24/2012 Wait on crane. Swap out spools. Make splice at 600 -ft. TIH with remainder of completion. MU Tubing Hanger. Make Final Splice. Land Hanger. RILDS.Test Pack -off. RU Slickline. Load IA with Inhibited seawater. Set WRP. Set Packer. 00:00 07:30 7.50 4,921 4,921 COMPZ RPCOM WODL T Continue to standby with crews and wait on crane to swap out ESP Cable spools over well 1D-134. Monitor well on trip tank. Review well program, audit rig for repair and maintenance. 07:30 08:30 1.00 4,921 4,921 COMPZ RPCOM OTHR T Spot crane and Swap ESP spools. 08:30 10:30 2.00 4,921 4,921 COMPZ RPCOM OTHR T Splice ESP power cable at 594 -ft from surface - due shortage on New ESP Cable install. 10:30 11:30 1.00 4,921 5,442 COMPZ RPCOM PUTB P Continue to RIH w/ ESP completion from 4921 -ft to 5,442 -ft Page 5of7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:00 0.50 5,442 5,447 COMPZ RPCOM PULD P PU TBG hanger and Landing joint with side Isolation sleeve, make up to completion string. Lower to rig floor. 12:00 14:00 2.00 5,447 5,447 COMPZ RPCOM OTHR P Install Penetrators and dummy off un -used ports. Space out and make final splice. 14:00 14:45 0.75 5,447 5,485 COMPZ RPCOM HOSO P Land hanger at 100k up wt and 65k down wt at 37.10 -ft ORKB (Parker 245) with tail centralizer at 5,485.43 -ft. Intake at 5,453 -ft. RILDS. 14:45 15:30 0.75 5,485 5,485 COMPZ RPCOM PRTS P PT Hanger pack off seals at 250/5,000 psi for 15 minutes - good test. 15:30 16:00 0.50 0 0 COMPZ RPCOM PULD P Pull landing jt with Isolation sleeve and install full open landing jt. 16:00 16:15 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM with slick line and rig crew on picking up and rigging up Slick line. 16:15 18:30 2.25 0 3,130 COMPZ RPEQP1SLKL P Spot and bring Slick line equipment to rig floor. RU Lubricator and slick line tools to drift and correlate to GLM #2. RIH w/ 2.79" gauge to 3,130 -ft, POOH, RIH w/ 3" KOT and tag GLM #2 at 3,077 -ft, flag wire - POOH, Stand back Slickline lubricator. 18:30 20:00 1.50 0 0 COMPZ RPCOM CIRC P PJSM- RU circ equipment. Reverse circulate 130 bbls corrosion inhibited (CRW -132) filtered seawater, ICP 70 psi, FCP 110 psi. 20:00 23:00 3.00 0 3,118 COMPZ RPEQP1SLKL P PJSM- MU and RIH w/ WRP on Weatherford Slick Pump, Set at, 3,118 -ft, POOH, standback Slickline equipment, Slick pump looks good, off load same. 23:00 00:00 1.00 0 0 COMPZ RPCOM PACK P RU test equipment. Presure up on WRP to 500 psi for 5 minutes, bring pressure up, initial shear at 1,000 t/ psi, second shear in packer setting h sequence seen at 1,900 psi, pressure tubing to 3,250 psi on chart 30 minutes, good, bleed tubing to 0 psi. 04/25/2012 Test IA. Bleed IA per decompression schedule. Set Catcher. Pull DV in upper GLM. Displace IA to Gelled Diesel, TBG to Diesel. Set DV in upper GLM. Test TBG. RD Slickline. Set TWC. ND BOP. Check ESP cable. NU Tree. Test tree and voids. Make final cable checks. Pull TWC. Set BPV. Secure cellar. RDMO 00:00 01:30 1.50 0 0 COMPZ RPCOM PRTS P Line up Test equipment to IA, Pressure test IA against Weatherford Hydrow II Packer to 1,500 psi, lost 65 psi in 15 min and 130 psi in 30 min., Failed, Bump IA pressure back up to 1,550 psi, 15 min IA 1,40 psi, 30 min IA 1,540 psi, pass. 01:30 05:00 3.50 0 0 COMPZ RPCOM OTHR P Bleed IA down following decompression schedule. Page 6 of 7 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 09:00 4.00 0 3,076 COMPZ RPEQPISLKL T RU Slick line and RIH w/ 3" OK -1 & 1.25" JD: Pull DV at 3,076 -ft- POOH due to miss communication. R e run new Dummy GLV in station 2 and POOH. PT at 300 psi for 5 minutes - good test. Redress tool for pulling GLV. 09:00 10:00 1.00 0 2,840 COMPZ RPEQPISLKL P RIH and pull DV #1 from GLM at 2,839 -ft. Stand by for IA displacement 10:00 12:00 2.00 2,840 2,840 COMPZ RPEQPI CIRC P PJSM w/ LRS. RU and reverse circulate 30 bbls of neat diesel and follow with 95 bbls of Gelled Diesel. 12:00 14:00 2.00 0 2,840 COMPZ RPEQP1SLKL P RIH and Set DV #1 in GLM at 2,839 -ft. POOH, 14:00 16:00 2.00 0 0 COMPZ RPEQPI PRTS P RU and PT tbg to 3,000 psi - good test. Conduct negitive test while RD Slick line. 16:00 16:30 0.50 0 0 COMPZ WELCTL MPSP P PJSM- Set TWC 16:30 17:00 0.50 0 0 COMPZ RPEQP1OTHR P PJSM with Crane on conducting critical pick for ESP Spool swap. Offload ESP spool and swap with Empty spool. RD Crane. 17:00 18:00 1.00 0 0 COMPZ WELCTL NUND P PJSM- Nipple down BOPE and Weatherford Safety Tensioning Adapter 18:00 19:00 1.00 0 0 COMPZ WELCTL OTHR P Make ESP cable / motor electrical integrity checks. 19:00 20:00 1.00 0 0 COMPZ WELCTL NUND P PJSM- Nipple up tree 20:00 22:00 2.00 0 0 COMPZ WELCTL PRTS P Pressure test tree 5000 psi 30 minutes on chart, good. Test hanger voids /pack -offs 5000 psi 15 minutes, good. 22:00 22:30 0.50 0 0 COMPZ WELCTL OTHR P Make final ESP cable / motor electrical integrity checks. 22:30 23:00 0.50 0 0 COMPZ WELCTL MPSP P PJSM- Pull TWC and set BPV 23:00 00:00 1.00 0 0 COMPZ MOVE MOB P PJSM- Dress tree, secure cellar, pits clean. Move off well slot 1D-134. Realease Rig at 24:00 Page7of7 • IfVG~~ ~~V ~RA/-r5/1~1TTAL ,,. PROACTive DiAgNOSiic SeevicES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) MTT Report 20,Jun-10 50-029-2292ao1 2) MTT Report 20-Jun-10 1 D-110A 1 Report 1 D-134 1 Report -~. 50-029-22892-00 ~ov-o3`~ i Pfr- ir! RECEIl9~.~ Signed : (~, Print Name: ~IUL 3 0 2010 Date . Ca~nr- ~n PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-WAIL : pdsanchorageCrilmemorylog.com WEBSITE : www.memoryloa.com C:~Documentc and Settings~Diane Williams~DesktoplTransmit_Conoco.doa: • • Memory Magnetic Thickness Tool Log Results Surnrnary Company: ConocoPhillips Alaska, Inc. Well: 1 D-134 Log Date: June 20, 2010 Field: West Sak Log No.: 10642 State: Alaska Run No.: 1 API No.: 50-029-22892-00 Pipet Desc.: 3.5" 9.3 Ib L-80 EUE Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 176 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib L-80 ABM-BTC Top Log Intvl.: Surface Pipet Use: Production Casing Bot. Log Intvl.: 176 Ft. (MD} Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first time this well has been togged with the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total meta! thickness of the 3.5" tubing, 7.625" casing, and 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20 fpm. INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from surtace to 176'. Changes in metal volume are relative to the calibration points at 62' and 92', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 3.5" tubing, 7.625" casing and 16" conductor pipe. A log plot overlay of the average overall metal thickness recorded by 5Hz, 8Hz and 10Hz is included in this report. All three passes indicate a metal loss feature over the interval 51' - 55', with the 5Hz pass indicating up to 7% relative metal loss, the 8Hz pass indicating up to 4% relative metal loss and the 10Hz pass indicating up to 2% relative metal loss. Since the lower frequency magnetic signals are more capable of permeating metal further from the tool than the higher frequency signals, the response from the 5Hz pass is considered to be more representative of the relative overall metal loss from the outer concentric strings} in this interval. A log plot of the entire 5Hz pass is included in this report. Indications of a broad line of isolated metal loss are recorded throughout the interval logged in this plot. An expanded log plot of the 5Hz pass (surface - 32') is included in this report as well. A maximum ~7% circumferential metal loss is indicated in the interval between 51' and 55' in the 5Hz pass. A maximum ^'3% circumferential metal loss is indicated in the interval between 72' and 78' in the 5Hz pass. A maximum -3% circumferential metal loss is indicated in the interval between 111' and 114' in the 5Hz pass. A maximum -3% circumferential me#al loss is indicated in the interval between 118' and 122' in the 5Hz pass. A maximum --3% circumferential metal loss is indicated in the interval between 171' and 176' in the 5Hz pass. ' The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. Field Engineer: G. Etherton Analyst: HY. Yang & J. Burton Witness: 8. Boehme ProActi~~e Diagnostic Services, ?nc. I P,O. Box 1369, Stafford, TX 77497 Phase: ~ %'Bi} or {€?°R} 565-9F:~35 Fax: E2Si} 565-1369 E-mail: Pl?5=~?miernorylog.cam Prudhoe Bay Field Office Phone: (947 } 659-23Q7 Fax: (907} 659-e314 1 ~o-~`~ 4 ~ A o`~~wEt`~ 5Hz, ~ and 1 aHz Delta Metal Thic~ess Passes Overlay Q4 Fc~> 1 D-134 June 2Q, 2Q10 Pn°AcTivE Dinyn°sTic SEHVICFS Database File: d:lwarriorldatal1d-1341overlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Mon Jun 21 11:14:54 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2010 (10Hz) (%) 50 _~_ w _ 50 -50 Delta Metal Thickness 2010 (8Hz) (%) -50 Delta Metal Thickness 2010 (5Hz) (%) 50 0 20 5Hz Delta Metal 40 10Hz Delta Metal ' i 60 Delta Metal Thickness 80 ~-Bottom of 16" Cond i~ i~ A o`~~,wE"s R~rded Magnetic Thickness L~ Data - 5Hz Pass Q~ fc7 F 1 D-134 June 20, 2x10 PROACTIVE ~I~C~YOSTIC ~JERVICfS Database File: d:\warriorldatal1d-13415hzpass.db Dataset Patl-u~iame: SHzPass Presentation Format: 18 Dataset Creation: Mon .Jun 21 11:00:55 2010 Charted by: Depth in Feet scaled 1:150 ~0 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 0 Line Speed (ftlmin) -200 -7 MTTP12 (rad) 3 Li S d ne " pee ~.. _. ~ .Hanger. i i - ~ - ; 3.5 Colla r ~ Pups - -. ~ - - - - j -1 3.5" Collar --1 ~- ~ i I Delta Met al T hickness Tubing Jt. 1 ' 20 A pparent Line of I solated Metal Loss r " 3.5 Collar arent Line of Isola ted Met al Loss 4fl pp 7.625" Collar „~- _ Tubin Jt 2 I I g . ~ r % Meta l Lo ss ~ ,~ 60 5 3 " Co llar ~ . Ap parent L ine of Isolated Pvieta l Loss 3% Met al Loss 16" Conductor 0 8 - - - + Tubing Jt. 3 --- - -- " _ 7. 625 Co llar i ~_ ~_ o`~~,wE"s E~anded 5Hz Pass Magnetic ~ckness Log Data Q~ p~°'s 1 D-134 June 20, 2010 Pn°Acrive Dinynasric Seaviees Database File: d:lwarriorldata\1d-1341expanded 5hzpass.db Dataset Pathnarne: SHzPass Presentation Format: 18 Dataset Creation: Mon Jun 21 91:00:55 2010 Charted by: Depth in Feet scaled 1:60 -50 Delta Me tal Thick nes s {% ) 50 1.3 MTTP01 {r ad) 11.3 0 Li ne Speed ( ft/mi n} - 200 -7 MTTP12 (r ad) 3 - - ^ _._~ ~ -- - ~~ __ ~ _ _ _- _ - - ~ Lin e S peed - - _. -- - _ _ _ _ - _ = - Hanger - --- -- - . -- 3 5" o lar S ~~ Pu s ~ - ~ I i - - . p I ~ r - 3.~' Co llar ~ - D elta ~ Met al T hickness 10 y i i }j j 4 S ~ ~2 °~ Tubing Jt. 1 ) t Li f I l t d M t l L ! ~ 20 t ,~ pnar en ne ' o s o a 7 e e a oss ~' ~ ~: i t z , k E 3 30 5 +~ -50 Delta Metal Thickness {%) 50 1.3 MTTP01 {rad) 11.3 0 Line Speed (ftlmin} -200 -7 MTTP12 {rad) 3 ~ ConocoPhillips Alaska, Inc. KRU 1 D-134 1 D-134 TUBING API: 500292289200 Well T e: PROD An le TS: de (0-5506 SSSV T e: NONE Ori Com letion: 11/12/1998 An le TD: 12 de 6224 , OD:3.500, ID:2 992) Annular Fluid: DIESEL Last W/O: 1/i/2006 Rev Reason: PULL ESP ASSY, Set SOV . Reference Lo Ret Lo Date: Last U date: 5!17!2007 ~RbDUCTION Last Ta : 5408' TD: 6224 ftKB (0-6209, Last Ta Date: 6!9/2006 Max Hole An le 68 de 3633 oD zs25, ^ Casin Strin -ALL wt:2s.7o) Descri lion Size To Bottom ND Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-4D WELDED -t PRODUCTION 7.625 0 6209 4226 29.?0 L-80 ABM-BTC - Tubin Strin -TUBING Size To Bottom ND Wt Grade Thread 3.500 0 5506 3542 9.30 L-80 EUE ~ Perforations Summa Gas Lift MandreWaMe Interval ND Zone Status Ft SPF Date T e Comment 2 (5387-5388, OD:5 390) 5551 - 5576 3586 - 3610 WS D 25 5 8!14!1998 IPERF 2 1!8" EJ, 0 deg phase/orient, no slim . / ~ - - 5624 - 5640 3657 - 3672 WS B 16 5 8/11/1998 IPERF 2 1/8" EJ, 0 deg phase/orient, no slim ~ 5712 - 5720 3742 - 3750 WS A3 8 5 11/9/1998 APERF 2 1!8" EJ, 0 deg phase/orient, no slim 5732 - 5738 3762 - 3767 WS A3 6 5 11 /9!1998 APERF 2 1/8" EJ, 0 deg phaselorient, no slim 5746 - 5752 3775 - 3781 WS A3 6 5 11/9!1998 APERF 2 1/8" EJ, 0 deg phase/orient, no slim 5766 - 5769 3795 - 3797 WS A3 3 5 11/9/1998 APERF 2 1/8" EJ, 0 deg phase/orient, no slim 5786 - 5822 3814 - 3849 WS A2 36 5 8/7/1998 IPERF 2 1/8" EJ, 0 deg phase/orient, no slim Gas Lift MandrelsNalves St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3972 2394 CAMCO KBMG DMY 10 BK-5 0.000 0 1/7/2006 2 5387 3427 CAMCO KBMG SOV 1.0 BK-5 0.000 2000 5/17/2007 GAUGE ~ Other lu s, ui ., etc. -COMPLETION (5466-5467, De th ND T e Descri lion ID OD:4.000) 3? 37 HANGER VETCO GRAY TUBING HANGER 3.500 5466 3504 GAUGE CENTRILIFT SENTRY GAUGE 3.500 5481 3518 SEAL CENTRILIFT TANDEM SEAL SECTION GSB3 DB H6 PC92 AFLASHlHSN 0.000 5495 3532 GEAR CENTRLIFT GEAR REDUCTION UNIT 538 11.42:1.562 0.000 5496 3533 MOTOR CENTRILIFT MOTOR 76 HP 1360V/KMHG 0.000 5505 3541 Centralizer MOTOR CENTRALIZER 0.000 SEAL (5481-5495, OD:5.130) GEAR (5495496, OD:5.380) MOTOR (5496-5505, OD:5.620) .: ..; -..,-, -:.„ ~ _ II ~. n I I ' . , ~ Central¢er (5505-5506, OD:6.000) Perf (5551-5576) Perf (56245640) Perf (5786-5822) I ~~x ~ ~ ~~ ~ ~ `~ ~~ ~ ~ ~ ~~' _., _. _ _ - ._ ,..w_ ~~. ~..~.~_..a,.-.W~.~,~..,. ._.r a y i ~ i 4~, ~ ~ F ,.,.«~ =' ., i 3a ±:: ~ ~._._ -t§~ ,~ rtr~syf ~(f#ss r.-~~Ikka ~~tle3~~ ~~.-~. ~~~_„-,. ._ ~ ~.~«~ ..,. ~,:. ,.. .. ,..> ,., n.-...-..T_.~~....- -.~wu+ - _. ~ ww s...-. - _ .r--- - TT ~~ R ~' `,. Lt~a~ ~ ~~ ~ ~.~~y ~ ;'~" ~ x ~ Fps ......~,.~ ._,.~.,.........~»..o,~,=«..,,,,,,, ,,,,;,,~...r~.....,..~,.:~, -~ ~ e ~.~~ ~ ,. ' 1 ~ ! a ~,i ~i a ~~ar 'a ~~,_ ~ t 3k. L~~€~ .~ k Hs'€~ k~!€,~~ ~~~a~, ~~,a~~~ ~ 4~ ~ ,~ ~, s.~ ""~ #""~ ~ ,. _ '~ '~t9 ~~ 14'{~si.? .L~'?~sr~k"{SUI LzUjDd f ~`~ ~ ~ ~'~ .s.~„ +~ a a ~ , a t ..~.. !t ~ P yt (" '~-' '~ wM ~~` y,~;i S#. ~4 eni~"`!X k~rtbk M t'}M ~al~mYM+ac-~..w8nr~o-'+~m +" $ >. asp-^ ''t~ 4.~".~`~ v yy ¢ a ~' S:*~ ~.:~ { J. ~G3 ~R~k. >r ~S 1 ~ _ .r ...,-...~ s ~~~ 3r rSSe,~<~ ~~5t p.-ra r ~„ _ g ~ maw...-K -tea„- - . :,. + - ~ ~ ~ ~ ate st's +, z,.~ s=a}~~t !s[y ¢ '~" ~''~'3 ~ " 9~'~ - ~ t~~ ? z" ~ '~ « ,% c ;~t~i ~ ~«tr,;~~~ Fi~x~:iu~`~,~ ~='ti~.~ ~`~ !~ ~, t4*~`~ ~~ w...,,,y..,,.,...y~ ~ ~., . ~.~"i ! _' .~, ~. ;~# i ~, _~ e r ~,.~ artii i4~i }'a.S r4 s. i ~ R 1..~ -. `}F L~ ~\h.F be~8 ~ W ~ •. P ._ wy ~ i ~ ~.lt ~"s ;.$4~# a~ r~ i . _,grt cd¢'s' ~ ~`~ ~ t~$ °~a x.°e ~ z wr ~y+yA :.' r ,.>vrw~.. ~, 6,'a ~«~~~ s,k~ 1~ k'~eR~ 4a N~.«t~ ~'~ _ _._ - ~,3~# ~,~± gya,..a. ,. .-. ..a~,. „- -.. .... . ~-: _ ft ; isr f = _, ' as ., .., _ „~_,.,a.v m ,. ~ _, .~.... F p ~ X~~tiap~fs };tygyt~ ~ fit Ct7 iei~6i# d C~L71lrf4 ~(Ck(fa ~'i3'. AY`ffl 4.f sx~6Y`~ "~ 4S 1 gym.. '1.46.3 et~r ~~e "'~T ..as s3yFU 1w~ ~ s-: ~ s ~ firuy +~ W- ~ ~ .„ i _:.. :;.. - ~a-,~~-. -,....~-.-....._-tea.,,..-- .. . ~. ~ .;:, ... _ , ^' t •..-. - ~nw-+,.-.-T _:_.__~~,~- _-. __.. ....-- ~.._~.. _ .... _-.:. .:-_ . __.~,:,..... .... ._ .....,.. „ass:.. .. fir. .. _ .. ' - - , } E. , - ~ ~_ ~x s 3 ~3'-_.+a i ~ t ~3e ~ ~YY # Ka ~ 1A e ~ ~ 4~ s a 9. t +• -xl. ;~' i~ -i a ' - - ~ .~`~s ~ ~+~-1~ ~a ~3 si ~~ ~~r a tea,,, -»- ~ 3 ~„) 4"~._ ....., ~.. _. - a~;. _~ ~, ~.,:fa r~ .>•}:~ q~t ,~ ~€tw'1'=r~.~4t€i ~, ~E~f l~ot!tiPf ~: ~: l1 C9i1 t~taatt t C1 ~~~ .-, ~ . _ .....P~..~~ . .., „ ~.~. • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: 1 I~q~.11 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 a 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 treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were performed between June 23, 2008 and August 24, 2008. The corrosion inhibitor/sealant was pumped on August 27, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. <, n~ Sincerely, .. ~~~~~~ SAP 0 ~ 200$ i~% ~~ M.J. oveland ConocoPhillips Well Integrity Projects Supervisor • RECEIN~ SEP 0 2 2008 Alaska pil & Gas Cons. Commi,sion Anchorage • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/27/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-23 191-U09 12" na 12" na 6.80 8/27/2008 1A-24 200-1'81 6" na 6" na 2.55 8/27!2008 1A-28 191-002 8" na 8" na 1.70 8/27!2008 1 B-13 194-055 24" na 24" na 8.50 8/27/2008 1 B-15a 204-256 SF na SF na 8.50 8/27/2008 1 B-16 194-037 21' 8" 4.00 25" 8/24/2008 6.80 8/27/2008 1 B-17 194045 6' S" 1.00 28" 8/24/2008 5.10 8/27/2008 1 D-134 198-111 SF na SF na 2.55 8/27/2008 1 D-135 197-184 SF na SF na 1.70 8/27/2008 1 D-141 a 208-016 16' 1.40 3' 6/23/2008 9.35 8/27/2008 ~~-~..