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Home My WebLink About200-132CRit CDt —3z) P-1-6 76dI3zc Regg, James B (CED) From: Regg, James B (CED) Sent: Friday, May 29, 2020 5:30 PM To: 'ALP DS Lead and Simops Coord'; Cook, Guy D (CED) Cc: ALP Ops Maint Supt; Long, Jason W Subject: RE: Explanation and Current SVS Test on CD1-30 Thank you for providing the test result for CRU CD1-30 (PTD 2001320) and the explanation of what led to the well not being tested as required by regulation, and what will be done to prevent recurrence. AOGCC production records indicate this well had been mostly shut in since March 2007 except for a few days in 2010, 2017 and 2019. A review of SVS test records indicate CPAI did test CD1-30 in 2017 and 2019; there is no record in AOGCC files of it being tested in 2010. I agree that the proposed automated pop-up window in CPAI's IP -21 system as described below should help mitigate this from occurring in the future. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.ree¢@alaska.eov. From: ALP DS Lead and Simops Coord <alp1450@conocophillips.com> Sent: Wednesday, May 27, 20201:26 PM To: Regg, James B (CED) <jim.regg@alaska.gov>; Cook, Guy D (CED) <guy.cook@alaska. ov> Cc: ALP Ops Maint Supt <alp1167@conocophillips.com>; Long, Jason W <Jason.W.Lo @conocophillips.com>; ALP DS Lead and Simops Coord <alp1450@conocophillips.com> Subject: Explanation and Current SVS Test on CD1-30 Dear Mr. Regg, My name is Robert Quigley, I am the Drillsite Lead Operatpf for the Alpine Field and GMT Field. Here at Alpine, the CD1 Operator brought on CDI-30 Producer 5/21/2020 at 0 9. We failed to give 48 Hours notification to the AOGCC and test this well before 5/26/2020 at 0359. CD1 Pad was tete 5/09/2020, CD1-30 was not, it was shut in at the time and not tested. We have an automated page in IP -21 (Our CS System) that we update after testing a pad. It is called SVS SAFETY VALVE REPORT. We enter all wells that wer not tested during the Pad test. Unfortunately CD1-30 was not entered on this page. Had it been entered IP -21 wo have sent the DS Lead Operator (me) an email stating this well had been brought on and a SVS Test is due. It wou send the same email every morning until it was removed from the SAFETY VALVE REPORT. This page also generate a notification to our WeIITRAK COPA page that our Production Engineers, Problem Wells, Wells Group Supe Isors, O&M Superintendents and the DS Lead Operator receives. So the failure was not entering th data on IP -21. Our solution, after discussions with Board Operators, Drillsite Operators, Automation Techs, O&M Su rintendent and myself the Drill Site lead is the following. Automation is Cbt-30 � 22&�t32o Regg, James B (CED) From: ALP DS Lead and Simops Coord <alp1450@conocophillips.com> Sent: Wednesday, May 27, 2020 1:26 PM eg�q To: Regg, James B (CED); Cook, Guy D (CED) / Cc: ALP Ops Maint Supt; Long, Jason W; ALP DS Lead and Simops Coord Subject: Explanation and Current SVS Test on CD1-30 Attachments: SVS CRU CD1 5-27-2020 MISC.xlsx Dear Mr. Regg, My name is Robert Quigley, I am the Drillsite Lead Operator for the Alpine Field and GMT Field. Here at Alpine, the CD1 Operator brought on CDi-30 Producer 5/21/2020 at 0359. We failed to give 48 Hours notification to the AOGCC and test this well before 5/26/2020 at 0359. CD1 Pad was tested 5/09/2020, CD1-30 was not, it was shut in at the time and not tested. We have an automated page in IP -21 (Our DCS System) that we update after testing a pad. It is called SVS SAFETY VALVE REPORT. We enter all wells that were not tested during the Pad test. Unfortunately CD1-30 was not entered on this page. Had it been entered IP -21 would have sent the DS Lead Operator (me) an email stating this well had been brought on and a SVS Test is due. It would send the same email every morning until it was removed from the SAFETY VALVE REPORT. This page also generates a notification to our WelITRAK COPA page that our Production Engineers, Problem