~ Jl1}~i .~ ~ i= ~~~ STATE OF ALASKA A~S~c~ ~~~ ~ , ALASKA OIL AND GAS CONSERVATION COMMISSIO C;~ ~' ! ";. ~,; , 0/ ~;,,.~F~,~ REPORT OF SUNDRY WELL OPERATIONS ~'~ ~~~'~~ --~~~ 1. Operations Pertormed: Abandon ^ Repair Well ~ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Wetl ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 198-111 /' 3. Address: Stratigrephic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22892-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 71' 1 D-134 8. Property Designation: 10. Field/Pool(s): ADL 25650 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 6224' feet true vertical 4241' • feet Plugs (measured) Effective Depth measured 5408' feet Junk (measured) true vertical 3447' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' PRODUCTION 6168' 7-5/8" 6209' 4226' Perforation depth: Measured depth: 5551'-5576', 5624'-5640', 5712'-5720', 5732'-5738', 5746'-5752', 5766'-5769', 5786'-5822' true vertical depth: 3586'-3610', 3657'-3672', 3742'-3750', 3762'-3767', 3775'-3781', 3795'-3797', 3814'-3849' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5485' MD. ~~~~~ ~ v~ ~ U ~~~$ Packers &SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 170 4 39 -- 164 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Brett Packer @ 265-6845 Printed Name Brett Packer Signature ~~ Title Phone: 265-6845 Wells Group Engineer ~ ~ZC` Date Pre h ro I 63-4612 Form 10-404 Revised 04/2006 ®~ ~ ^ ~ ~ \ 1 Q ~ Submit Orig~ ~y~ • Time Logs -- Date From To Dur S De th E. De th Phase Code Subcode T COM __ _ _ _. 05/10/2008 03:30 04:30 1.00 COMPZ WELCT OWFF P Monitor well for flow. Gained 4.2 bbls over the 30 minute period. SWI for 30 mnutes and obtain SIP of 20 psi. Prepare to increase kill weight fluid to 9.3+ 04:30 07:00 2.50 COMPZ WELL OWFF P Increase kill weight fluid to 9,3+ ppq. Monitor Well. 07:00 08:30 1.50 COMPZ WELC CIRC P Circulated 250 bbls 9.3+ ppg SW w/6% KCL @ 3 BPM @ 290 psi holding 90 psi back pressure. 22 bbls loss. 08:30 11:30 3.00 COMPZ WELCT CIRC P SIW. SITP=60 PSI SICP=30 PSI. Bled press off thru choke. Well flowing back @ 8.5 GPM slowed down to 1.5 GPM in 70 min. SI well, SITP = 20 psi SICP 0. Opened back up and pumped 40 bbls of 9.8 ppg down IA and 10 bbls down tubing . SITP = 0 SICP 0. 11:30 13:30 2.00 COMPZ WELCT OWFF P Monitored well. Well dead. 13:30 15:30 2.00 COMPZ WELCT NUND P Set BPV. RD circulating lines. ND tree 15:30 22:00 6.50 COMPZ WELCT NUND P NU BOP and install HCR and 3 1/2 Rams in the LPR's. 22:00 00:00 2.00 COMPZ WELCT Function test and test 250/2500 psi. Witnessing waived by Bob Noble, AOGCC. 05/11/2008 00:00 02:00 2.00 COMPZ WELC BOPE P Function test and test 250/2500 psi. Witnessing waived by Bob Noble, AOGCC. 02:00 03:30 1.50 COMPZ RPCOh OTHR P Re arrange Drill pipe in derrick for handling of 3 1/2 Production to be ulled. 03:30 05:00 1.50 COMPZ RIGMN' SVRG P Slip and Cut Drill Line 05:00 06:00 1.00 COMPZ RPCO OTHR P Pull blankin lu ,double check for press. 0. Pull BPV. Install isolation sleeve. 06:00 06:30 0.50 COMPZ RPCO NUND P MU landing jt. PJSM. BOLDS. Pulled 160K, hanger unseated. Up wt 93K. Pulled hanger to rig floor. Filled hole and monitored well for flow. Well static. 06:30 08:00 1.50 COMPZ RPCOh CIRC P Circulate hole volumn w/KWF 9.3 . SD monitor well, well static. 08:00 10:00 2.00 COMPZ RPCO6 PULD P LD landing jt and tubing hanger. POOH with ESP assembly, standing. back tubin in derrick, spooling up ESP & heat trace cables. Pull 2 singles & one triple. Hole fill not exact. MU head pin. Weight up pits from 9.4 to 9.6 10:00 12:30 2.50 COMPZ RPCO CIRC P Circulate 9.6 ppg KWF around 4 BPM 190 si SD, monitor well, let a ualize. F'~ge 2 of 5 • Time Logs _ Date From To Dur 5. De th E. De th Ph e Coe Subcode T COM 05/11/2008 12:30 21:00 8.50 5,506 41 COMPZ RPCOA PULD P - -_ _- Continue POOH w/ ESP Assembly, standing back tubing in derrick, spooling up ESP and heat trace cable and removin clam sand bands. 21:00 23:30 2.50 41 0 COMPZ RPCOh PULD P Lay down ESP Components. Recovered 170 joints 3 1/2, 9.3#, L-80 EUE 8rd tbg, 2-GLM's, 6- 9.3#, L-80 EUE 8rd pup joints, 1-hanger. 8 - SS bands, 3- Protectorlizers, 3-Flat Guards, 2-4' Cannon Clamps, 1-3' Cannon Clamp, 2- Sentry Guage Clamps, 42- Xcplg Clamps, 454-5' Clamps, 90- Xcplg Dual Channel Clam s. 23:30 00:00 0.50 0 COMPZ RPCO OTHR P Clean Rig floor and wrap ESP Cable Spool. 39.5 BBL loss today 91.5 bbl Total Lo e 05/12/2008 00:00 01:00 1.00 COMPZ RPCO OTHR P Continue to Clean rig floor and Swap over to DP a ui . 01:00 02:00 1.00 0 214 COMPZ RPCOh PULD P Install Wear ring and held PJSM w/ crew on Test pkr and RBP. PU and MU Test PKR and RBP 02:00 05:00 3.00 214 4,370 COMPZ RPCOh TRIP P Rih from derrick w/ Test PKR and RBP to 4,370' 05:00 07:00 2.00 4,370 5,500 COMPZ RPCO TRIP P PU dp from pipe shed and Rih f/ 4,370' to 5500'. 07:00 10:00 3.00 5,500 5,479 COMPZ EVAL DHEO P Set RBP 5500'. Picked up off RBP. Performed MIT on 7 5/8" casing by pressure up on casing to 2600 psi (charted). Pressure bled off to 2500 psi in first 15 min. Bled off to 2450 psi in 30 min. Bleed pressure off. Released from RBP pulled 1 jt DP. Set test acker 5479'.Pressure test between RBP and_testepackerx 2500_ psi held for 5 min solid. Bled pressure off. Pressure test IA to 2500 psi found two small leaks on graylock connections on surface equipment. Repaired leaks. Repressured IA to 2550 psi held for 30 min. held solid,: pressure after 30 min. 2550 si. Bleed ressure off. 10:00 11:00 1.00 5,479 5,500 COMPZ EVAL DHEQ P Released test packer: Lower down 1jt DP retrieved RBP and released. 11:00 15:00 4.00 5,500 0 COMPZ RPCO PULD P POOH standin back drill i e. Laid down RBP and test acker. 15:00 16:00 1.00 0 199 COMPZ RPCO TRIP P PJSM MU 6 1/8"mill tooth bit and six 4 3/4"drill collars. 16:00 17:30 1.50 199 5,528 COMPZ RPCOh TRIP P RIH w/ DP from 199' to 5,528' out of derrick. 17:30 20:00 2.50 5,528 5,730 COMPZ RPCO TRIP P PU and Rih f/ 5,528' to 5,686' and pump DP vol. and clear pipe. Continue to PU and rih to 5,730' and Ta ed u . 20:00 22:00 2.00 5,730 5,722 COMPZ RPCO TRIP P Pooh w/ 4 stands to 5,463' and Rih PU 11 'ts d to 5,722'. -- F'a€~e 3 a# 5 r~ Time Logs_ Date From To Dur S De th E. D th Pha e Code Subcode T COM 05/12/2008 22:00 00:00 2.00 5,722 5,800 COMPZ RPCO CIRC P Clean out fill f/ 5,730' to 5,800'. Having to circ for 15' @ 3 bpm @ 270 psi and then reverse circ @ 3 bpm @ 270 psi. Recoverin fine silt sands. Losses for toda 38 bbls. 12 .5 b I T losses. 05/13/2008 00:00 04:00 4.00 5,800 5,879 COMPZ RPCOh CIRC P Clean out fill f/ 5,800' t/ 5879'. Having to circ for 15' @ 5 bpm @ 590 psi and then reverse circ @ 3 bpm @ 270 psi. Recoverin fine silt sands. 04:00 05:30 1.50 5,879 5,879 COMPZ RPCO OTHR P Held PJSM w/Crane op. Remove ESP Cable and Heat trace Spools. Install the same. 05:30 18:00 12.50 5,879 6,073 COMPZ RPCO CIRC P Clean out fill f/ 5,879' t/ 5,899'. Having to circ for 15' @ 5 bpm @ 590 psi and then reverse circ @ 3 bpm @ 270 psi. Recovering fine silt sands and carbolite propellants. Clean out fill f/ 5,899' U 6,073'. Having to circ for 15' @ 5 bpm @ 590 psi and then reverse circ @ 3 bpm @ 270 psi. Recovering fine silt sands and Carbolite propellants. Circulate 3 hole vol of 260 bbls 3 b m 300 si. 18:00 18:30 0.50 6,073 5,720 COMPZ RPCOti TRIP P Pooh f/ 6,073' t/ 5,720' to bottom of To erf. 115k u wt. 18:30 19:00 0.50 5,720 5,720 COMPZ RPCO OWFF P Observe well for flow, had slight gain then stabilized. 19:00 21:30 2.50 5,720 4,072 COMPZ RPCO TRIP P Pooh la in down DP f/ 5,720 to - 4,072' 21:30 22:30 1.00 4,072 199 COMPZ RPCO TRIP P Pooh standing back 40 stands of 3 1/2 DP f/ 4,072' t/ 199' 22:30 23:00 0.50 199 0 COMPZ RPCOh TRIP P Pooh and stand back DC's. Break down 6.125" OD bit and bit sub. 23:00 00:00 1.00 0 COMPZ RPCOti OTHR P Pull wear ring and change over to tbg equip and RU spooling equip. over sheeves. 193.4 bbl loss today, 322.9 bbl total losses. 05/14/2008 00:00 00:30 0.50 COMPZ RPCO OTHR P Continue to clean and clear rig floor. 00:30 01:30 1.00 COMPZ RPCO DHEO P PU and serviced ESP Motor, Upper and Lower Seals. 01:30 02:00 0.50 COMPZ RPCOh OTHR P Thread esp cable thru sheeve and han sheeve. 02:00 03:00 1.00 0 40 COMPZ RPCOh OTHR P Test motor P-P 1.6, P-P 1.6, P-G 2m OLMS. Install guide pins and insert MLE Head. Install 3 protectorlizers, 2 flat wards. 03:00 05:30 2.50 40 125 COMPZ RPCO RCST P Continue to Rih and install Guardian Sensor, GLM#2. Meg ESP Cable 3.6 Phase to Phase, 2.5 gig Phase to Grd. Sensor 4 si 65? 05:30 09:00 3.50 125 2,493 COMPZ RPCO RCST P . Continue to Rih w/ 3 1/2 ESP Com letion 57k u wt. 55k do wt. 09:00 10:00 1.00 2,493 2,493 COMPZ RPCOh OTHR P MU Heat Trace Line -Bottom will be @ 3,000' when landed. Test ESP Cable and Heat Trace. Pays 4 of r~ Time Logs Da e From To Dur 5. De th E. De th Phase Code Subcode T COM 05/14/2008 10:00 17:30 7.50 2,493 5,440 COMPZ RPCO RCST P Continue to Rih w/ 3 1/2 ESP Completion f/ 2,493' t/ 5,440'. 85k up wt, 60k do wt. Test ESP cable and Heat Trace eve 1,000' ran. 17:30 18:00 0.50 5,440 5,440 COMPZ RPCOh OTHR P Test ESP Cable and Heat Trace, MU TBG Han er and in stall enetrators. 18:00 23:30 5.50 5,440 5,440 COMPZ RPCO OTHR P Space out cables and make final s lices. 23:30 00:00 0.50 5,440 5,485 COMPZ RPCOI~ HOSO P Test final splices and drain stack. Land 3 1/2 ESP Completion w/ bottom of Centralizer 5 484.8'. 92k up wt., 60k do wt. Total losses for today 36 bbls. 358.9 bbls total loss. 05/15/2008 00:00 00:30 0.50 5,485 5,485 COMPZ RPCOti SFEQ P RILDS and test hanger to 5,000 psi. Lower seal ood but u er seal failed. 00:30 01:30 1.00 5,485 5,485 COMPZ RPCO OTHR T BOLDS Pull hanger to rig floor and inspect. Replace w/ new seals and reland. 01:30 02:00 0.50 5,485 0 COMPZ RPCO SFEQ P RILDS and witness test hanger void to 5,000 si. - ood. 02:00 04:30 2.50 0 0 COMPZ RPCO NUND P ND ROPE and set back 04:30 05:00 0.50 0 0 COMPZ RPCO6 DHEO P Test ESP Cable and Heat Trace 05:00 06:00 1.00 0 0 COMPZ RPCOh NUND P PJSM, NU adapter and tree, final testin ESP electrical. 06:00 08:00 2.00 0 0 COMPZ WELC BOPE P PJSM, test prod tree 250 / 5000 psi 15 min. Test successful. 08:00 12:00 4.00 0 0 COMPZ RPCO FRZP P RU /freeze protect well. 100 bbls diesel do annulus, 25 bbls do tbg. ICP = 2 bpm - 750 psi, FCP = 1250 psi. "0" psi tbg and annulus. Set BPV, NORDIC RIG 3 RELEASED THIS DATE 1200 HRS. ~'~g~ 5 of 5 f ,~ _ ~ KUP 1D-134 ~ P _ w a . ~ ~c~t~s~+ta hi[lips ~ ,: ~ ~~ Er1L API / l3Wl Herd Name Wen ara[us ~Maxrmum tncbnanort (°/ local Uepm (knb) ~ -~ '',5002922892 WEST SAK PROD 6799 6224.0 ( ,Comment ~. N2S (ppm) Date Annotati... End Date KB-Ground Distance (ft) Rlg Release Date __ 1a:nng 1o-I `~ hF arzro9lraa:4~Fn~ NONE 4 1/1/2008 Last WO: 5/15/2008 42.41 11/12/1998 Sr r i r-~~~=~. __ Annotation Depth (ftK8) Entl Date Annotation End Date Last Tao: 5.408.0 6/9/2006 Rev Reason: WORKOVER 6/17/2008 -5 ~ 2518 t ~ I ~ >._ . . Casing Description OD (in) ID (in) lop (ftK8) Set Depth (kKe) SetDepth (I VU) (ftK8) Wt (Ibs/tt) Gratle 1 Op COnneOtlOn CONDUCTOR 16 15062 0.0 1210 ~ 121.0 6258 H40 WELDED Tubing Jt 37 I Casing Description OD (in) ID (in) Top (ftK8) Set Depth (ftK6) Set Depth (ND) (ftK8) Wt (Ibslft) Grade Top Connection HANGER 37 l " ~ ~ISURFACE 7 5/8 6 750 0.0 6209.0 ~ 4,226.4 29.70 L 80 ABM-BTC ~ ~ ~TUbing Hanger Pup It, 39 ~ ` I ubng Dest,~~Hllon OD 1~~,j ID U~~) (Top (kK... Set Depth (11h.8) Shc Depth (ND) (kK8) Wt (lbs/R) Grade TOp C nechon ESP Recomoletion.. 31/2 ~....... - I I . I ' "S a ~ ®....... ~ Top (ftK8) Item Description Comment .D (in) CONDUCTOR, 0-121 ~ 37.1 HANGER Tubing Hanger, Vetco, - 2.992 HEAT TRACE, aT ' 3,010.S iHEAT TRACE Heat Trace Starts@3,000' 0.000 ~ 3,994.0 'IGAS LIFT Camco, KBMG, BK-5, tin w/DMY STA 1 2.920 I 5,368.3 GAS LIFT GLM 2, Camco, KBMG, BK-5, 1"w/DMY STA 2 2.920 5,444.7 1SENSOR Guardian Sensor @ 5,441' - 5,438' 2.992 5,454.8 ESP INTAKE ESP-Intake, SE8442XA 1.995 5,460.4 SEALS Upper and Lower Seal, GS63DB 1 1.995 5,474.2 ,GEARBOX GRU, 525, 9:1 1.995 5,475.S IESP MOTOR ESP -Motor 76 hp, 1360v, KMHG 1.995 I 5.4P? " °SP Centralizer F°p Centralizer 1.995 ~ GAS LIFT, 3,994 ~ ~ ~ ~. ii € Top (kKe) Dra~upbon ern rtur~ Late iD (in) ..omrrr } - 37.OHEAT TRACE HEAT TRACE 5/24/2008 0.0001 i 5,418.0'.SLIPSTOP SLIPSTOP SET ON TOP OF PACKOFF set 5/24/2008 5/24!2008 1.500; l 5,425.OPACKOFF 3 5" PAC KOFF ASSEMBLY set 5/24/2008 5/24/2008 1.500 5,455.0 (,PUMP 1TTC ESP PUMP rOAL 33.08') set 5/28/2008 5i24l2008 1 ~ n00 .. , - _ -. ~. snot ~icw... ~ Btm Top (ND) Btm (ND) Den Shot ' ',TOp (kK6) (ftK8) (ftK8) (ftK6) Type Zone (sho T cal Date ~ Comment GAS tIPT, s,3ss c ~ 5,551.0 5,576.0 3,585.9 3,610.1 IPERF 5 O 125',8/14/1998 2 1/8" EJ, 0 deg phase/orient, no slim 5,624.0 5,640.01 3,656.6 3,672.311PERF 5 0 80'.8/11/1998 '2 1/8" EJ, 0 deg phase/orient, no slim 5,712.0 5,720.01 3,742.1 3,749.8''~,APERF 5.0. 40 11/9/1998 12 1/8" EJ, 0 deg phase/orient, no slim ' 5,732.0, 5,738.0 '1 3,761.5 3,767.31APERF 5.0'', 30 11/9/1998 2 1/8" EJ, 0 deg phase/orient, no slim 5,746.0 5,752.0 3,775.1 3;780.9 APERF _ S.O 30 11/9/1998 .2 1/8" EJ, 0 deg phase/orient, no slim j ' ', -~, 5,766.01, 5,769.0 3,794.5'. 3,797.4.APERF 5.0~ 1 19115 //1 19115 // 998 121/8" EJ, 0 deg phase/orient, no slim 5,786.Q' 5,822.0 3,813.9 3 Sip ~ IPERF 5 0 180 8/7/1998 12 1/8" EJ 0 deD phase/or""lent no slim 1 SLIPSTOP. 5.418 ~~: s ,. -...... ~.._... ~.. e End D ata AnnL~oJVI, 15/15/2008 NOTE: Original Rig KB Measurement Parker 245 - PACKOFF, s,azs ' '~ 1,6/17/2008 ___ NOTE: VIEW w/9.0 SCHEMATIC VERSION lD-134 (PTD 1981110) Report off ailed ESP: broken shaft, RWO T... . . Tom & Jim, The ESP failed in West Sak producer 10-134 (PTO 1981110) requiring a RWO to repair the ESP. Slíckline diagnostics performed on 5/18/07 found the shaft is not turning, indicating it is broken. The well remains SI while waiting on a RWO to repair. There are no plans to attempt to gas lift this well while waiting on the RWO. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com S\CJ~ MA'f ·2 1 20D7 From: NSK West Sak Prod Engr Sent: Friday, May 18, 2007 11:08 AM To: Jenkins, Lubbie Allen Cc: Selisker, Gary R; Rodgers, James T; CPA Wells Supt; NSK Problem Well Supv; Dinkins, Walter R; Atol, Christopher Gerald; Campbell, Blaine M; Ennis, J J; CPFl DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; NSK Centrilift Fld Srv Subject: 10-134: broken shaft, RWO required FYI. I just received word from the field that the rotational test tool indicates 10-134 has a broken shaft. We will need a RWO to get this well back online. The shaft breaking event happened on 3/23/2007 (sudden drop in VSO A Phase current, from 60A to 49A). The pump was pulled 5/17/2007 and came out of the hole with a locked rotor (appears to be locked up with sand). The last rig workover on this well was completed 1/8/2006. The well produced -200 bopd at -17% watercut. The rotational test tool was pinned to verify that it was properly seated and it was checked for rotation after it was pulled from the well. Let me know if you have any questions. Thanks -Hai Hai Hunt / Pete Nezaticky NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 10f2 5/20/2007 9:39 AM n........ ,Lr-,-V JU"""",,, ,-,"U'''UL-- <L.r, J'" a" VY\,," e e Tom, I have reviewed the records. The details from the operations summaries and cement reports indicate that both 1D-40 and 1D-134 had good returns throughout the cement jobs and cement to surface. I have compiled the reports and highlighted the information related to the cement jobs. I have edited the documents to remove proprietary contractor data. My schedule for this afternoon is full. I will follow up on Monday with electronic or hard copies of the documents. Pat Reilly ConocoPhillips (907) 265-6048 (907) 244-5558 (907) 265-1535 Alaska Drilling WORK CELLULAR FAX & Wells (\()~\~a~ \ \ f"o-..~",,,,,û.. ~'"C) \'- \ '^' K "? ~<-<2-\-\-~Q: ~~ \ \.. .Ç\\((:, So ~ l b~- \ .~~ ~q-\~"'ì. ¢ \ ~.. '-\0 ~~,~,-Q: ~~\..\-.\ '^-~ ()~~~I;-f;, a..<-c:....~~ \\f M ?ff1Lt{ .-()(o \\:1 Thanks again for your help. pa'trick.J.Reilly@conocophillips.com -----Original Message----- From: Thomas Maunder [maill:o:Lom ma.œ:der:3)admin.sl:at:e.ak.us] Sent: Thursday, April 06, 2006 10:13 AM To: Reilly, Patrick J Subject: Re: 1D-40 Surface Cement--1D-134 as well 4JOO-\\S, ! i l:'"', l~Ý ~ \S'6-\ \. \ Pat, Could you also provide information on 1D-134 as well? about as thin as for 1D-40. Thanks much. Tom The summary is Thomas Maunder wrote, On 4/6/2006 10:06 ~~: Pat, I am reviewing the close wells to 1J-127. Would it be possible to get some "detailed" information on the surface cementing operations for 1D-40. That is the casing that would be across the West Sak. The information submitted with the completion report is pretty brief. No problems are indicated, but interpretation is difficult when all that the summary says is , "Run 9-5/8" casing. Break circ @ 2300' & 4300', good returns. Finish running 9-5/8" casing with shoe @ 6978' I FC @ 6897'. Circulate and condition mud for cement job. Held PJSM. Cement 9-5/8" casing. N/D diverter system." It is noted that they drilled soft cement and wound up running a RTTS to test the casing. Formation test once out of the shoe looks OK at 13.8 EMW. Thanks for your help on this matter. Tom Maunder, PE AOGCC > e e ID-134 Package: Page 1: This string had a stage tool set above the West Sak. (See Page 4 & 5) The contaminated cement indicates c_ement to the stage tool. Pages 2-3: -Remaining operational summary Page 4: Casing Detail- Tool at 2530 MD. Page 5: Survey - Stage tool depth is more than 1800' TVD. That is about the depth of the permafrost. Therefore the 1 sl stage TOC should have made it above the West Sak. Page 6: Our cement indicates no tight hole while running casing. We also had full returns throughout the job and bumped the plug. I think the data indicates that we likely have a competent barrier on the surface casing of ID-134. 7/17/1998 7/18/1998 7/19/1998 7/20/1998 17:30 - 19:30 19:30 - 22:30 22:30 - 00:00 00:00 - 01 :00 01 :00 - 05:00 05:00 - 05:30 05:30 - 08:00 08:00 - 00:00 00:00 - 06:30 06:30 - 08:00 08:00 - 15:00 15:00 - 16:00 16:00 - 20:00 20:00 - 00:00 00:00 - 02:00 02:00 - 05:30 05:30 - 06:30 06:30 - 07:30 07:30 - 18:00 18:00 - 20:00 20:00 - 22:00 22:00 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 03:00 03:00 - 07:00 07:00 - 08:30 08:30 - 10:00 10:00 - 11 :00 11:00 -13:00 13:00 - 13:30 13:30 - 14:30 14:30 - 18:00 18:00 - 18:30 18:30 - 19:30 e .,\)ç-\\ ! Page 1 of 3 ConocoPhillips Alaska Operations Summary Report 2.00 DRILL jDRLG NULL 3.00 :T~'n PROD 1.50 Ip~~D NULL 1.00 ¡PULD PROD 4.00 iTRIP PROD 0.50 CIRC PROD 2.50 TRIP PROD i 16.00 DRILL jDRLG PROD 6.50 DRILL :DRLG PROD 1.50 ICIRC PROD 7.00 TRIP PROD 1.00 jPULD PROD 4.00 ¡TRIP PROD 4.00 iCIRC PROD 2.00 iCIRC PROD 3.50 TRIP PROD 1.00 IpULD PROD 1.00 I PROD 10.50 PROD i 'CIRC CEMENl PLUG i 1.50 I CIRC 0.50 j 1.50 CEMEN~PLUG 2.00 2.00 PROD PROD legal Well Name: 1 D-134 Common Well Name: 1D-134 Event Name: ROT - DRilLING Contractor Name: Nordic Calista Services Rig Name: Nordic 2 Date From - To I Hours Code I cfouJe Phase I 7/16/1998 00:00 - 16:30 16.50 DRILL ¡ DRLG PROD 16:30 - 17:30 1.00 DRILL I DRLG PROD i PROD PROD PROD 0.50 1.00 i NUND 4.00 ! NUND 1.50 WELCTL! BOPE I I I i 1.50 ¡TRIP 1.00 WELCTLi BOPE I 2.00 . 0.50 WELCTLI BOPE I 1.00 I TRIP 3.50 0.50 'CIRC 1.00 PROD PROD PROD PROD PROD PROD Start: Rig Release: Rig Number: 7/15/1998 11/12/1998 2 Spud Date: 7/15/1998 End: 11/12/1998 Group: Description of Operations Drlg f/1 073' to 3978'. ADT - 10.11 hrs Hole packed off in tight spot at 3938' while backreaming connection. Packoff was in BHA below jars.Worked pipe free. Est'd circ. Hole cleaning problems Run PWD tool where hole cleaning and hydraulics are a problem Back ream through tight spot f/3938' to 3915' slowly. Tight spot cleared up after reaming through first time. See above See above POH f/ bit change. Nû píûblems. Download and change out MWD.Orient BHA. Reset motor to 1.4 deg. Orient BHA. RIH slow w/20 stds DP. CBU RIH. Rotate each std slow to transfer wt. Wash and ream 90' to bottom. No problems. Drlg f/ 3978' to 5630'. ADT - 10.19 hrs. Drlg f/5630' to 6224'. ADT - 5.92 hrs. Circ 10 vis sweep. Monitor well. Pump dry job. POH. Pump out of hole f/5124' to 2000' due to swabbing. Cont' POH. Download Sperry Sun. MU HO. RIH to TD. Circ at 1800', 4100' and 5000'. No problems. Pump 10 vis sweep. Circ and cond mud for csg. Circ and cond mud for csg. POH. LD BHA for inspection. RU GBR. Held prejob safety meeting. RIH w/7 5/8" csg. Circ 1 csg volume at 2153',4000' and 5500'. MU hanger and land csg at 6209'. Circ and condition mud at 8 bpm. Total - 900 bbls. Test lines to 3500 psi. Pump 20 bbls preflush, 50 bbls ARCO spacer, 138 bbls 10.5 ppg lead cement, drop by pass plug, pump 59 bbls 15.8 ppg tail cement, drop shut off plug, pump 10 bbls tail. Displaced w/ mud w/ rig pumps. Bumped plug. Load top plug. Opened stage tool at 2900 psi. Q ~/'-'í {'IIAj)-¡Z IT T-o Circ out cement contaminated mud. eM '" ./ Start 2nd stage cement job. S T I'r 6 E" Tt>o L fV\ 1> ,,' Pump 2nd stage cement. Pump 230 bbls 10.5 lead cement, 10 bbls 15.8 cement, drop plug and displace with mud. Closed stage tool at 1500 psi. Check floats. LD LJ. RD csg tools. ND diverter. Wash out bag. NU tbg spool and BOPE. Test blinds, all breaks and 1st 3 valves on choke manifold to 300 and 2000 psi. Witness of West Sak modified BOP test waived by AOGCC rep John Spalding. MU BHA and RIH to 2406. CBU. Test test csg, annular, inside kill and manual choke valve to 300 and 2000 psi. Drill out cement and stage collar at 2531'. CBU. Test csg and lower pipe rams to 300 and 2000 psi. RIH. Tag cement at 5790'. Drill out cement f/5790' to LC at 6077'. CBU. Test csg Printed: 4m2006 10:17:14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To e e ~ 1 D-134 1 D-134 ROT - DRILLING Nordic Calista Services Nordic 2 I Sub Hours Code Code Phase 7/20/1998 19:30 - 22:00 22:00 - 00:00 00:00 - 01 :00 01 :00 - 03:30 03:30 - 06:30 06:30 - 08:00 08:00 - 12:00 12:00 - Î 2:30 12:30 - 13:00 13:00 - 17:30 17:30 - 18:00 18:00 - 21 :30 7/21/1998 7/22/1998 21 :30 - 22:00 22:00 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 01 :00 01 :00 - 02:00 02:00 - 04:00 04:00 - 05:00 05:00 - 06:00 11/6/1998 00:00 - 02:30 02:30 - 09:00 09:00 - 09:30 09:30 - 16:00 16:00 - 16:30 16:30 - 00:00 11/7/1998 00:00 - 13:00 11/8/1998 13:00 - 20:30 20:30 - 00:00 00:00 - 03:00 11/9/1998 03:00 - 00:00 00:00 - 02:30 02:30 - 08:00 08:00 - 09:00 09:00 - 13:00 Page 2 of 3 ConocoPhillips Alaska Operations Summary Report 2.50 I TRIP 2.00 TRIP 1.00 ¡TRIP 2.50 i CIRC 3.00 I TRIP 1.50 : CIRC 4.00 TRIP 0.50 I 0.50 CMPL TN¡ RUNT 4.50 CMPL TNI RUNT 0.50 I 3.50 I CIRC 0.50 TRIP 0.50 I 1.00 0.50 1.00 1.00 2.00 ICIRC NUND CMPL TN! I i PROD PROD PROD PROD PROD PROD PROD PROD CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN 1.00 RIGMNTI' RSRV CMPL TN 1.00 RIGMNT¡ RSRV CMPL TN 13.00 21.00 2.50 5.50 2.50 : CIRC 6.50 WELLSA 0.50 RIGMNT RSRV 6.50 I PULD 0.50 I 7.50 CMPL TN: RUNT 7.50 i 3.50 WELLSR 3.00 TRIP 1.00 4.00 CMPL TN CMPLTN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPLTN CMPL TN CMPL TN 13:00 - 14:00 1.00 CMPL TN 14:00 - 17:30 3.50 CMPL TN 17:30 - 20:30 3.00 TRIP CMPL TN 20:30 - 00:00 3.50 CMPL TN 11/10/1998 00:00 - 02:00 2.00 CMPL TN Start: Rig Release: Rig Number: 7/15/1998 11/12/1998 2 Spud Date: 7/15/1998 End: 11/12/1998 Group: Description of Operations ¡ JPOH. . RIH w/ scraper assembly. :TIH T/6077' 'CBU Change-Out Mud T/Fresh Water 382bbl @ 5 1/4 bpm 800 psi ¡ TOOH T/2563 = TIH 6077' j Circ. 35 bbl hi-vis water sweep ;TOOH = dn top scraper = dn bottom jt. dp ; Püll weai büshing i rlu to run 3.5" tbg/pjsm wlco man, tool pusher on tbg job ¡ run 3.5' tbg 195 jts tag bottom 6077' I safety meeting w/co man 'with open end tbg @ 6077'circ.-pump hog wash job ending w/3% kcl brine in hole UD 21 jts tbg rig repair fill up line valve Rig Repair Keep up with PM pump 107 bbls diesal down annulas to freeze protect well equalize diesel between annulas & tbg thru kill line u-tube diesel to tbg. MU hanger &Landing jt. land @ 5475' ND BOPE NU tree. test=leaking=remove tree=new o-rings. NU tree. test to 3000 psi 10 min. Set BPV Leaky O-ring Check all pieces of tree/wellhead before nippling up Change-out saver sub & grabs, replace bowl. Cut & slip drlg. line=96'. Reset duo-matico Released rig @ 06:00 Hrs. 22 July "98" BOLDS-Pull hanger to floor=50K up wt= CBU. POOH=LD 3-1/2"tbg=Carbolite traces in couplings Service rig Load pipe shed wi 3-1/2" PH 6 tubing= drift & strap Set wear ring= Load BHA & pup jts. RIH w/6-3/4" mill & 3-1/2" PH 6 work string= tagged @ 5517' = P/U kelly. Tagged top of Carbolite @ 5520'= Mill Carbolite 6071 '= hard bottom= continued to circ. sand. Continued to circ, rotate & reciprocate= sand continued to run in. Blow down Kelly & POOH wet = LD mill & bit sub. P/U 3-1/2" Mule shoe & RIH to 5348'= Reverse circulate cleaning up Carbolite and sand. Reverse circ. down in 90' intervals to TD= Continue to circ. to clean out. Continued to clean hole of Carbonite (sand), prep for seawater. Pull above perfs to flush and clean surface lines, kelly, shakers, flowline etc. RIH to 6066' = Held PJSM wlall involved w/Hog Wash. Displaced Visc Brine w/3% KCL Seawater= Pumped 150 bbl casing clean up displacement (Hog Wash)= 145 NTU's before= Circ. dwn tbg. take returns up ann, suck hog wash out ann valve, rotat.& recip. pipe while pumping= up wt.=95K dwn wt=35K. Clean pits & filter brine. Circ. filtered brine to clean up= NTU's in=10 out= 90 = After 2 hole volumes, cont. to circ. NTU's in=13 out 54. RD circ. equip.= POOH, LD 10 jts, standing back remaining tubing. RIU E-Line= PJSM= Started in hole w/ perforating gun. Correlated wllogs= on depth w/ Schlumberger 4-1/2" HSD perforating Printed: 4/7/2006 10: 17, 14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date e e Page 3 of 3 ConocoPhillips Alaska Operations Summary Report 1 D-134 1 D-134 ROT - DRILLING Nordic Calista Services Nordic 2 From - To Hours Code 2.00 11/10/1998 00:00 - 02:00 02:00 - 03:00 1.00 ITRIP CMPLTN 03:00 - 08:00 5.00 CMPL TN 08:00 - 08:30 0.50 RIGMNT! RSRV CMPL TN 08:30 - 21 :00 12.50 CMPL TN 21 :00 - 23:30 2.50 ITRIP CMPL TN 23:30 - 00:00 0.50 CMPL TN 11/11/1998 00:00 - 02:00 2.00 I CMPL TN I ·02:00 - 05:30 3.50 CMPL TN[ RUNT CMPL TN 05:30 - 06:00 0.50 WAlTON CMPLTN I 06:00 - 06:30 0.50 RIGMNT[ RSRV CMPLTN 06:30 - 07:30 1.00 WAlTON CMPLTN I ¡ I 07:30 - 09:00 1.50 I CMPL TN 09:00 - 23:00 14.00 CMPL TN¡ RUNT CMPL TN 23:00 - 00:00 1.00 CMPL TN 11/12/1998 00:00 - 02:00 2.00 CMPLTN 02:00 - 02:30 0.50 CMPL TN 02:30 - 04:00 1.50 CMPL TN 04:00 - 06:30 2.50 CMPL TN 06:30 - 10:30 4.00 CMPL TN 10:30 - 11 :30 1.00 CMPL TN 11 :30 - 12:00 0.50 CMPLTN Start: Rig Release: Rig Number: Spud Date: 7/15/1998 End: 11/12/1998 Group: 7/15/1998 11/12/1998 2 Description of Operations guns loaded w/51 B Deep Penetrating Charges ( 5 SPF, 72 degrees phasing, 46" entrance hole size, 34.6" depth of penetration)= RIH & perf. the following intervals: 5712'-5720' > 5732' - 5738' > 5746'- 5752' > 5760' - 5766'. Two runs. RD Schlumberger perf. equipment. Pick up 162 jts. 3 1/2" tbg. & rih wi same. PJSM-service rig. Rig up hawco slick line & rih wi 2.85 drift Î 05" 10ng=Tight @ 1500'-pûh change to 2.85 gauge ring-rih to 5115 no problem=attempt several different combinations of drifts wi no success-decision to run tbg. employed pump. Poh wi 3 1/2" tbg. Pull wear ring. Splice esp cable fl motor. Pick up & make up motor & pump. on baker personnel to hook up sentry gauge. Limited number of people trained to install sentry gauges. Train more employees in this operation. PJSM=sevice rig. on baker personnel to hook up sentry gauge. Limited number of people trained to install sentry gauges Train more employees in this operation Make up outer sentry gauge & splice wire. Run in hole wi completion=run heat trace f/3015'. Space out & make up hanger. Hook up penetrators. Finish splice on esp cable to hanger & baker bottom hole sentry gauge. Land tbg. hanger=rilds=test hanger seals. PJSM=n/d bope. N/U tree & test packoff=Pull bpv=set 2 way check=test tree to 250-5000#=pull twc. RIu circ. equip. in cellar & displace 150 bbl. diesel=U-tube same. P/U lubricator & set bpv. Prepare rig fl move=make final esp & heat trace check. (Release rig f/ 10-134 To 10-131 @ 1200 hrs. 11/12/98) Printed: 41712006 10:17:14 AM ¡e Ie Lf CASING! TUBING / LINER DETAIL Tubing or Csg Description WELL: DATE: 1 OF 1 D- 134 7/20/98 PAGES ARca Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS RKB to Landing Ring 40.96 Vetco Gray Fluted Mandrel Casing Hanger & pup 2.93 40.96 58 jts 7-5/8",29.7#, L-80, ABM-BTC Casing (Jts #86 - #143) 2443.27 43.89 Jt"B" 7-5/8",29.7#, L-80, ABM-BTC Casing - Baker Locked 43.32 2487.16 Gemoco '754' Stage Cementing Tool 2.80 2530.48 Jt"A" 7-5/8",29.7#, L-80, ABM-BTC Casing - Baker Locked 43.31 2533.28 68jts 7-5/8",29.7#, L-80, ABM-BTC Casing (Jts #18 - #85) 2873.17 2576.59 Marker Pup Jt: 7-5/8",29.7#, L-80, ABM-BTC Casing 21.00 5449.76 Marker Pup Jt: i-5i8", 29.i#, L-80, ÂBM-BiC Casing 21.48 5470.76 14 jts 7-5/8", 29.7#, L-80, ABM-BTC Casing (Jts #4 - #17) 585.43 5492.24 Gemoco Insert Shut-Off Baffle 'PBTD 6077.67 1 jt 7-5/8",29.7#, L-80, ABM-BTC Sasing (Jt #3) 42.76 6077.67 Gemoco Float Collar 1.30 6120.43 2jts 7-5/8", 29.7#, L-80, ABM-BTC Casing (Jts #1 & #2) 85.79 6121.73 Gemoco Float Shoe 1.50 6207.52 6209.02 Marker Jt between Jt #17 and 18 TD 6224.00 Jt A, Stage Collar, Jt B between Jt #85 and 86 Rat hole 14.98 Centralizers Jt #1 Bow spring on stop collar in middle of jt Jt#2 2 Spiroglide centralizers w / stop collar in middle of jt. Jt#3 Bow spring on stop collar in middle of jt Jt #4 - 15 2 Spiroglide centralizers w/ stop collar in middle of each jt.(24 total) Jt #16 - 20 1 Straight blade centralizer on each jt. (5 total) Jt A - Jt B Bow spring on stop collar in middle of jt Bow spring on cplg of 23,26,29,32,35,38,41,44,47,50,53,56,59,62, 65,68,71,74,77,80,83,89,92,95,98,101, 104, 107, 110, 113, 116, 119, 122,125,128,131, 134, 137 & 140 (39 total) Remarks: String Weights with Blocks:Up wt 260k. Dn wt 11 Ok. Used API mod thread dope Parker Rig #245 Drilling Supervisor: Donald Lutrick ConocoPhillips Alaska (Kuparuk) HALLIBURTON Kuparuk River Unit Design Report for 1 D-134 - 1 D-134 - 1 D-134 Measured TVD below Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth System Depth +N/-S +E/-W Northing Easting Rate Section Comments (ft) (0) ¡O) (ft) (ft) (ft) (ft) (ft) (ft) (0/1OOft) (ft) 112.00 0.00 0.00 0.00 112.00 0.00 0.00 5,959,153.84 560,490.83 0.00 0.00 121.00 0.00 0.00 9.00 121.00 0.00 0.00 5,959,153.84 560,t90.83 0.00 0.00 188.00 0.50 28.00 76.00 188.00 0.26 0.14 5,959,154.10 560,490.97 0.75 -0.26 274.00 0.25 3.00 162.00 274.00 0.78 0.32 5,959,154.62. 560,491.15 0.34 -0.78 377.11 1.92 254.51 265.09 377.09 0.54 -1.33 5,959:154.37 560,489.50 1.95 -0.52 471.59 3.85 242.49 359.45 471.45 -1.35 -5.67 5,959,152.45 560,485.17 2.-13 1.45 e 563.08 6.85 227.44 450.53 562.53 -6.46 -12.41 5,959,147.28 560,478.47 3.59 6.68 651.93 11.26 221.92 538.25 650.25 -16.50 -22.12 5,959,137.16 560,468.85 5.05 16.89 743.15 14.73 215.84 627.13 739.13 -32.54 -34.86 5,959,121.03 560,456.23 4.08 33.15 833.32 17.51 205.26 713.76 825.76 -54.10 -47.37 5,959,099.36 560,443.90 4.47 54.94 924.53 21.38 187.93 799.83 911.83 -83.02 -55.53 5,959,070.39 560,435.98 7.!57 83.99 1,014.85 27.02 177.85 882.21 994.21 -119.87 -57.03 5,959,033.53 560,434.77 7.72 120.86 1 ,107.20 30.14 177 .D7 963.30 1,075.30 -164.00 -55.06 5,958,989.42 560,437.10 3.40 164.95 1,197.49 33.47 177.95 1,040.02 1,152.02 -211.53 -53.01 5,958,941.91 560,439.53 3.72 212.44 1,287.80 39.21 178.84 1,112.74 1,224.74 -265.00 -51.54 5,958,888.46 560,441.43 6.38 265.88 1,376.96 46.11 180.36 1,178.26 1,290.26 -325.38 -51.17 5,958,828.09 560,442.29 7.132 326.24 1,468.49 49.61 180.57 1,239.67 1,351.67 -393.24 -51.72 5,958,760.24 560,442.28 3.83 394.09 1,560.67 56.46 178.82 1,295.07 1,407.07 -466.84 -51.28 5,958,686.65 560,443.31 7.58 467.68 1,650.45 59.31 180.10 1,342.79 1,454.79 -542.87 -50.58 5,958,610.63 560,444.63 3.40 543.68 1,743.99 66.30 179.76 1,385.52 1,497.52 -626.02 -50.47 5,958,527.50 560,445.41 7.48 626.81 1,934.38 65.36 180.70 1,463.47 1,575.47 -799.71 -51.16 5,958,353.82 560,446.11 0.67 800.49 t 2,219.24 65.08 180.90 1,582.87 1,694.87 -1,058.31 -54.77 5,958,095.22 560,444.59 0.12 1,059.12 2,504.37 65.91 180.32 1,701.13 1,813.:J -1,317.74 -57.53 5,957,835.80 560,443.92 0.34 1,318.56 2,788.2b 65.71 179.10 1,817.46 1,929. -1,576.69 -56.22 5,957,576.90 560,447.31 0.40 1,577.44 3,072.07 67.28 178.83 1,930.65 2,042.65 -1,836.91 -51.51 5,957,316.76 560,454.11 0.56 1,837.53 3,355.51 66.66 178.77 2,041.53 2,153.53 -2,097.70 -46.05 5,957,056.04 560,461.67 0.22 2,098.18 e 3,633.30 67.99 180.21 2,148.63 2,260.63 -2,353.99 -43.79 5,956,799.80 560,466.00 0.68 2,354.40 3,914.59 66.48 181.78 2,257.47 2,369.47 -2,613.31 -48.27 5,956,540.48 560,463.60 0.'14 2,613.76 4,014.37 63.96 181.09 2,299.29 2,411.29 -2,703.87 -50.54 5,956,449.91 560,462.06 2.60 2,704.34 4,108.09 62.32 181.03 2,341.63 2,453.63 -2,787.46 -52.09 5,956,366.32 560,461.18 1.'15 2,787.94 4,201.85 58.28 181.62 2,388.08 2,500.08 -2,868.86 -53.97 5,956,284.91 560,459.96 4.34 2,869.37 4,296.86 53.71 182.11 2,441.20 2,553.20 -2,947.56 -56.52 5,956,206.20 560,458.04 4.83 2,948.10 4,392.44 50.80 181.27 2,499.70 2,611.70 -3,023.10 -58.76 5,956,130.66 560,456.41 3.12 3,023.67 4,487.63 48.45 180.80 2,561.36 2,673.36 -3,095.60 -60.07 5,956,058.15 560,455.68 2.50 3,096.18 4,581.49 45.75 180.52 2,625.25 2,737.25 -3,164.35 -60.87 5,955,989.41 560,455.44 2.88 3,164.93 4,676.46 42.66 181.43 2,693.32 2,805.32 -3,230.54 -61.98 5,955,923.21 560,r4.86 3.32 3,231.13 4,772.32 38.77 180.04 2,765.97 2,877.97 -3,293.05 -62.81 5,955,860.71 560, , 54.53 4.17 3,293.65 4,866.20 35.15 178.24 2,840.97 2,952.97 -3,349.48 -62.00 5,955,804.29 560,455.79 4.02 3,350.05 4,962.48 30.18 178.46 2,922.00 3,034.00 -3,401.40 -60.50 5,955,752.39 560,457.72 5.16 3,401.94 5,057.13 26.20 179.06 3,005.41 3,117.41 -3,446.09 -59.52 5,955,707.71 560,459.06 4.22 3,446.61 07 April, 2006 - 13:46 Page 2 of 4 COMPASS '-.f1 6209 LC Depth: 6077 5 West Sal< Report Date: 07/19/98 AFC No.: AK9669 Hole Diameter: 97/8" Angle thru KRU: 12deg through West Sal< % washout: State type used, intervals covered and spacing Ran 1 bow spring on jt #1, 2 spiroglides wI stpp collar on it #2, 1 bqw spring on it #3, 2 spiroglides with stop -15,1 straight bl"de on it 16 - 20 and 1 bOW spring every third it to surface. Weight: PV(prlor cond): PV(after cond): 9.5 29 24 YP(prior con d): 36 YP(after cond): 28 Gels after: 11/24 Totai Volume Circulated: 900 Volume: Weight: 8.4 20 Volume: 50 Weight: 10.5 Reciprocation speed: 10fpm Actual Displacement: 281/118 Str.Wt.Up: 2601< Str.Wt. 1101< WI. in mud: CP: Date:7120/98 Time:00:52 P4sredcsg in hole wI top drive. Circ and conditioned mUd at 8.1 bpm. cated csg 4ntillead cement rounded shoe. Had 10.5 cement to surface on 2nd Floats held: yes/yes Calculated top of cement: Surface Hed Cement Company: DS Rig Contractor: PARKER Approved By: Donald Lutrick e Conoc6Phillips e Jim Ennis Wells Group Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1544 February 3, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West th Avenue Suite 100 Anchorage, Alaska 99501 ~tANNED FES G'? 2.005 Subject: Reports of Sundry Well Operations for 10-134 / \\ \ \~tt Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Reports of Sundry Well Operations for the recent workover on the West Sak well 10-134. If you have any questions regarding this matter, please contact me at 265-1544. ..r J. Enni Wells G oup Engineer CPAI Drilling and Wells J E/skad e e RECEIVED if & r:::u rnn.. ". 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 OlffftthoragèJ Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 198-1111 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, AnchoraQe, Alaska 99510 50-029-22892-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 71' 10-134 8. Property Designation: 10. Field/Pool(s): ADL 25650, ALK 468 Kuparuk River Field 1 West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 6224' feet true vertical 4241' feet Plugs (measured) Effective Depth measured 5407' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' PRODUCTION 6168' 7-5/8" 6209' 4226' Perforation depth: Measured depth: 5551'-5576',5624'-5640',5712'-5720', 5732'-5738', 5746'-5752', 5766'-5769', 5786'-5822' true vertical depth: 3586'-3610',3657'-3672',3742'-3750', 3762'-3767', 3775'-3781', 3795'-3797', 3814'-3849' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5444' MD. Packers & SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: RBDMS 8Ft FEB I.) 7 2006 Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation SI Subsequent to operation 119 7 118 -- 186 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Jim Ennis @ 265-1544 D:::..,. :hL~,,,,,,, Printed Na,\ 1m Ennis Title ( ~ C>1 Wells Engineer ~~j Phone ~c:..5 --/.)~i Signature :.. " .e:!Y'""" Form 1 0-~04 Revised 04/2004 OR Submit Original Only STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION FEB 0 7 2006 REPORT OF SUNDRY WELL OPERA TIßjf~ I GJ NAL 07:00 - 11 :00 11:00-18:00 18:00 - 20:00 20:00 - 21 :00 21 :00 - 23:30 12/31/2005 23:30 - 00:00 00:00 - 03:00 03:00 - 06:30 06:30 - 09:00 09:00 - 10:00 10:00 - 11 :00 11 :00 - 14:00 14:00 - 00:00 1/1/2006 00:00 - 02:00 02:00 - 02:30 02:30 - 06:00 06:00 - 09:30 09:30 - 13:00 13:00 - 13:30 13:30 - 16:00 16:00 - 00:00 1/2/2006 00:00 - 14:30 14:30 - 15:30 . ConOCOPhillip~:AlaSka Operation$ ,Summary Report 4.00 MOVE POSN MOVE Legal Well Name: 1D-134 Common Well Name: 1D-134 Event Name: WORKOVER/RECOMP Start: 12/30/2005 Contractor Name: Rig Release: 117/2006 Rig Name: Nabors 3S Rig Number: D~~e .n.. ...~r~.~_.- T~"r Hours l.,:po~~:t~~~eJ.c~_~:~:Ji->______~< . q~sp,~i,Pti?~_~~_~_~~[~~on~__,.~.~_:~c___ 12130/2005 00:00 - 01 :30 1.50 II MOVE MOVE MOVE [Removed BOPE from behind well 1 D-1 02 and put behind the well@ 1D-134. Removed mats and cleaned up around well. 01 :30 - 04:00 2.50' MOVE MOVE MOVE I Lined up carrier to well, pulled forward to install Herculite. 04:00 - 07:00 3.00 WAlTON WOW MOVE Wait on 20 to 30 MPH winds to lay down before laying out Herculite for containment. Begin laying out herculite; spot up derrick sub. Continue with spotting pipe shed & pits. Note: Witness of upcoming BOPE test waived by state rep Jeff Jones @ 21 :00, 12/29/05. Raise derrick and contiue with rig set-up. Accepted rig @ 1800 hrs 12/30105 three hr adjustment for waiting on wind. 2.00 WELCTL NUND DECOMP Rig up truck with 3% KCL, hook up hardlines to return tanks. Blow air thru all lines to confirm not frozen up. Loaded pits with 9.6 ppg filtered brine. DECOMP Held Pre-Spud meeting with crew coming on and covered all safety concerns also. DECOMP RU lubricator with much difficulty, wellhead very crooked. Pulled BPV, RD lubricator. DECOMP Hook up truck with 3% KCL seawater for well kill. WRKOVR Circulated hot filtered seawater w\3% KCL at 2 BPM and 800 psi to clean tubing & ESP equipment. WRKOVR Shut down, SITP = 210 psi. Circulated filtered 9.6 ppg Brine w\ 3% KCL around to kill well. Circulated at 550 psi tubing and 250 psi annulus @ 4 BPM until 9.6 ppg returns, switched and taking returns to pits. 24 bbls lost. WRKOVR Shut down and monitor pressure; IA=90 psi, Tbg=70. Come back online circulating 2.5 bpm, holding 40 psi backpressure; maintain 1: 1 rtns. WRKOVR Shut down. 40 psi lA, 60 on tbg. Monitor for 10 mins. Bleed off and monitor returns to pits. Shut back in and monitor for 10 mins, pressure built to 20 psi. Open back up and bleed to 0 psi. Well dead. Suck out stack, install BPV. Remove tree, install plug-off tool. Conduct spill drill in cellar. NU BOP stack. Wellhead and tree very crooked making NU difficult. With rig centered over well, could not pull wellhead over straight to get flow nipple in. DECOMP Cleaned all gravel out of cellar to assist in pulling wellhead over straight. Installed flow nipple and aired up boots. 0.50 WELCTU NUND DECOMP Sucked out mouse hole and installed same. 3.50 WELCT~ BOPE DECOMP Function test BOPE. Switch hoses around. Test rams and choke manifold to 250/3000 psi, annular to 250/2500 psi. Witnessing of test waived by Jeff Jones w/AOGCC. 3.50 WELCT BOPE DECOMP Crew Change. Continue with BOPE test. 12.5 hrs over the allotted 7 hrs. to NU & test. 9 hrs should be charged CPAI 3.5 hrs to Nabors. 3.50 WELLS PLGM DECOMP Pull blanking plug and BPV. Bleed small amount of gas off IA. BOLDS. Prep to unlandl hanger. PULL DECOMP Unland hanger (70k# up) and pull to the floor. Have some difficulties getting hanger through stack. Kick on charge pump; took 9 bbls to fill hole. DECOMP Begin rigging up cable 1 heat trace sheaves. Rig up spoolers. WRKOVR Begin pulling old completion out of hole, strappingldrifting & installing seal rings on way out of hole. Hole drinking 7-9 bbls 1 hr. WRKOVR Continue POH with completion racking back pipe. Strapping, drifting, and installing seal rings on way out. 1.00 FISH ! PULL WRKOVR Esp equipment at surface; begin breaking 1 laying down. Note: first joint I 7.00 MOVE RURD MOVE 1.00 WELCT 2.50 WELCT 0.50 WELCT 3.00 WELCT 3.50 WELCTL! KILL I 2.50 WELCT 1.00 WELCT 1.00 WELLS 3.00 WELCT 10.00 WELCT DECOMP DECOMP DECOMP 0.50 FISH 2.50 WELLS' RURD 8.00 FISH PULL 14.50 FISH I PULL I Page 1 of 4 Spud Date: 7/15/1998 End: Group: Printed: 2/3/2006 10:55:35 AM ConocoPhillip~·Alaska .. ... . Operations S'....mm~:ry Re.port Page 2 of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Nabors 3S . .. .,. , ; I , From - To!- HolÏrs Ii Code I Sub I Phase '.... ¡Codel 1=~:::::::-1 ::::::Eì::::: I I ; 2.00 WELLS TRIP iWRKOVR I 1 0-134 1 0-134 WORKOVER/RECOMP Start: Rig Release: Rig Number: 12/30/2005 117/2006 Spud Date: 7/15/1998 End: Group: Date Description of Operations . ..... .w...._____ 11 :00 - 13:00 of tubing above ESP is packed with sand. Note: Fluid losses averaging 3 to 4 bbls I hr. Clean up rig floor; everything currently covered in crude from completion equipment. Lay down remaining equipl, etc. Prep to run in hole with test packer/RBP. Install wear ring. Note: All bands, clamps, guards accounted for. Everything that came out of hole has been NORM tested. Rig up tongs and elevators for running workstring PH-6. Begin making up RBPltest packer on PH-6 workstring. Opened blinds, one stainless steel band below wear ring. Successfully fished out band. 1.00 WELLS TRIP I WRKOVR Start running in hole with packerl RBP on PH-6 workstring. 6.00 WELLS TRIP IWRKOVR Continue picking up workstring, run in hole with packer and RBP for MIT on casing. 0.50 WELLS TRIP WRKOVR Crew change. Continue RIH wI RBP & test packer. Service rig 4.50 WELLSR TRIP WRKOVR Attempted to set Bridge plug. Plug would pull heavy, but not take i weight. Still losing fluid @ 4 BPH. 2.00 WELLSR PLGM WRKOVR Set retrievamatic with 4 turns to the right. Set 20K on PKR. Line up to test IA to 2,500 PSI. Unibolt connection on kill line leaked. Pressure test Casing to 2,500 PSI and record on chart. Test passed. Beginning pressure 2,500 PSI. Ending pressure 2,450 PSI. UP WT = 60K Dwn wt DWN wt 36K DWN. WRKOVR POOH monitoring fluid levels. 4 BPH loss. Order 290 BBLS 9.6# for reverse out run. WRKOVR ND and layed down packer and RBP. RU tools for picking up mill and drill collars. WRKOVR MU 4.6250" mill, jars and 6 - 4.750" Drill Collars. WRKOVR Start running workstring from derrick. 3 -4 BPH fluid loss. WRKOVR 'Continue in hole with clean out run. Tagged top of fill or obstruction @ 5787' RKB. WRKOVR MU head pin and hose, established circulation pumping 3 BPM w/21 0 psi. Tried washing down but obstruction is solid. Losses were approx. 60 BPH. Slowed rate down to 2 BPM w/160 psi. Losses down to 15 -16 BPH. Very little sand back with returns. Made several attempts to rotate and made maybe 12". WRKOVR Continue to reverse circulate while discussions with assets over continuing in hole. WRKOVR Break down and rig down reverse circulating equip. Clear rig floor. I Begin picking up Kelly. PUH to 5736'. Pre-job safety meeting. WRKOVR i RU & test lower & upper safety valves, 250/3000 psi, RD test equip. WRKOVR After testing before Kelly could be drained water froze. Had to RU steam on swivel & upper Kelly Cock valves to thaw plugged kelly. WRKOVR Re test lower & upper Kelly Cock valves,drained. MU Kelley hose. Held pre-job safety meeting w/Hazard Analogist Check List. WRKOVR PU jt #178 RU tongs, MU jt to Kelly. Establish circulation rate 4 BPM @ 430 psi DP press. WRKOVR Attempted to rotate and torque guage not working. Guage plugged off, removed and cleaned. WRKOVR Start pumping again at rate 4 BPM w/500 psi. Lowered mill down tagged obstruction again at 5787. Milled thru obstruction with approximately 1000 ft/# torque. Continued to wash down to connection @ 5798'. Switch hoses, closed annular and reverse circulated out 1 1/2 Drill pipe volum, but nothing back over shackers. WRKOVR Made connection and continued to wash down to 5861'. Acts as though we are pushing something down hole. Reversed out with same results, 21 :00 - 23:00 1/3/2006 23:00 - 00:00 00:00 - 06:00 06:00 - 06:30 06:30 - 11 :00 13:00 - 18:00 5.00 WELLS TRIP 18:00 - 19:30 1.50 WELLS TRIP i 19:30 - 21 :00 1.50 WELLS~TRIP 21 :00 - 00:00 3.00 WELLS~TRIP 1/4/2006 00:00 - 02:00 2.00 WELLS~ TRIP I 02:00 - 07:00 5.00 WELLS CIRC 07:00 - 09:00 2.00 WAlTON ORDR 09:00 - 16:00 7.00 WELLS RURD 16:00 - 17:30 1.50 WELLS SEQT 17:30 - 20:30 3.00 WELLS~ OTHR I 20:30 - 23:30 3.00 WELLS~ SEQT I I 23:30 - 00:00 0.50 WELLSR RURD I 1/5/2006 00:00 - 01 :00 1.00 WELLS EQRP 01 :00 - 02:30 1.50 WELLS 02:30 - 05:00 2.50 WELLS Printed, 2/3/2006 10:55:35 AM Page 3 of 4 ConocoPhillips Alaska Operations Summary Report 10-134 10-134 WORKOVER/RECOMP Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Nabors 3S Date : From - Tol¡:Hours Code I î~Je Phase . I 1/5/;·~~~----T~;:;~-~-;~~~ WE~~S 'WA~~ WRK~VR 105:00 - 06:00 i 1.00 WELLS EQRP WRKOVR 106:00 _ 07:30 1.50 WELLS RURD WRKOVR 07:30 -12:00 4.50 WELLS WASH WRKOVR 12:00 - 13:30 1.50 WELLS CIRC WRKOVR 13:30 - 14:30 1.00 WELLS RURD WRKOVR 14:30 - 15:00 0.50 RIGMNT, RSRV WRKOVR 15:00 - 21 :00 6.00 WELLSIÚRIP WRKOVR j 21 :00 - 00:00 3.00 WELLSIÚRIP WRKOVR 1/6/2006 00:00 - 01:15 1.25 WELLS+.,P WRKOVR 01:15 - 03:00 1.75 WELLSRNUND WRKOVR 03:00 - 03: 15 0.25 WELLSR SFTY WRKOVR 03:15 - 07:00 3.75 CMPL TN RUNT WRKOVR 07:00 - 10:00 3.00 CMPL TN OTHR WRKOVR 10:00 - 12:00 2.00 CMPL TN OTHR WRKOVR 12:00 - 15:15 3.25 CMPL TN RUNT CMPL TN 15:15-15:30 0.25 CMPL TN SFTY WRKOVR 15:30 - 17:00 1.50 CMPL TN RUNT CMPL TN 17:00 - 00:00 7.00 CMPL TN RUNT CMPL TN 1/7/2006 00:00 - 01 :15 1.25 CMPL TN RUNT CMPL TN 01 :15 - 02:00 0.75 CMPL TN! RURD CMPL TN ·02:00 - 04:00 2.00 CMPL TN! RURD CMPL TN 04:00 - 06:00 2.00 CMPL TN RURD CMPL TN 06:00 - 09:00 3.00 CMPL TN RURD CMPL TN 09:00 - 09:30 0.50 CMPL TN RURD CMPL TN 09:30 - 10:00 0.50 CMPL TN SEQT CMPL TN 10:00 -10:15 0.25 CMPL TN RURD CMPL TN 10:15 -10:45 0.50 CMPL TN! SFTY CMPL TN 10:45 - 15:00 4.25 CMPL TNi NUND CMPL TN Start: Rig Release: Rig Number: Spud Date: 7/15/1998 End: Group: 12/30/2005 117/2006 Description of Operations ......... .. w.n ..._.._.____.___ow_ ..._____________.___ no sand or metal back over shackers. Removed damaged Kelly Hose. Stand Kelly back. Made connection, switched valves to reverse. Tag up hard while reversing @ 4 BPM. Up wt prior to reversing 65K -- DWN wt = 20K with annular closed @ 350 PSI. Begin jetting at 4 BPM to jet by. 420 PSI TP. Able to jog through and of push obstruction down. Heavy carbolite and formation sand to surface at 4 BPM. Losses to formation = 1 BPM. Continue reverse out to top of joint 182. This would be 5,890' RKB! Circulate bottoms up until sand clears. Reverse rate = 4.75 BPM @ 700 PSI. Rig down reverse equipment. Monitor well for fluid loss. Prepare to POOH. Service Blocks & Draworks, adjust brake linkage. POOH with workstring up to Drill Collars. Circulating over the top while POOH. LD power tongs, elevators, bails. PU HT tongs, PU Kelly and make up to stump, break Kelly and lower Kelly Cock valve, LD Kelly and swivel, MU bails & elevators, LD rathole. Lost total of 185 bbl fluid last 24hrs. Finish laying down Kelly and Swivel. Pull and lay down 6 Drill Collars and mill. Pull wear ring. RU running tools for completion. PJSM with all involved in running completion. PU ESP Motor and service same. Pick up ESP cable thread into sheave and prepare motor termination. Install pressure gaugel test and strap with two SS bands. RIH. Losses 1.5 BPH. Pre-job safety meeting for Ray Chem installation. Install heat trace at 2,952' RKB. Clamps on rig floor inproper due to heat trace grove on wrong side. Locate correct clamps on location and reload pipe shed & rig floor. Continue to install new completion with heat trace.Megging both cables every 1000'. Finish running completion, tubing from derrick, ESP motor, cable and heat trace to 5506'. Meg both cables. Pick up tubing hanger, MU and oriented to wellhead and flowline. Install penetrators. Cut ESP cable and heat trace, make final splice on same. Spool up excess cable and tie off. Making connection on Guardian BHP Guage. Gaurdian gauge tech wire connector failed after hooking to penetrator. Run to warehouse for new connector. Land tubing with caution. Use guides to assist in centering through BOPE. Confirm correct orientation of hanger. RILDS. See REMARKS for Band Count. Pressure test upper and lower seals to 5,000 PSI. Set BPV. Begin to empty pits. Prepare to Nipple DWN BOPE. Pre-job safety meeting as to nipple Dwn proceedures. Well noted that BOP are not centered. Will have ot snub off BOPE while lifting to keep from shearing penetrators. Nipple Dwn HCR, BOPE, prepare to pick off of casing head. Lay down ESP trunk, Clean pits, begin breaking lines. Release hardline to exterior tanks. Printed, 2/3/2006 10,55,35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 1/7/2006 15:00 - 15:10 15:10 - 17:30 17:30 - 20:30 20:30 - 22:00 22:00 - 00:00 ConocoPhillips Alaska ·(þþerations Summary Report 1 0-134 1 0-134 WORKOVER/RECOMP Nabors 3S ".' I I Sub l Hours I COd:l~o~e i 0.171 CMPL TN SFTY 2.33 CMPL TN NUND i I 3.00 CMPL TN SEQT Phase CMPL TN CMPL TN CMPL TN 1.50 MOVE I MOVE MOVE i 2.00 MOVE MOVE MOVE Page 4 of 4 Start: 12/30/2005 Rig Release: 1/7/2006 Rig Number: Spud Date: 7/15/1998 End: Group: Description of Operations ......... .....-.-...--- Pre-job safety meeting prior to lifting BOPE. Pick BOPE off casing flange with extreme caution to ensure penetrator integrity. Back stubborn casing head studs off of BOPE flange. Test ESP & heat trace----Test good. NU tree. test bonnet to, one of penetrators would leak above 3000 psi but good test to 3000 psi. Tested upper & lower tubing body test to 5000 psi. Test tree to 5000 psi. Cleaned cellar and released rig @ 20:30 hrs 1/7/2005. Did not freeze protect, Well Group will pump freeze protect when rig is out of way. Disconnect flowline, hoses etc. to each module. Scope derrick down. Lower derrick down to carrier. Blow down steam, disconnect all electrical. Unpin Carrier. Printed: 2/312006 10:55:35 AM e ConocoPhiUips Alala, Inc. TUBING (0-5444, 00:3.500, 10:2.992) KRU 'D-134 API: 500292289200 Well T e: PROD SSSV fyii~~t'J9.NE _ -- --- -- - -- 'Od -Com letion: 11/12/1998 Annular Fluid: DIESEL----. ---.------------- Last W/O: Rel.e!~.I1_c~_~C?g: ___._. 'ROOUCTlON (0-6209, 00:7_625, Wt:29.70) Interval TVD Zone GAUGE (5430-5431, 5551 - 5576 3586 - 3610 WSD 00:2.000) PUMP 5624 - 5640 3657 - 3672 WSB (5444-5474, 5712 - 5720 3742 - 3750 WSA3 00:4.720) 5732 - 5738 3762 - 3767 WSA3 5746 - 5752 3775 - 3781 WSA3 5766 - 5769 3795 - 3797 WSA3 5786 - 5822 3814 - 3849 WSA2 SEAL (5474-5488, 00:5_130) GEARBOX (5488-5489, 00:5.250) MOTOR (5489-5491, 00:5.250) Perf (5551-5576) Perf (5624-5640) Perf (5786-5822) Status Ft Comment 25 2 1/8" EJ, 0 deg phase/orient, nostim 16 5 8/11/1998 IPERF 2 1/8" EJ, 0 deg phase/orient, nostim 8 5 11/9/1998 APERF 2 1/8" EJ, 0 deg phase/orient, nostim 6 5 11/9/1998 APERF 2 1/8" EJ, 0 deg phase/orient, nostim 6 5 11/9/1998 APERF 21/8" EJ, 0 deg phase/orient, nostim 3 5 11/9/1998 APERF 2 1/8" EJ, 0 deg phase/orient, nostim 36 5 8/7/1998 (PERF 21/8" EJ, 0 deg phase/orient, ....'--_m."__._.___.. u.____._ _._._..._1.___ ___ ____.__no~ti!':1____________ .____.___.._._.__._. BAKER SENTRY GAUGE 120TP2000 PCP GSB3 DB 8L H6 PFS 9:1 525 SERIES 57 HP 1315/26 KMH ID 0.000 0.000 0.000 0.000 0.000 ) R.e: West Sak WelllD-134 (PTD 1981110) Subject: Re: West Sak Well1D-13 (PTD 1981110) From: Thomas Maunder <tom _ under@admin.stat Date: Thu, 28 Apr 2005 07:14:08 800 To: NSK Problem Well Supv <n1617@conocophillips.com> Brad, Thanks for the notice. Keep us advised of any plans. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, The E5P on well 1 D-134 (PTD 1981110) is no longer operational. The motor runs, but draws high current as the pump end is locked up. It will require a rig workover to repair. The well is currently 51. It has not been decided whether we are ready to pursue gas lifting the well. ConocoPhillips will notify the AOGCC under a separate communication if approval for gaslift is requested. Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907 -659-7224 SCiÅ,NNED Il¡PR 2 8 20fJ5 1 of 1 4/28/20057:14 AM MICROFILMED 7~30~02 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Saved as M:/weepie/microfilm_marker.doc 198-111-0 KUPARUK RIV U WSAK 1D-134 50- 029-22892-00 PHILLIPS ALASKAINC Roll #1: Start: Stop Roll #2: Start Stop MD 06224 TVD 04241 Completion Date: 11/12/98 Completed Status: 1-OIL Current: Name D 8767 L DGR/EWR4-MD L DGR/EWR4-TVD L SRVY RPT Interval Sent Received T/C/D 1,2 -/SPERRY MPT/GR/EWR4 OH 10/7/98 10/7/98 1,2 v/1216224 ill- b'z.Z."f OH 10/7/98 10/7/98 1,2 ~/ 1214241 OH 10/7/98 10/7/98 M,'SPERRY 0-6224.0 OH 8/19/98 8/26/98 Tuesday, January 09, 2001 Page 1 of 1 STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL E~] GAS ~-~ SUSPENDED E~ ABANDONED~] SERVICE ~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-111 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22892 4 Lo~tion of well at su~ace. . . 9 Unit or Lease Name '~,,ut~'~ 511'FNL, 601'FEL, Sec. 23, T11N, R10E, UM '~ '" ,''~ ~' ~"';~~~, Kuparuk River Unit AtTop Producing Inte~al~'" ~'~: .... ~;'~ 1166'FSL, 665'FEL, Sec. 23, T11,,R10E, UM ' ..~..:.:,:_ ~. ; WestSak1D-134 At Total Depth ~ 11 Field and Pool 1014' FSL, 669' FEL, Sec. 23, T11N, R10E, UM ~ ...... KUPARUK RIVER 5 Elevation in feet (indi~te KB, DF, etc.) ~ 6 Lease Designation and Serial No. West Sak Oil Pool RKB 41', Pad 71'] ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. ~15 Water Depth, if offshore 16 No. of Completions 15-Ju1-98 18-Jul-98 12-Nov-98~ NA feet MSL 1 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey 20 Depth where SSSV set 21 Thickness of permafrost 6224' MD & 4241' ~D 6071' MD & 4092' ~D YES ~ NO ~ NA feet MD 1517' APPROX 22 Type Electric or Other Logs Run GR/CCL 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58~ H-40 SURF. 121' 24" 260 sx AS II 7.625" 29.7~ L-80 SURF. 6209' 9.875" 1. 175 sx DLW, 278 sx Class G 2. 292 sx DLW, 60 sx AS I 24 Pedorations open to Production (MD+~D of Top and Boffom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 5497' N/A 5786'-5822' MD 3814'-3849' ~D 4 spf 5624'-5640' MD 3657'-3672' ~D 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 5551'-5576' MD 3586'-3610' ~D 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5712'-5720' MD 3742'-3750' ~D 5 spf 5786'-5822' MD see affachments 5732'-5738' MD 3762'-3767' ~D 5 spf 5624'-5640' MD 5746'-5752' MD 3775'-3781' ~D 5 spf 5551'-5576' MD 5760'-5766' MD 3789'-3795' ~D 5 spf Date First Production.,~,., IM~thod of OperatiOnGas(FIowing,Lift gas Ii., etc.) ~ ~ ! ~ ! I Date of Test Heurs Tested PRODUCTION FOf[OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL ~TIO 12/1/98 8 TEST PERIOB 130 7 10 100~ 79 Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (~) Press. 218 0 24-HOUR RATE: 376 30 29 0~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presen~ of oil, gas or water. Submit ~re chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9.r' ~' 30. '~'¢ GEOLOGIC MARKERS 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 West Sak Sand 5556' 3591' Base West Sak Sand 6005' 4027' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. / //~~/y~ Signed Title Shallow Sands Team Leader DATE /'_ Prepared by Name/Number Sharon Allsup-Drake/263-4612 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 Date: 10/14/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-134 WELL_ID: AK9669 TYPE: AFC: AK9669 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:07/15/98 START COMP: RIG:RIG # 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22892-00 07/15/98 TD: 1073' SUPV:DCL D1) 1073) 07/16/98 TD: 3978' SUPV:DCL D2) 2905) 07/17/98 (D3) TD: 5630' (1652) SUPV:DONALD LUTRICK 07/18/98 (D4) TD: 6224' (594) SUPV:DONALD LUTRICK 07/19/98 (D5) TD: 6224' ( 0) SUPV:DONALD LUTRICK 07/20/98 (D6) TD: 6224'( 0) SUPV:DONALD LUTRICK MW: 9.0 VISC: 245 PV/YP: 29/53 DRILLING APIWL: 8.6 Move rig from 1D-131 to 1D-134. Accept rig @ 0800 hrs. 7/15/98. NU diverter system and function test. Drilling from 121' to 1073' RIH MW: 9.5 VISC: 245 PV/YP: 39/57 APIWL: 7.8 Drilling from 1073' to 3978' Hole packed off in tight spot at 3938' while backreaming connection. Packoff was in BHA below jars. Worked pipe free. Back ream through tight spot from 3938' to 3915' slowly. Tight spot cleared up after reaming through first time. DRLG MW: 9.5 VISC: 210 PV/YP: 43/56 APIWL: 5.0 Drilling from 3978' to 5630' MW: 9.6 VISC: 190 PV/YP: 38/56 RU TO RUN CSG APIWL: 4.8 Drilling from 5630' to 6224' NU BOP MW: 9.5 VISC: 75 PV/YP: 24/28 APIWL: 6.2 PJSM. Pump 1st stage cement. MW: 9.0 VISC: 107 PV/YP: 27/22 WIPER TRIP W/ SCRAPERS APIWL: 20.0 Pump 2nd stage cement. ND diverter. NU BOPE and test. Drill out cement and stage collar at 2531' Drill out cement from 5790' to LC at 6077' Date: 10/14/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 07/21/98 (D7) MW: 8.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 6224'( 0) ABOUT READY TO MOVE RIG SUPV:MORRISON/CUNNINGHAM Run 3.5" tubing. Pump hog wash. Freeze protect well and equalize diesel between annulus and tubing. 07/22/98 (D8) MW: 8.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 6224'( 0) RIG RELEASED ~ 0600 TO MOVE TO WELL 1D-132 (75' AWAY FROM CP SUPV:CUNNINGHAM/MORRISON ND BOPE. NU tree and test, leaking, remove tree, new o-rings. NU tree and test to 3000 psi. Set BPV. Release rig ~ 0600 hrs. 7/22/98. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~. WELL SERVICE REPORT '~' K1(1D-134(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-134 FRAC, FRAC SUPPORT 0804980822.1 DATE DAILY WORK UNIT NUMBER 08/07/98 PERFORATE "A2" INTERVAL DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES SWS-STEPHENSON SCHWENDERMAN FIELD AFC# CC# Signed ESTIMATE AK9669 230DS10DL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 50 PSI 0 PSI 0 PSI 0 PSII 0 PSII 0 PSi DAILY SUMMARY RAN GR/CCL LOG F/6074' TO 5300'. RAN #1 2-1/8" ENERJET PERF GUN (18') PERFORATE 7" CASING F/5822' - 5804'. RAN #2 PERF ASSEM PERFORATED F/5804' - 5786' (18') ALL SHOTS FIRED. 2-1/8" ENERJET/BH/4SPF/0 DEG PHASING/0 DEG OREINT.[Perf] TIME LOG ENTRY 07:15 MIRU SWS (STEPHENSON AND CREW) TGSM WORKING IN RAIN. MU ASSEMBLY, WAS UNABLE TO GET GUN GR TOOLS TO WORK. MU GR / CCL / WT. TL= 21' PT LUB 3000 PSI. 09:30 RIH TAG DOWN AT 6074' AND TIE IN W/SPERRY SUN MWD GR LOG DATED 7/18/98 LOG UP TO 5300'. POH. 11:00 13:00 AT SURFACE SHUT IN WELL AND SECURED EQUIPMENT. WENT TO 20-09 WELL TO ASSIST HALLIBURTON RECOVER CHEMICAL CUTTER (FISH). CONTINUE OPERATIONS. MU #1 PERF ASSEMBLY. 18', 2-1/8" ENERJET/DH/4 SPF/0 DEG PHASING/0 DEG OREINT/SAFE FIRING HEAD/MPD/CCL/WT/SWIVEL. TL=36'. 14:00 RIH, TIE IN W/PREVIOUS CCL LOG. PERFORATE 7" CASING F/5822' - 5804' (18'), GOOD SURFACE INDICATIONS. POH. 16:00 AT SURFACE RD, ALL SHOTS FIRED. MU #2 PERF. ASSEMBLY ADDED 1 SET OF ROLLERS, PERF ASSEM SAME AS ABOVE. TL= 38'. 16:30 18:30 RIH, TIE IN AND PERFORATE 7" CASING F/5804' - 5786' (18'). GOOD SURFACE INDICATIONS. POH. AT SURFACE RD, ALL SHOTS FIRED, LEAVE WELL SHUT IN FOR FRAC FOLLOW UP. NOTIFIED DSO. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-134(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-134 FRAC, FRAC SUPPORT 0804980822.1 DATE DAILY WORK UNIT NUMBER 08/08/98 FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 YESI YES DS-GALLEGOS RIGGS FIELD AFC# CC# Signed ESTIMATE AK9669 18WSTF7SC InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann IlnitialOuterAnn I Final Outer Ann 55 PSI 888 PSI 6 PSI 900 PSII 10 PSI 0 PSI DALLY SUMMARY [Frac-Refrac] PUMPED FRAC PER PROCEDURE USING 50# HEC AND PROP LOC FLUIDS AT 20 BPM AND 2500#. PUMPED 116,110# 16/20 PROPANTW/115,530 # OF 10 PPG TO PERF'S REVERSED OUT 580 # FROM TBG.SCRENED OUT 36 BBL INTO 61 BBL FLUSH. NO SAND IN TBG EXPECT TO TAG FILL @ 5800' TO 5900' TIME LOG ENTRY 09:20 MIRU DS, TGSM, ( 19 PEOPLE ON LOCATION) PT LINES TO 5000# 10:15 PUMPED 128 BBL DIESEL DOWN BACK SIDE. SWITCH OVER TO WATER AND PUMPED THE 100 BBL BREAKDOWN. 10:45 PUMPED 100 BL WATER BRAKEDOWN @ 30 BPM AND 2800# DO STEP DOWN. SHUT IN TI GET ISIP. OF 750# DOEN PULSE TESTS. 11:45 PUMPED DATAFRAC 150 BBL WATER @ 15 BPM AND 1998 # PUMPED 69 BBL 50# HEC GEL @ 15 BPM AND 1945 # PERFORM STEP DOWN ISIP 888 # MONITOR PRESS. 12:45 PUMP 2ND PART OF DATAFRAC 31 BBL 50# HEC GEL @ 15 BPM AND 2225 # PUMPED 74 BBL FLUSH @ 15 BPM.DO STEP DOWN ,GET ISIP OF 902 # 15:45 PUMPED MAIN FRAC @ AVG RATE OF 20 BPM AND 2900 # W/50 # HEC GEL. W/16/20 PROPANT. PUMPED FLUSH SCREENED OUT 36 BBLS INTO FLUSH. SHUT DOWN AND REVERSED OUT W/80 BBL DIESEL. PUT AWAY 108,000# OF 10 PPG 16/20 PROP. TO PERF'S SHULD TAG FILL @ 5800 'TO 5900'. 18:10 RDMO DS ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT ,, K1(1D-134(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-134 FRAC, FRAC SUPPORT 0804980822.1 DATE DAILY WORK UNIT NUMBER 08/11/98 PERFORATE "B" INTERVAL DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 5 YES YES SWS-STEPHENSON SCHWENDERMAN FIELD AFC# CC# Signed ESTI MATE AK9669 18WST F7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 200 PSI 0 PSI 0 PSI 0 PSII 1700 PSII 1700 PSI DAILY SUMMARY IRAN 2-1/8" ENERJET PERF ASSEMBLY WAS UNABLE TO GET DOWN. CHANGED ASSEMBLY AND GOT DOWN. PERF F/5624' TO 5640' (16') BH/4 SPF/180 DEG PHASING/90 DEG ORIENT F/LOW SIDE. [Perf] TIME 17:00 18:30 21:00 00:00 01:00 LOG ENTRY MIRU SWS (STEPHENSON AND CREW) TGSM, WORKING AROUND OTHER LARGE EQUIPMENT. MU PERF ASSEMBLY 2-1/8" ENERJET (16' GUN,MPD,CCL,WT) TL-32', PT LUB TO 3000 PSI. RIH, UNABLE TO GET DOWN, STOPPING IN HIGH ANGLE 67 DEG. MADE MULTIPLE ATTEMPTS. POH ADD ROLLERS. STILL STOPPING, ADD MORE WEIGHT. NO GOOD. POH. ADD SWIVEL AND 6' WEIGHT RIH. WORKED DOWN TAGGED DOWN AT 5696' RKB. TIE IN AND ATTEMPT TO FIRE GUN, NO SURFACE INDICATIONS. POH. GUN MISSFIRED. CHANGED SWIVEL AND REMOVED ROLLERS. RIH W/ASSYMBLY (16' EJ GU NlM P D/CCL/WT/WT/SWlVEL/H EAD)TL--40'. RIH. WORKED DOWN AND TIED IN W/SCHLUMBERGER PERF LOG DATED 8/7/98. PERFORATED FROM 5634' TO 5640' (16') HAD GOOD SURFACE INDICATIONS. POH. 02:30 03:00 AT 200' WAITED FOR PARKER DRILLING TO COMPLETE CEMENT JOB ON LOCATION TO COMMENCE RADIO SILENCE. 05:00 POH RD. ALL SHOTS FIRED. LEAVE WELL SHUT IN FOR FRAC JOB. NOTIFIED DSO. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~' K1(1D-134(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-134 FRAC, FRAC SUPPORT 0804980822.1 DATE DAILY WORK UNIT NUMBER 08/11/98 B SAND FRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 5 YES YES DS-GALLEGOS JORDAN FIELD AFC# CC# Signed ESTIMATE AK9669 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann , Initial Outer Ann , Final Outer Ann 206 PSI 0 PSI 346 PSI 0 PSII 10 PSI 0 PSI DALLY SUMMARY B SAND FRAC SCREENED OUT WITH 7 PPA PROPPANT AT PERFS. LEFT 1500 LBS PROPPANT IN CASING AFTER REVERSING OUT. ESTIMATED TOP OF FILL 5636'. TIME LOG ENTRY 07:00 MIRU DS FRAC UNIT-GALLAGOS; APC; HES; LRS. TGSM. PT SURFACE LINES 6029 PSI OK. 09:41 LOAD CASING WITH 120 BBL DIESEL DOWN BACKSIDE. 10:08 PUMP HIGH RATE BREAKDOWN. SD ISIP 701 PSI. 10:53 PUMP DATA FRAC STAGES. SD TO ANALYZE. SET PAD AT 30 BBL. 13:01 PUMP FRAC ACCORDING TO MODIFIED PROCEDURE. SCREENED OUT WITH 7 PPA PROPPANT AT PERFS. CLEANED OUT TUBING BY REVERSE CIRCULATING DIESEL TO TANK. 16:00 RDMO DS FRAC UNIT. TOTAL PROPPANT PUMPED 61,821 LBS. TOTAL PROPPANT INJECTED 48,221 LBS. 12,100 LBS PROPPAND REVERSED OUT; 1,500 LBS LEFT IN PIPE. ESTIMATED TOP IF FILL IS 5636'. MAX TREATING PRESSURE 4436 PSI DURING BREAKDOWN. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~' K1(1D-134(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-134 FRAC, FRAC SUPPORT 0804980822.1 DATE DAILY WORK UNIT NUMBER 08/14/98 PERFORATE "D" SAND INTERVAL DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 7 YES YES SWS-ST E PH ENSON SCHWEN DERMAN FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE AK9669 18WSTF7SC $11,824.30 $383,707.29 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 100 PSI 150 PSI 0 PSI 0 PSII 0 PSI 0 PSI DALLY SUMMARY RAN 2-1/8" ENERJET GUNS 15'/BH/4 SPF/. TOOLS STOPPING UNABLE TO GET PAST 2000'. CHANGED ASSEMBLY. RIH TIE IN AND PERFORATE 7" CASING 15' F/5576' TO 5561'. RAN FERF ASSEMBLY #2 AND PERFORATE 7" CASING 10' FROM 5561' TO 5551'. TIME LOG ENTRY 07:30 09:00 10:00 11:00 MIRU SWS (STEPHENSON AND CREW) TGSM JOB OVERVIEW, PINCH POINTS. MU PERF ASSEBMLY (15' GUN/SAFE/MPD/CCI_/WT/WTSWVEL/HEAD) TL=38', PT LUB 3000 PSI. RIH, TOOLS STOPPING @ 1800', UNABLE TO GET PAST 2000'. POH. AT SURFACE RD, CHANGE TOOL ASSEMBLY. MU ASSEMBLY 2-1/8" ENERJET/DH/4 SPF/0 DEG PHASING AND 0 DEG ORIENT(15' GUN/SAFE/CCL/WT/WT/ROLLER/SWIVEL/HEAD) TL 39' RIH. TIE IN AND PERFORATE 7" CASING F/5576' TO 5561' GOOD SURFACE INDICATIONS. POH. 13:00 AT SURFACE RD. ALL SHOTS FIRED. MU ASSEMBLY #2 SAME AS ABOVE W/10' GUN. RIH TIE IN AND PERFORATE 7" CASING F/5561' TO 5551'. GOOD SURFACE INDICATIONS. POH. 16:00 AT SURFACE RD. ALL SHOTS FIRED. LEAVE WELL SHUT IN FOR FRAC. NOTIFIED DSO. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $1o.oo APC $200.00 $26,800.00 ARCO $0.00 $250.00 BAKER OIL TOOLS $0.00 $1,150.00 DIESEL $0.00 $8.40 DOWELL $0.00 $223,696.50 HALLIBURTON $0.00 $79,376.00 LITTLE RED $1,060.00 $12,220.00 RADIUS $0.00 $5,000.00 SCHL U M BE RG E R $10,564.30 $35,196.39 TOTAL FIELD ESTIMATE I $11,824.30I $383,707.29 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~' K1 (1 D-134(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-134 FRAC, FRAC SUPPORT 0804980822.1 DATE DAILY WORK UNIT NUMBER 08/15/98 D SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 8 YESI YES DS-GALLEGOS JORDAN FIELD AFC# CC# Signed ESTIMATE AK9669 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 170 PSI 1039 PSI 216 PSI 1269 PSI 0 PSII 0 PSI DAILY SUMMARY IPUMPED D SAND FRAC AS DESIGNED. TOTAL PROPPANT PUMPED 85,201 LB. TOTAL PROPPANT PLACED IN FORMATION 84,714 LB WITH 487 LB LEFT IN PIPE. ESTIMATED TOP OF FILL 5560, BOTTOM PERFS 5576~' = 16' FILL. MAX TREATING PRESSURE 5747 PSI. TIME LOG ENTRY 07:00 MIRU DS FRAC UNIT- GALLAGOS; LRS; APC; HES. TGSrvl, 18 ON LOCATION.PT LINES TO 6862 PSI. 08:00 FLUID PACK ANNULUS. CIRCULATE 68 BBL DIESEL DIESEL DOWN BACKSIDE TAKING RETURNS FROM TUBING TO OPEN TOP TANK. 08:30 PUMP 100 BBL HIGH RATE BREAKDOWN STAGE AT 30 BBL PER MINUTE. STEP DOWN AND PULSE TEST. DID NOT SEE GOOD BREAKDOWN. 09:00 REPEAT HIGH RATE BREAKDOWN STAGE. SD ISIP 778 PSI. 09:45 PUMP WATER DATAFRAC. SD ISIP 760 PSI. 11:00 PUMP GEL DATAFRAC. SD ISIP 795 PSI. 2371 PSI PC - MODIFY PUMP SCHEDULE. 12:05 PUMPED D SAND FRAC AS DESIGNED THROUGH FLUSH. TOTAL PROPPANT PUMPED 85,201 LB. TOTAL PROPPANT PLACED IN FORMATION 84,714 LB WITH 487 LB LEFT IN PIPE. MAX TREATING PRESSURE 5747 PSI. 15:00 RDMO DS FRAC UNIT. CIRCULATE 50 BBL DIESEL DOWN BACKSIDE UNTIL CLEAN DIESEL RETURNS TO TANK FROM TUBING. ESTIMATED TOP OF FILL 5560', BOTTOM PERFS 5576' = 16' FILL. Date: 12/10/98 kRCO ALASKA INC. WELL SUMMARY REPORT Page: REMEDIAL AND COMPLETION OPERATIONS WELL:iD-134 RIG:NORDIC # 2 WI: 0% SECURITY:0 WELL__ID: AK9669 TYPE: Ab'C: AK9669 STkTE:ALASIOt AP1 NL~4BER: 50-029..-221t92-00 AKEA/CNTY: NOETH SI,0PE EAST FIELD: KUPARUK RIVER I~IT BLOCK: SPUD:07/15/98 START COMP:].1/05/98 FINAL: 3,1/05/98 (C9) TD: 0' PB: 0' POH=LD 3-1/2" DEAD STRING MW: 8.6 BRINE SUPV:RICK 0VERSTRRRT Moving rig from 1H-01 Lo 1D-134. MIRU. ND tree, NU BOPE and test to 250/3500 psi.. 11/06/98 {C10) TD: 0 ' Pg: 6077 ' DRILLING OUT CARBOLITE TO SUPV:RICK OVERSTREET Pull tubing. RIH w/6.75" mill. MW: 8.7 BRINE 11/07/98 (Cll) TD: 0' PB: 6077' REVERSE CIRC. W/MULESKOE MW: 8,7 BRIN~.. :SUPV: RiCK Mill carbolite ~ 6071', hard bot. toi~, c~ntinued sand. Ciz~c, rob. ate and reciprocate, sand continued to run in. 11/08/98 {C12) TD: 0' PB: 6077' CLEANING SURFACE EQUIPMEN MW: 8.7 SUPV:RICK OVERSTREET Reverse circulate cleaning up carbo]ite and sand. BRI,NE 11/09/98 (C13) 'I'D: O' PB: 6077' P/U 3-]/~" TUBING W/ W1R~: MW: fl.7 BRINE SUPV:RICK 0VERSTREET Contillued to clean ho],e oC carbolite (sand). Pump ho9 wash, RII{ w/perforating guns. 11/10/98 (Clfl) TD: 0' PB; 6077' MAKING UP a SPLICING BAKE SUPV:M.C. HEIM Run Pe):'foYaEing guns. MW: 8.7 ~RIN'E 11/11/98 (C15} TD: ~' DB: 6077' NIPPLE UP TREE. SUPV:M.C. HEIM RIM with completion, run heat trace. MW: 8,7 BRINE 11/12/98 (C16) O' 6077' MW: 8.7 BRINE SUPV:M.C. HEIM N/D BODE. N/U tree and test packoff, test tree to 250/5000#. Prepar~ riq 'for move. R~leas~ ri~ ~ 1200 hrs. 11/12/98. ARCO Alaska, Inc. ' · Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 4, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-134 (Permit No. 98-111) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-134. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Senior Drilling Engineer AAI Drilling TWM/skad Kuparuk Unit Kuparuk 1D 1D. 134 SURVEY REPORT August, 1998 Your Reft API-500292289200 Last Survey Date 18-July.98 Job# AKMMS0290 KBE- 112.0' 0 t6tt,tkL DRILLING SERVICES Survey Reft svy46 Sperry-Sun Drilling Services Survey Report for ID-'134 Your Ref: API-500292289200 Kuparuk Unit Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth (~) (fi) (~) 0.00 0.000 0.000 -112.00 0,00 121.00 0.000 0.000 9,00 121.00 188.00 0.500 28.000 76.00 188.00 274.00 0.250 3,000 162.00 274.00 377.11 1.920 254.510 265.09 377.09 471,59 3.850 242.490 359.45 471,45 563.08 6.850 227.440 450,53 562.53 651.93 11.260 221.920 538.25 650.25 743,15 14.730 215.840 627.13 739,13 833.32 17.510 205.260 713.76 825.76 924.53 21.380 187.930 799.83 911,83 1014.85 27.020 177.850 882.21 994.21 1107.20 30.140 177.070 963.30 1075.30 1197.49 33.470 177.950 1040.02 1152.02 1287.80 39.210 178.840 1112.74 1224.74 1376.96 46,110 180.360 1178.26 1290.26 1468.49 49.610 180.570 1239.67 1351.67 1560.67 56.460 178.820 1295.07 1407,07 1650.45 59.310 180.100 1342,79 1454.79 1743,99 66.300 179.760 1385.52 1497,52 1934.38 65.360 180.70~_ 1463.47 1575.47 2219.24 65,080 180.900 1582.87 1694.87 2504.37 65.910 180.320 1701.13 1813.13 2788.25 65.710 179.100 1817.46 1929.46 3072.07 67.280 178,830 1930.65 2042.65 3355.51 66.660 178.770 2041.53 2153.53 3633.30 67.990 180.210 2148,63 2260.63 3914.59 66.480 181.780 2257.47 2369.47 4014,37 63.960 181.090 2299.29 2411,29 4108.09 62.320 181.030 2341.63 2453.63 Local Coordinates Northings (ft) 0.00 N 0.00 N 0.26 N 0.78 N 0.54N 1.35 S 6.46 S 16.50 S 32.54 S 54.10 S 83.02 S 119.87 S 164.00 S 211.53 S 265.OO S 325.38 S 393.24 S 466.84 S 542.87 S 626.02 S 799.71 S 1058.31 S 1317.74 S 1576.69 S 1836,91 S 2O97.7O S 2353.99 S 2613,31 S 27O3.87 S 2787.46 S Global Coordinates Dogleg Ve~ical Eastings Nothings Eastings Rate Section (~) (fi) (~) (°/100fi) (~) 0.00E 5959153.84 N 560490.83 E 0.00 0.00E 5959153.84N 560490.83E 0.000 0.00 0.14 E 5959154.10 N 560490.97 E 0.746 -0.26 0,32 E 5959154.62 N 560491.15 E 0.341 -0.78 1.33W 5959154.37 N 560489.50 E 1.953 -0.52 5.67W 5959152,45 N 560485.17 E 2.130 1.45 12.41W 5959147.28 N 560478.47 E 3.593 6.68 22.12W 5959137.16 N 560468.85 E 5.053 16.89 34,86W 5959121.03 N 560456.23 E 4.084 33.14 47.37W 5959099.36 N 560443.90 E 4.474 54.93 55.53W 5959070.38 N 560435.97 E 7.574 83.98 57.03W 5959033.52 N 560434.77 E 7.721 120.86 55.06W 5958989.41N 560437.10 E 3.402 164.94 53.01W 5958941.89 N 560439.53 E 3.724 212.43 51.54W 5958888.43 N 560441.43 E 6.383 265.87 51.17W 5958828.06 N 560442.28 E 7.824 326.23 51.72W 5958760.20 N 560442.28 E 3.828 394.09 51.28W 5958686,60 N 560443.31 E 7,584 467.67 50.58W 5958610.58 N 560444.63 E 3.396 543.67 50.47W 5958527.44N 560445.40 E 7.480 626.81 51.16W 5958353.74 N 560446.11E 0.668 800.49 54.77W 5958095.12 N 560444.58 E 0.117 1059.12 57.53W 5957835.68 N 560443.91 E 0.345 1318.55 56.22W 5957576.75 N 560447.30 E 0.398 1577.43 51.51W 5957316.58 N 560454.10 E 0.560 1837.53 46.05W 5957055.84 N 560461.67 E 0.220 2098.18 43.79W 5956799.57 N 560465.99 E 0.677 2354.40 48.27W 5956540.22 N 560463.60 E 0.744 2613.76 50.54W 5956449.65 N 560462.05 E 2.602 2704.34 52.09W 5956366.05 N 560461.18 E 1.751 2787.94 Comment Kuparuk 1D Con~'nued_. 17 August, 1998 - 8:32 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for '1D-134 Your Ref: API-500292289200 Kuparuk Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth Northings (ft) (ft) (ft) (ft) 4201.85 58.280 181.620 2388,08 2500.08 2868.86 S 4296,86 53.710 182.110 2441.20 2553.20 2947.56 S 4392.44 50,800 181.270 2499.70 2611.70 3023.10 S 4487.63 48.450 180.800 2561.36 2673.36 3095.60 S 4581.49 45.750 180.520 2625.25 2737.25 3164.35 S 4676.46 42.660 181.430 2693.32 2805.32 3230.54 S 4772.32 38.770 180.040 2765.97 2877.97 3293.05 S 4866.20 35.150 178.240 2840.97 2952.97 3349.48 S 4962.48 30.180 178.460 2922.00 3034.00 3401.40 S 5057.13 26.200 179.060 3005.41 3117.41 3446.09 S 5152.15 22.430 179.570 3091.98 3203.98 3485.21 S 5248.76 18.550 181.160 3182.46 3294.46 3519,02 S 5344.24 15.100 182.630 3273.84 3385.84 3546.63 S 5438.50 14.700 182,530 3364.93 3476.93 3570.85 S 5627.74 14.110 182.110 3548.22 3660,22 3617.88 S 5816.19 13.340 181.490 3731.29 3843.29 3662.57 S 6006.18 12.740 180.920 3916.38 4028.38 3705.43 S 6156.22 12.330 181.910 4062.84 4174.84 3737.98 S 6224.00 12.330 181.910 4129.06 4241.06 3752.45 S Local Coordinates Global Coordinates Dogleg Vertical Eastings Northings Eastings Rate Section (fi) (fi) (~) (°/100fi) (~) 53.97W 5956284.64 N 560459.96E 4.343 2869.37 56.52W 5956205.92 N 560458.04E 4.829 2948.10 58.76W 5956130.37 N 560456.41E 3.123 3023.67 60.07W 5956057,86 N 560455.68 E 2.497 3096.18 60.87W 5955989.11N 560455.43 E 2.885 3164.93 61.98W 5955922.90 N 560454.86 E 3.321 3231.13 62.81W 5955860.39 N 560454.53 E 4.167 3293.65 62.00W 5955803.97 N 560455.79 E 4.024 3350.05 60.50W 5955752,06 N 560457.71E 5.163 3401.94 59.52W 5955707.38 N 560459.05 E 4.216 3446.61 59.04W 5955668.27 N 560459.85 E 3.974 3485.71 59.21W 5955634.46 N 560459,95 E 4,057 3519.51 60.09W 5955606.84 N 560459.29 E 3.640 3547.14 61.18W 5955582,62 N 560458.40 E 0.425 3571.37 63.09W 5955535.56 N 560456.87 E 0.317 3618.43 64.50W 5955490.87 N 560455.81 E 0.416 3663.14 65.41W 5955448.00 N 560455.25 E 0.323 3706.01 66.21W 5955415,44 N 560454.72 E 0.309 3738.57 66.69W 5955400.97 N 560454.35 E 0.000 3753.04 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. ' Vertical depths are relative to V~;/-e-II. Northings and Eastings are relative to Well. ,,. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 181.010° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6224.00ff., The Bottom Hole Displacement is 3753.04ff., in the Direction of 181.018° (True). Comment Projected Survey Kuparuk 1 D Continued,.. 17 August, 1998 - 8:32 - 3 - DrillQuest 0 F! I I..I--I IM G SEFlk/ICE S WELL LOG TRANSMITTAL Tol State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 7, 1998 1D-134, AK-MM-80290 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22892-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518. (907) 273-3500. Fax (907) 273-3535 A I'~ I ~1 ~,~ I i'~----~--,, 0 Fi I I_1_1 ~ (~ S E l:l/.~ I I-- E S 19-Aug-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 D-134 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 6,224.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) AUG 26 1998 Alaska O$t & Gas 0ohs. Commission Anchor~e 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 1. 1998 Thomas W. McKav Shallow Sands Team Lcader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Prudhoc Bay Unit I D- 134 ARCO Alaska. Inc. Permit No. 98-111 Sur. Loc. 51 I'FNL. 60 I'FEL. Sec. 23. T 11N. R 10E. UM Btmnholc Loc. 980'FSL. 666'FEL. Sec. 23. T11N. R10E. UM Dear Mr. McKav: Encloscd is the approvcd application for permit to drill the above rcfcrcnccd well. PLEASE NOTE: Your request for an exception to the requirements of 20 AAC 25.033(e) and 25061(a) is NOT needed. Those requirements apply to exploratory and stratigraphic test wells only. Thc permit to drill docs not cxcmpt you from obtaining additional pcrmits required by law from othcr govcrnmcntal agcncics, and docs not authorizc conducting drilling opcrations until all other rcquircd permitting dctcrminations arc madc. Bloxvout prcvcntion cquipmcnt (BOPE) must bc tcstcd in accordancc with 20 AAC 25 035. Sufficicnt notice (approximately 24 hours) must be given to allow a rcprcscntative of the Commission to witncss a tcst of BOPE installcd prior to drilling new hole. Notice may be given bv. contacting thc Commission pctrolcum field inspcctor on thc North Slope pager at 659-3607. Robcrt N. Christcnson. P.E. Commissioner BY ORDER OF THE COMMISSION dlffEnclosurcs cc: Department of Fish & Game. Habitat Scction xv/o cncl. Dcpartmcnt of Environmental Conservation xv/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill lb Type of Well Exploratory BI StratigraphicTest BI Development Oil X Re-Entry Deepen Service [~ Development Gas [~ SingleZone X Multiple Zone D 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 71' feet Kuparuk River Field 3. Address 6. Property D~esignation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 511' FNL, 601' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1089' FSL, 666' FEL, Sec. 23, T11N, R10E, UM 1D-134 #U-630610 At total depth 9. Approximate spud date Amount 980' FSL, 666' FEL, Sec. 23, T11N, R10E, UM 7/1/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1D-135 6218' MD 980' @ TD feet 15' @ 120' feet 2560 4250' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 64.64° Maximum surface 1420 psig At total depth 1865 psig (TVD) 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) 24" 16" 62.5# H-40 Weld 79' 41' 41' 120' 120' +_2.00 CF 9.875" 7.625" 29.7# L-80 BTC MO£ 6177' 41' 41' 6218' 4250' 626 Sx Arcticset III & 309 Sx Class G & 60 sx AS I 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 Sudace Intermediate LinerPr°ducti°nOR] } AL Perforation depth: measured true vertical Anchorage 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X Signed21' I he~'~~.,,v~ ~ re by certify that the foregoing is true and correct~ ~--t° the best of my knowledgeTitle Shallow Sands Team Leader Date ~'~~ Commission Use Only Permit Number IAPInumber IApprovaldate ¢,,(2~ ~'¢ I See cover letter for C~ ~ _ ! J i 50- O,3, ff --- ~ ~ ~ c~ 2. ~' other requirements Conditions of approval Samples required I-- Yes I'~ No Mud Icg required E~ Yes [~ No Hydrogen sulfidemeasures r~Yes [~No Directional surveyrequired ~,Yes E~] No Required workingpressureforBOPE ~]2M [~~[~ 5M [-~ IOM [~ 15M Other: ORIGINAL SIGNED'BY by order of Approved by Rol3~Irt N_ (~hri~tc.n.~rCfl)mmissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. ,~-- ~' Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor j' ,. June 2, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-134 West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1 D pad. The well is designed including hydraulic fracturing stimulation treatments using resin coated type proppant material. The stimulation procedure is designed to control sand production expected in these unconsolidated formations. The well is planned as a producer well using a progressive cavity ESP ("ESPCP") to artificially lift the well. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak Pool Rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU and West Sak wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-134, such as shallow gas. There have been eight (10) Kuparuk wells and (14) West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is July 1, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Sinc~'/," ..,--) / (:.//_~/ / ' // Thomas A. Brockway Operations Drilling Engineer Attachments: cc: West Sak 1 D-134 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK6 Drill and CaSe Plan for West Sak 1D-134 (L5) Frac-for-Sand Control Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. , Spud and directionally drill 9-7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 7-5/8" 29.7# L80 BTC casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. 6. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3,000 psi. 7. Pick up 6-3/4" mill tooth bit with 3-1/2" drill pipe and collars. Trip in and drill out stage collar. Clean out to PBTD. 8. Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. 9. Swap well over to non-freezing completion brine. Filter brine to desired level. Trip out. 10. Pick up 3-1/2" tubing deadstring and TIH. Circulate filtered brine to desired level. 11. Hang tubing in wellhead, install back pressure valve, and nipple down BOP stack. Nipple up and pressure test production tree. Secure well. 12. Release rig. 1 D-134 (L5) Page I TAB,06/02/98,v1 Completion Plan for West Sak 1 D-134 (L5) Frac-for-Sand Control Producer Four-Stage, Frac-for-Sand Control Completion (Off Ri.q Fracs) General Procedure: Well Preparation . Stage 1 3. Rig up frac equipment on well, and pressure test lines and production tree. Pull back pressure valve, and pressure test tubing and annulus. Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. NOTE: The number of stages frac'd may decrease from four (4) to three (3) depending on log results and final completion design strategy. Rig up thru-tubing perf guns for Stage I frac job which includes the West Sak A2 sands. RIH with perf guns, and position guns on depth. 4. Perforate Stage 1 overbalanced, and POOH with E-line. 5. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 1 interval. 6. Mix epoxy ! resin coated proppant and perform frac-for-sand control frac job on Stage 1 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 1 from Stage 2 to follow. Pressure test sand plug as required. 7. RIH with slickline and confirm sand top above Stage 1 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 2 8. Rig up thru-tubing perf guns for Stage 2 frac job which includes the West Sak A3 sands. RIH with perf guns, and position guns on depth. 9. Perforate Stage 2 overbalanced, and POOH with E-line. 10. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 2 interval. 11. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 2 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 2 from Stage 3 to follow. Pressure test sand plug as required. 12. RIH with slickline and confirm sand top above Stage 2 perfs. Use CTU as required to jet sand plug top to desired PBTD. 13. Rig up thru-tubing perf guns for Stage 3 frac job which includes the West Sak A4 and B sands. RIH with perf guns, and position guns on depth. 14. Perforate Stage 3 overbalanced, and POOH with E-line. 1 O-134 (L5) Page 2 TAB,06/02/98,v1 15. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 3 interval. 16. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 3 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 3 from Stage 4 to follow. Pressure test sand plug as required. 17. RIH with slickline and confirm sand top above Stage 3 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 4 18. Rig up thru-tubing perf guns for Stage 4 frac job which includes the West Sak D sands. RIH with perf guns, and position guns on depth. 19. Perforate Stage 4 overbalanced, and POOH with E-line. 20. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 4 interval. 21. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 4 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 4 from tubing tail. Pressure test sand plug as required. 22. RIH with slickline and confirm sand top below tubing tail. Use CTU as required to jet sand plug top to desired PBTD. 23. Set back pressure valve in tubing hanger, pressure test production tree and secure well. Release frac, E-line, CTU, and slickline equipment as required. Pull Deadstring, Clean Out Well, Run ESP and Production Tubinq 24. MIRU completion rig on well. Nipple down production tree and nipple up BOP stack on wellhead. Install 3-1/2" rams unless VBR's are available. Pressure test BOP stack to 3,000 psi. 25. Pull back pressure valve. 26. Pull tubing hanger and circulate well to clean brine as required. 27. TOH and lay down deadstring. 28. Pick up rock bit and casing scraper and TIH with workstring. 29. Clean out sand plugs, proppant, and perforating debris to PBTD below base of West Sak interval. 30. Circulate well to clean brine. TOH with workstring. 31. Pick up Centrilift ESPCP (progressive cavity ESP) motor, seal assembly, and tubing crossover on 3-1/2" production tubing. 32. Run in well with ESPCP motor assembly with power cable and data gathering information wire attached to tubing. 33. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 1 D-134 (L5) Page 3 TAB,06/02/98,v1 34. Position ESPCP at desired depth, set tubing hanger and run electrical penetrators through same. 35. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 36. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. 37. Release rig and turn well over to production. Note: For E-line retrievable ESPCP pumps, the pump components may be run in the well with slickline after the completion rig has released from the well. 1 D~134 (L5) Page 4 TAB,06/02/98,v1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1 D-134 (L5) Drillin_q Fluid Type Extended Bentonite Slurry Drillin_q Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12 % Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A combination surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately 200 feet TVD below the base of the permafrost interval. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-134 (L5) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. 1 D-134 (L5) Page 1 TAB,06/02/98,v. 1 Based on actual well test data from the nearby WSI-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg I::MW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,626' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/fi from the West Sak base to surface, the following MASP can be computed: MASP = (4055 ft)(0.46 - 0.11 psi/fi) - 1420 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7-5/8" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 7- 5~8" 29.7# L80 BTC-MOD casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. A deadstring will then be run in the well in preparation for off-rig perforating and fracture stimulation treatments. A completion rig would then return to the well following fracture stimulation work to remove the deadstring, and to install the ESP pump, power cable, heat trace, and production tubing. Drillinq Area Risks: Drilling risks in the West Sak 1D-134 (L5) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-134 (LS). Well Proximity Risks: The nearest existing well to West Sak 1D-134 (L5) is WS 1D-135 (G7). As designed, the minimum distance between the two wells would be 15.0' at 120' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-134 (L5) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 7-5/8" combination surface / production casing and prior to the drilling rig moving off of the well. 1 D-134 (L5) Page 2 TAB,06/02/98,v. 1 Cr~oted by .nth For: BROCKWAY Date plotted : 28-May-98 P[ol Reference ;s W~ 1D--134/L5 Vets, Ceotd;netes ere M feet reference slot T~e Ve~icel Depths ere rel~ence ~8 (Perker ~2~). I :RC 0 Alaska, Field : Kuporuk River Unit Location : North Slope, £os! (feet) -> 300 0 300 I I I I I 300 300 300 600 9OO 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 500 181.01 AZIMUTH 3681' (TO TARGET) ***Plone of Proposol*** RKB ELEVATION: 1 12' KOP TVD=300 TMD=300 DEP=0 BEGIN TURN TO TARGET TVD=400 TMD=400 DEP=O 6.92 10.98 15.59 DLS: 5.00 dog per 100 fi 20.59 25.26 50.17 35.10 40.05 45.01 49.97 92 EOC TVD=1435 TMD=1695 DEP=658 B/ PERMAFROST TVD=1629 TMD=2149 DEP=1067 MAXIMUM ANGLE 64.64 DEG BEGIN ANGLE DROP TVD=2459 TMD=4087 DEP=2818 TARGET ANGLE 13 DEG ESTIMATED SURFACE LOCATION: 511' FNL, 601' FEL SEC. 25, T11N, RIOE 270 Az Begin Tum to Terget/p Bose Permafrost TARGET LOCATION: 1089' FSL, 666' FEL SEC. 2.3, T11N, RIOE TARGET TVD=3776 TMD=5732 DEP=3680 SOUTH 3680 WEST 65 Begin ~gle Drop .~ Ugnu Sends End Angle Drop/~ ~ ~, Too WestSek Sand~/ I \ Bose West SeA Sonds~ I&l / TO -- 7 5/8 CosMg Pt~ 30O 600 900 1200 1500 0 --i- 1800 ~ 21 O0 ~ I v 24O0 2700 3000 3300 3600 64.11 56.11 48.11 3900 4-4.1 1 40.11 36.11 T/ UGNU SNDS TVD=5012 TMD=4§24 DEP=5451 32.11 DLS: 4.00 deg per 100 28.11 24.11 20.11 ,. 16.11 , END ANGLE DROP TVD=3431 TMD=5578 DEP=5601 ~. I TD LOCATION: 1 ....... I,~ 980¢ 'FSi: ~666.L FEL \ T/ W SAK SNDS WD=3626 TMD=5578 DEP=3646~ TARGET - A3 TVD=3776 TMD=5732 DEP=3680 ~ B/ W SAK SNDS WD=4055 TMD=6018 DEN=3745 ~ _ TD - CSG PT TVD=4250 TMD=6218 DEP=3790 I i i 0 300 I i i [ i I I i I i ii I ii I I i i i 600 900 1200 1500 1800 21 O0 2400 2700 3000 3300 Verficel Section (feet) -> Azimuth 181.01 with reference 0.00 N, 0.00 E from slot #134 i i i 5600 3900 IrC~o~,~ ~ f~n~For: RROCk'~AY Oote plotted: 28-U~y-98 Rial Reference ~s ~ 1D-134/L5 Vets. ~. / ~ / aska, In . Structure : Pad 1D Well: 154 Field : Kuparuk River Unit Location : North Slope, Ala 6O 40 2O 0 20 80 10o 120 140 160 180 200 220 240 26O 28O 300 <- West (feet) ' East (feet) -> 60 140 120 (~00 80 60 40 20 0 20 40 60 80 100 120 140 16( I I I I I I I I I I / I I I ./ I I I I / I -- I I I I I I I I I ~o %, ~oo _j?__o_o__ ............ 0 ~800 ,,"'lo 70_0. .... 2_°_~ .... -~--~--~-~ .... "'""' '""'" -9,-see ...... 'X,~; 1700 '""~00 // / ,,'"' 90C 600 ./. uu// /t200 ,," /// / ,oo 7// ......., ,ooy/, ,o ,,,,.," /'600 ~: ,,4'oo / o lOOO ~ ,,, ooo 1~oo t ~6°° · " 1 ,; _~j_5__O0 700 1200 ,," ]oo / ~ ........... [ 300 ,,,,' / 7oo ..... . aoo [ 14.oo ," 11 O0 /' " ; 500 '"- " '-. 900 ," / _~ ...... O0 '-.. i1700 .' 1300 . '-. I ," / i 800 -,. 500 ( 1200 / / '"'.,,. 900 900/ 3000 250d' 2100 1600 ¢--aO0 ", 600 !1000'-.... ' %. 1 6100 / "' ~ ". 20 ,' ",, i 1800 / , ',. 11 O0 ,, 14-00 900 ~, 700 ........... / ,, / ', ,, ,,, ',,, / ,, ~ / '~ 80~) /~ooo / / ] ',,I i \',,~ 1900 / 1500 _,' // [ 1000 '~, i I ",,,, ,' / : ] '; 900 / ! / ," 1600 i i 2000 " i 1100 i ' /1100 : ' / II , ; ~ 1000 ,, / ",, ........ .......... ..... , 60 140 120 100 80 60 40 20 0 20 40 60 80 100 120 140 160 <- West (feel)' East (feel)-> 60 40 20 200 22O 24O 260 28O 300 18o 160 80 100 (- 120 '-~ ,--I- 14o I C~o~ ox ~.~h For: BROCKqYAY [3ote platted: 28-Uoy-g8 PrOt R~ference is ~ 10-134/L5 Vets. Coord;notes ore ;n feet reference sloL ~154. a I~c. Structure : Pod 10 l: 134 Field : Kuperuk River Unit Locotion : North Slope, Alasko 2OO 240 280 .320 360 400 440 48O 520 560 6O0 I V 640 68O 72O 760 8OO 840 880 920 960 1200 <- West (feet) 520 280 240 200 160 120 80 40 0 4-0 80 120 160 %%)200 24-0 280 ' ' ' ,~oo , ~oo... ,,,, ~oo% i / ',, ~ooo o i ,\ '\ ".., ~./2100 '"'\ 10~ ~0~'" ',.140£.; 17oo i~2oo ,,, ',, i~1 O0 , i2200 : \ 1.300 i ~ 1200 , ; ,' ~ 2300 \ ~ 1300 ," " ~ 9o0 ,,' \ I ', 13O0 ~ 400 ? 24OO 2000 ! ! ~ 4oo ; \ ,,' ,,, ,,, \, / ~ 400 ¢ 2500 '\ ; \ / ", 2100 ; ',, ; \ ,,' ~5op \ ',,, ,, \, / ",, ~°° , i 320 280 240 200 160 120 80 40 0 40 80 120 160 200 240 280 <- West (feet 2OO 24O 280 520 560 400 44O 480 520 0/3 0 (- --i-- 56O riO0 I 640 V 68o 72O 76O 800 84O 88O 920 96O IvC,eote~ ~y t;r~ For: BROCKWAY Dote platted: 28-1~oy-98 Plot Reference ia ~ 1D-154/L~ Vets. ~. as Inc. Structure : Pod 1D II 134 Field : Kuporuk River Unit Locofion : North Slope, Alosko 7oo 8OO goo lOO0 1100 1200 1300 1400 1500 1600 1700 I V 18oo 1900 2000 2100 2200 2300 2400 250O 2600 8OO 7O0 _60O I ,/~ I I I t I ~2 /' 1500 /' / / , ~ 1700 2100 2300 <- West (feet) 500 400 500 200 1 O0 0 100 200 300 400 500 600 700 1900 ' / ' I , / ; / l : / 3500 5OO 3100/ / ! / ! ! ; / ! ! / ; 3300 [ 2700/ 23o~, / ! / / / 2900 ~ 2500 / ! / I / ! ! ! / 2100, 2300i ~,~l I ~ I I I I I ; 31500 1700 1900 2700 2900 3100 3300 3500 3700 5900 · I I I..,. II I I I I ..,,,,,,,. '""% ~3100 1700 1900 \ 2100 '\ 2300 2500 ! 2700 / 800 700 600 500 400 300 200 1 O0 0 100 200 500 400 500 600 700 <- West (feet) 7OO 8OO 900 IOO0 1100 1200 1300 1400 1500 1600 1700 I 18oo V 1900 20O0 2100 2200 2300 2400 2500 2600 West' Sak 1 D-134 (L5) Producer Well Four (4) Stage Frac-for-Sand Control with 3-1/2" Deadstring 16" Conductor Casing @ 80' Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) 3-1/2" Tubing Deadstdng 9.3# L-80 EUE 8RD-Mod (to frac through off-dg) 7-5/8" Casing Marker Joint 29.7# L-80 BTC-Mod (set +/- 50' above top perforation) D Sand Frac'd with Resin Coated Proppant B + A4 Sands Frac'd with Resin Coated Proppant A3 Sand Frac'd with Resin Coated Proppant 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD Cemented to Surface (+/- 6218' MD / 4250' 'I-VD) A2 Sand Frac'd with Resin Coated Proppant Anchorage ARCO Alaska, Inc. TAB, 05/18/98, v.1 WeS'[ Sak 1 D-134 (L5) Producer Well Four (4) Stage Frac-for-Sand Control Completion 3-1/2" Production Tubing 9.3# L-80 EUE 8RD-Mod 16" Conductor Casing @ 80' Raychem Heat Trace (through permafrost) Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) Power Cable for ESP Centrilift Camco 3-1/2" x 1" 'KBMM' Gas Lift Mandrel Arctic Lift 3500 psi Shear circulating valve pre-loaded in GLM (circulate well for freeze protection purposes) ESP Pump Section Centrilift ESP Gearbox Centrilift 7-5/8" Casing Marker Joint 29,7# L-80 BTC-Mod (set +/- 50' above top perforation) ESP Motor Section Centrilift D Sand Frac'd with Resin Coated Proppant 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD Cemented to Surface (+/- 6218' MD / 4250' TVD) B + A4 Sands Frac'd with Resin Coated Proppant A3 Sand Frac'd with Resin Coated Proppant Resin Coated Proppant J-~ ..... ~,. ~ ARCO Alaska, Inc. TAB, 05/18/98, v.2 ARCO Alaska, Inc. Pad 1D slot #134 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : WS 1D-134/LS Vets. 93 Our ref : prop2188 License = Date printed : 28-May-98 Date created = 16-A~r-~7 Last revised : 27-May-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is n70 17 56.290,w149 30 36.428 Slot Grid coordinates are N 5959153.711, E 560490.115 Slot local coordinates are 511.00 S 601.00 W Projection type: alaska - Zone 4, Spheroid= Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indlcate~ by an asterisk, e.g. 487.4* Object wellpath PMSS ¢0 - 7340f>,,10,Pad 1D PMSS <556-7024f>,,9,Pad 1D MSS ¢3311-8200'>,,7,Pad 1D PGMS <O-8610~>,,6,Pad 1D PGTLg <O-8930~>,,5,Pad 1D PGMS <O-7502~>,,4,Pad 1D PGMS <O-8070'>,,3,Pad 1D PGMS <0-9783'>,,2,Pad 1D PGMS <0-8365f>,,1,Pad 1D 1D-D Version #2,,1D-D,Pad 1D 1D-F Version #2,,1DoF,Pad 1D 1D-B Version #3,,1D-B,Pad 1D TOTCO Survey,,WS-8,Pad 1D PMSS ¢0-5462~),,J3,Pad 1D WS 1D-127/L1 Vets. #3,,127,Pad 1D WS 1D-128/K2 Vers. #3,,128,Pad 1D WS 1D-126/J1 Vets. #5,,126,Pad 1D WS 1D-132/K4 Vets. #3,,132,Pad 1D WS 1Do110/C3 Vets. #3,,1lO,Pad 1D WS 1D-125/H2 Vets, #3,,125,Pad 1D WS 1D~123/G1 Vets. #3,,123,Pad 1D WS 1D-122/F2 Vets. #3,,122,Pad 1D WS 1D-116/61 Vets. #3,,116,Pad 1D WS 1D-114/D2 Vets. #3,,114,Pad 1D WS 1D-113/C1 Vets. #3,,113,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 28-Apr-98 45.0 100.0 100.0 29-Apr-98 375.0 120.0 120.0 E-Nov-97 28.0 300.0 300.0 13-Nov-97 147.1 375.0 6218.0 13-Nov-97 267.5 300.0 300.0 4-Aug-92 387.6 400.1 400.1 4-Aug-92 508.0 20.0 375.0 4-Augo92 627.8 375.0 375.0 10-Dec-97 747.9 400.1 400.1 24-Nov-9? 163.0 300.0 300.0 24-Nov-97 43.0 300.0 300.0 24-Nov-97 133.0 300.0 6080.0 21-May-98 35.2 850.0 850.0 1-Dec-97 119.8 425.0 425.0 27-May-98 189.4 575.0 575.0 2T-May-98 167.0 700.0 700.0 27-May-98 209.8 425.0 425.0 27oMay-98 46.0 775.0 775.0 27-May-98 553.0 300.0 300.0 27-May-98 223.0 375.0 400.1 27-May-98 297.0 425.0 425.0 2T-May-98 313.0 300.0 300.0 27-May-98 433.0 300.0 300.0 2T-May-98 463.0 260.0 260.0 27-May-98 478.0 300.0 300.0 WS 1D-112/A1 Vets. #3,,112,~ 1D WS 1D-III/B2 Vets. #3,,111,Pad 1D WS 1D-136/J7 Vets. #1,,136,Pad 1D PMSS <0-4414'>,,GS,Pad 1D PNSS <0-4530'>,,F6,Pad 1D PMSS <0-4515'>,,F4,Pad 1D PMSS <0~4590'>,,ES,Pad LD PNSS <0-5142'>,,E3,Pad 1D PMSS <0-5205'>,,E7,Pad 1D PMSS <0-5047'>,,G3,Pad 1D PMSS <0~4850'>,,D4,Pad 1D PMSS <O-5126'>,,D6,Pad 1D PMSS <381-6092'>,,C7,Pad 1D WS 1D-158/Lll Vers. #1,,158,Pad 1D W$ 1D-141/A11 Vers. #1,,141,Pad 1D WS 1D-142/B10 Vers. #1,,142,Pad LD WS 1D-140/A9 Vets. #1,,140,Pad 1D WS 1D-139/B8 Vets. #1,,139,Pad 1D WS 1D-143/C9 Vets. #1,,143,Pad 1D WS 1D-144/D8 Vets. #1,,144,Pad 1D WS 1D-145/Cll Vets. #1,,145,Pad 1D WS 1D-146~D10 Vers. 91,,146,Pa~ 1D WS 1D-147fE9 Vets. #1,,147,Pad 1D WS 1D-148fE11 Vets. #1,,148,Pad 1D WS 1D-149rF8 Vets. #1,,149,Pad 1D WS 1D-152~G9 Vets. #1,,152,Pad 1D WS 1D-150/F10 Vets. #1,,150,Pad 1D WS 1D-153/H10 Vets. #1,,153,Pad 1D WS 1D-154/J11 Vets. #1,,154,Pad 1D WS 1D-155/H8 Vets. #1,,155,Pad 1D WS 1D-156/J9 Vets. #1,,156,Pad 1D WS 1D-157/K10 Vets. #1,,157,Pad 1D WS 1D-159/L9 Vets. #1,,159,Pad 1D WS 1D-160/K8 Vets. #1,,160,Pad 1D WS 1D-161/L7 Vets. #1,,161,Pad 1D WS 1D-138/K6 Vets. #1,,138,Pad 1D WS 1D-151/G11 Vers. #1,,151,Pa~ 1D WS 1D-107/B4 Vets. #1,,lO?,Pad 1D WS 1D-102/A5 Vets. #3,,102,Pad 1D WS 1D-103/B6 Vets. #3,,103,Pad 1D WS 1D-104/A7 Vets. #3,,104,Pad 1D WS 1D-108/A3 Vets. #3,,108,Pad 1D PMSS <1957-5265'>,,JS,Pad 1D WS 1D-101/C5 Vers. #3,,101,Pad 1D PMSS <O-5015'>,,GT,Pad 1D PMSS <0-4778'>,,H4,Pad 1D WS 1D-131/L3 Vets. #3,,131,Pad 1D 27-May-98 27-May-98 27-May-98 8-Dec-97 19-Dec-97 16-Dec-97 22-Dec-97 30-Dec-97 7-Jan-98 6-Jan-98 12-Ja~-98 19-Jam-98 27-Jan-98 27-May-98 27-Hay-98 27-May-98 27-May-98 15-Apr-97 15-Apr-97 15-Apro97 15-Apr-97 15-Apr-97 15-Apr-97 15-A~r-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 27-May-98 2?-May-98 27-May-98 27-May-98 15-Apr-97 27-Ma7-98 27-May-g8 27-May-98 27-Ma7-98 2?-Hay-98 24-Nov-9? 27-May-98 13-Nov-97 9-Nov-97 2?-May-98 493.0 538.0 27.8 330.0 345.0 360.0 404.5 450.0 420.0 240.0 570.0 615.0 644.5 188.8 267.6 256.7 278.9 290.5 246.2 236.2 226.8 218.0 209.9 202.6 196.2 183.0 190.7 180.9 180.0 180 4 182 0 184 8 193 9 199 9 206 9 62.0 186.3 598.0 688.0 673.0 658.0 583.0 60.0 703.0 15.0 105.0 76.9 260.0 300.0 575.0 100.0 100.0 100.0 400.1 180.0 120.0 100.0 100.0 120.0 300.0 280.0 260.0 300.0 300.0 260.0 300.0 300.0 300.0 300.0 300.0 300.0 300.0 300.0 300.0 300.0 300.0 300.0 300.0 300.0 260.0 300.0 300.0 260.0 300.0 300.0 300.0 300.0 280.0 300.0 100.0 300.0 120.0 120.0 650.0 260.0 5025.0 575.0 100.0 100.0 100.0 400.1 180.0 120.0 100.0 100.0 120.0 300.0 260.0 260.0 300.0 300.0 5580.0 300.0 300.0 3OO.O 300.0 300.0 300.0 300.0 300.0 300.0 3OO.0 30O.O 300.0 300.0 300.0 260.0 300.0 300.0 260.0 300.0 300.0 300.0 300.0 280.0 300.0 5920.0 400.1 120.0 120.0 650.0 8 ,7 , J 6 13 5/8" 5000 PSI BOP STACK West Sak Operations - Producer Wells ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID, 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES, BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE MNE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7. TEST TO 250 PSI AND 3(X)0 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PS! HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTI'OM RAMS TO 250 PS! AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BUND RAMS AND TESTTO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESELAND ALL VALVES ARE SET IN THE DRILUNG POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILMNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2' TO 6' OR 4-1/2' TO 7' PIPE ODS AS APPROPRIATE. 1. 16--STARTING HEAD 11' - 5000 PSI HORIZONTAL TUBING HEAD 3. 11' 50(X) PSI X 13-5/8' 50(X) PSI DOUBLE STUDDED ADAPTER/SPACER SPOOL 4. 13-5/8' - 50(X) PSI X 13-5/8' - 5000 PSI SPACER SPOOL 5. 13-5/8' - 5000 PSI PIPE RAMS 6. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 7. 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP. BLIND RAMS ON BTM 8. 13-5/8' - 5CXX) PSI ANNULAR TWM, 9/22/97 KUPARUK RIVER UNIT- WEST SAK OPERATIONS 20" DIVERTER SCHEMATIC I 5 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 4 f2 .1 HCR . MAINTE~NANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THATAN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC.. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"- 2000 PSI ANNULAR PREVENTER. TWM, 9/15/97 10 ' 122 123 ~ 5 124 N '125~ 126 127~ 128 ,134~ LEGEND sEE SHEET J 2 FOR NOmS ~D LO~TION INFORMATION o gx/sr/~ conductors gOUNSBURY · "AS-STAKED" CONDUCT~ LOCA~ON~l~/j~ A ASSOCiATeS, [NC. ~ "PR~OSEO" CONDUCTOR L~A ~ON ~ ~-~as P~RS SURV~YO~ ~EA' lO M~LE XX UNIT' ARCO Alaska, Inc Ik DRILL SI~ 1-D " ~ ~ST SAK PHASE lB - ~ CONDUCTORS AS-STAKED LOCA~ONS LK6104D14 5/16/98 NSK 6.104-d14 ~ 9F,2 0 I. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. PIT I1 ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN C SEA LEVEL. ALL DISTANCES SHO~ ARE TRUE. Y9 MONUMENTS PER LHO AND ASSOCIATES. ~~~ 14 ~ 23, m~SHIP. I' NOR~, RANGE 10 EAS~ U.M. ~l,~)i ~ST FROM A. SP. ZONE 4 GRID NORTH,~ 'CONDUCTORS 7-8; C~A-DIDX-6IO4D,O FOR CONDUCTORS 21 105,106,109,115.117-121,124,129,130,133 ~ 135; AND CEA-DIDX-6104DI3 FOR CONDUCTORS 9 ~ 10. HClNI ~ MA P SCALE: I" = I MILE J SEC. SEC. PAD O.G. Well A. S.P. s 'X' LA TI TUDE L ONGI TUDE No. 'y' ~ ~ ELE~ ELE~ Sec. 14, T. 11 N., R. IO E. F.S.L. FE.L. 1o8 ~5,959,738.9 560,490.6 70' 18' o2. o5' I49' 30' 36.28' 74' 596' 70.4' 62.4' 11o ,~5,959,7o8.9 560,490.6 70' 18' oi. 75" 149' 30' 36.28" 44' 596' 70.4' 66.5' ~I1 ~5,959,693.9 560,490.6 70' 18' 01.6o' 149. ~o' 36.29" 29' 596' 70.4' 66.5'~ Sec. 23, T. 11 N., R. IO E. F.N.L.~E.L. 112 ~5,959,64&9 560,490.6 70' 18' oi. 16" I49' 30' ~6.3o" 16' 597' 70.4' 63.1' 113 ~5,959,633.9 560,490.6 7o' 18' Ol. O1" I49' 30' 36.3o" 31' 597' 70.4' 63.2' 114 ~5,959,618.9 560,49o. 6 70' 18' 0o. 87' 149' 30' 36.30' 46' 597' 70.4' 63.2' 116 ~5,959,588.9 560,490.6 70' 18' oo. 57" 149' 30' 36.31' 76' 597' 70.4' 63.3' 122 5,959,469.0 560,490.7 70' 17' 59.39" 149' 3o' 36.34' 196' 598' 70.5' 64.1' 123 5,959,453.9 560,490.7 70' 17' 59.24" 149' ~o' 36.34" 2II' 598' 70.4' 64.2' 125 5,959,379.2 560,490.7 70' 17' 58.5I" 149' 30' 36.36" 286' 599' 70.3' 64.3' 126 5,959,363.9 560,490.7 70' 17' 58.36" 149' 30' 36.36" 301' 599' 70.3' 64.3' 127 5,959,3~&9 56o, 490.7 70' 17' 58.21' 149' 30' 36.36' 316' 599' 70.3' 64.3' 128 5,959,334.1 560,490.7 70' 17' 58.~" 149' 30' 36.37" 331' 599' 70.3' 64.5' 131 5,959,2~4. o 560,490.7 70' 17' 5x18" 149' 30' 36.39" 421' 600' 70.5' 69.9' 132 5,959,229.2 560,490.7 70' 17' 5z03" I49' 30' 36.39" 436' 600' 70.4' 69.8' 134 5,959,15~.8 560,490.8 70' 17' 56.29" 149' 30' 36.41" 5II' 6oi' 70.5' 69.1' · ~ Proposed location, work in progress [~[ & ASSOCIATES, INC. ~ ENGINEE~ P~NNERS Aa[A: ~ .as[ - conductors as- toc o s , ,~:,~,~,, ~/~/o~ N~K 6.104-d14 2 o~ 2 0 · WELL PERMIT CHECKLIST COMPANY. ~'~ )/2,, ( ~ WELL NAME ~ ~ ~ ~ r~-l~ PROGRAM: exp [] dev,,~redrll [] serv [] wellbore seg I::1 ann. disposal para req II FIELD & POOL INIT CLASS ¥") £ ,J I - fO ,' I, GEOL AREA ~ c~ 0 UNIT# I I I (¢ O ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... ENGINEERING 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~;(~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. .~N N N N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide m~. Y N .,/.A 31. Data presented on potential overpre~es ....... Y N 32. Seismic analysis of shallo~~ones ............. Y N 33. Seabed coney (if off-shore) ............. Y N 34. Cont~~rogress reports ....... Y N exploratory only] ANNULAR DISPOSAL APPR DATE With proper cementing records, this plan 35. (A) will contain waste in a suitable rec~ ...... Y N (B) will not contaminate fr.~C~cause drilling waste... Y N . to surface; (C) will not im'p~nical integrity of the well used for disposal; Y N (D) will ,no~. mage producing formation or impair recovery from a Y N po,9~f¢, and (E~),/~ill not circumvent 20 AAC 25.252 or 20,,~AC 25.412. Y N GEOLG)GY: ENGINEERI,.NG: U]C/An~ar COMMISSION: M:chel~list rev 05/29/98 dl f: C:\msoffice\wordian\diar~a\che(iMist PLEASE NOTE: co Co "'/Z¢ Your request for an exception to the requirements of 20 AAC 25.033(e) and 25.061~ NOT needed. Those requirements apply to exploratory and stratigraphic test wells onl Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. ... No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Tue Sep 29 15:57:13 1998 Reel Header Service name ............. LISTPE Date ..................... 98/09/29 Origin ................... STS Reel Name .............. ~.UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 98/09/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT (WEST SA/{) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-80290 S. GONIOTAKI D. LUTRICK 1D-134 500292289200 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 29-SEP-98 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING MWD RUN 2 AK-MM'80290 S. GONIOTAKI D. LUTRICK 23 liN 10E 511 601 .00 112.00 70.50 OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) 9.875 DRILLERS DEPTH (FT) 6224.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E MAIL MESSAGE FROM MIKE WERNER OF ARCO ALASKA, INC. ON 08/26/98. 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6224'MD, 4241 'TVD. SLIDE = MUD MOTOR DRILLING (NO ROTATION). SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY ~(EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/29 Maximum Physical Record.. 65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP $ START DEPTH STOP DEPTH 100.0 6178.0 100.0 6178.0 100.0 6178.0 100.0 6178.0 100.0 6178.0 100.0 6185.5 100.0 6224.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 121.0 3978.0 2 3978.0 6224.0 REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 FET MWD HOUR 4 1 68 Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max DEPT 100 6224 GR 13.9369 136.188 RPX 0.7957 2000 RPS 0.7683 2000 RPM 0.3312 2000 RPD 0.6905 2000 ROP 7.8531 809.18 FET 0.0829 16.8057 Mean Nsam 3162 12249 69.6715 12172 72.2715 12157 65.9382 12157 76.5123 12157 99.5105 12157 277.726 12249 0.45569 12157 First Reading 100 100 100 100 100 100 100 100 Last Reading 6224 6185.5 6178 6178 6178 6178 6224 6178 First Reading For Entire File .......... 100 Last Reading For Entire File ........... 6224 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 100.0 3937.5 RPD 100.0 3937.5 RPM 100.0 3937.5 RPS 100.0 3937.5 RPX 100.0 3937.5 GR 100.0 3945.0 ROP 100.0 3978.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 16-JUL-98 ISC 5.06 CIM 5.46 MEMORY 3978.0 121.0 3978.0 .3 67.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P1033CRG6 P1033CRG6 BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.880 9.9 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: SPUD MUD 9.00 245.0 9.0 500 8.6 5.900 5.200 6.000 6.000 30.6 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size DEPT FT 4 1 68 GR MWD 1 API 4 1 68 RPX MWD 1 OKMM 4 1 68 RPS MWD 1 OHMM 4 1 68 RPM MWD 1 OHMM 4 1 68 RPD MWD 1 OHMM 4 1 68 ROP MWD 1 FT/H 4 1 68 FET MWD 1 HOUR 4 1 68 Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 100 3978.5 2039.25 7758 GR 13.9369 134.683 66.3147 7691 RPX 2.6244 2000 108.943 7676 RPS 3.1266 2000 98.7498 7676 RPM 0.3312 2000 115.784 7676 RPD 1.1~49 2000 152.129 7676 ROP 12.4492 3879.93 321.158 7758 FET .0~0829 246439 0.~286679 ~76 First Reading For Entire File .......... 100 Last Reading For Entire-File ........... 39.7.8.5 First Reading 100 100 100 100 100 100 100 Last Reading 3978.5 3945 3937.5 3937.5 3937.5 3937.5 3978.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003~.. Service Sub Level Name... Version Number ........... 1..0.0 Date of Generation ....... 9~/09/29 Maximum Physical Record..65~35 File Type.~ .............. LO Previous F$1e Name ....... STSLI~,002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 3938.0 6178.0 RPD 3938.0 6178.0 RPM 3938.0 .6178.0 RPS 3938.0 6178.0 RPX 3938.0 6178.0 GR 3945.5 6185.5 ROP 3979.0 .6224.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER {FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 18-JUL-98 ISC 5.06 CIM 5.46 MEMORY 6224.0 3978.0 6224.0 12.3 64.0 TOOL NUMBER P1033CRG6 P1033CRG6 .9.880 9.9 SPUD MUD 9.50 210.0 7.5 450 6.2 5.100 3.382 4.900 7.000 44.5 # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point ............... Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units .......................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 2 3LPI 4 1 RPX MWD 2 OHMM 4 1 RPS MWD 2 OHMM 4 1 RPM MWD 2 OHMM 4 1 RPD MWD 2 OHMM 4 1 ROP MWD 2 FT/H 4 1 FET MWD 2 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 ' 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 3938 6224 5081 GR 23.0066 136.188 75.4328 RPX 0.7957 123.42 9.45256 RPS 0.7683 96.7514 9.73164 RPM 0.7298 92.465 9.23927 RPD 0.6905 77.95 9.37384 ROP 7.8531 607.206 207.201 FET 0.1781 16.8057 0.745208 First Last Nsam Reading Reading 4573 3938 6224 4481 3945.5 6185.5 4481- 3938 6178 4481 3938 .6178 4481 3938 6178 4481 3938 6178 4491 3979 6224 4481 3938 .6178 First Reading For Entire File .......... 3938 Last Reading For Entire File ........... 6224 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/09/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Scientific Technical Services Date ..................... 98/09/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 7, 1998 ~31 ,~ .- 1D- 134, AK-MM-80290 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker? Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1D-134: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22892-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22892-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Dresser Industries_ Inc._ Comoanv