Wells, Wells Group Supervisors, O&M Superintendents and the DS Lead Operator receives. So the failure was not entering the data on IP -21. Our solution, after discussions with Board Operators, Drillsite Operators, Automation Techs, O&M Superintendent and myself the Drill Site lead is the following. Automation is creating a Pop-up window on IP -21, when bringing on any well that has not been online in the last 30 -days stating, This well has been shut in greater than 30 -days. Is the SVS Test Current? PLEASE verify with the DS Lead Operator. Our apologies in not catching this. I have confidence this extra step will help mitigate this from happening in the future and we hope to continue in having the AOGCC's confidence in our ability to try to correct short comings when exposed in our procedures and good operating practices. On behalf of Alpine and GMT Fields Sincerely Robert Quigley/Shane Hume ALP DS Lead / SIMOPS 907-670-4017 Office 907-943-1169 Cell Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: COPA Submitted By: Robert Quigley Date: 5/27/2020 Operator Rep: Chris McCaughy Field/Unit/Pad: Alpine / CRU / MI MISC AOGCC Rep: Separator psi: LPS 156 HPS I Well Data Pilots ISSVISSSVI Retest/SI Dade Well Type Well Pressures Gas Lift Waiver Well, Separ Set UP Test Test Test Date of Retest Oil, WAG, G1NJ, Inner Outer Tubing Yes/No Yes/No Number Number PSI PSI Tri Code Code Code Or Date Shut In GAS, GSTOR, 51 PSI PSI PSI CDI-30 1 2001320 1561 1001 103 P P P OIL 16001 9061 180 ' e 1 ✓ Wells: I Components: 3 Failures: 0 Failure Rate: ❑ 90 Day Remarks: Tested on request of AOGCC's Jim Regg and Guy Cook. PLB 01/26/11 Page 1 of I SVS CRU CDl 5-27-2020 MISC • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECENED '\F l 4 /WI' April 01, 2011 APR 0 B ska ui1 gas coonso C Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 13 9-- Anchora e, AK 99501 a00 O Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped March 13 -15 and March 27 -28, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor r • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 04/01/2011 CD1 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD1 -15PB1 50103206190000 2100470 10" n/a _ 10" n/a 4.3 3/13/2011 CD1 -20 50103205030000 2042400 6" n/a 24" n/a 5.4 3/13/2011 CD1 -21 50103203620000 2010060 6" n/a 13" n/a 8 3/13/2011 CD1 50103203480000 2001320 6" n/a 20" n/a 6.4 3113/2011 CD1 -31 50103203470000 2001180 6" n/a 14" n/a 6.4 3/13/2011 CD1 -37 50103203020000 1990670 8" _ n/a 13" n/a 8.3 3/13/2011 CD1 -38 50103203230000 2000030 4" n/a 13" n/a 4.9 3/13/2011 CD1 -39 50103203040000 1990800 4" n/a 15" n/a 4.4 3/13/2011 CD1-40 50103202980000 1990440 4" n/a 15" n/a 5.2 3/13/2011 , . . ~ ConocoPhillips Alaska "7 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 B~ March 31,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 5CJ\NNED APR 1 () 2007 àÐO-~'O'J- Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment / . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 ?/16/200? Alpine Field March 31,2007 F:\LaserFiehe\CvrPgs _I nserts\M ierofi 1m _Marker.doe MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ,,~J.iô"'1 ":"~~'........ '\:,v ') ) c.fJf-30 ( Annular Iniection Permit Required Documents: r;I' 9-5/8" Casing Detail IW" 9-5/8" Cementing Details tit"" Daily Drilling Report from Surface casing cement job v 9-5/8" Initial Casing Shoe Test (j' 7" Casing Detail œ' 7" Cementing Details ~ Daily Drilling Report from Intermediate casing cement job ~Formation Adequacy for Annular Injection Test \~CAfMNED JÅN 1 ~ 2004 (( <9°0"-/¿d- ( (" ]1PHILLIPS Alaska, Inc. Casing Detail 9 5/8" Surface Casin Well: Date: CD1-30 9/18/00 A Subsidiary or PHILLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.45 FMC Gen V Hanger 2.57 36.45 Jts 3 to 72 70 Jts 9-5/8. 36# J-S5 BTC Csg 2622.10 39.02 Davis Lynch Float Collar 1.48 2661.12 Jts 1 to 2 2Jts 9-5/8. 36# J-55 BTC Csg 71.75 2662.60 Davis Lynch Float Shoe 1.75 2734.35 2736.10 TO 12 1/4. Surtace Hole 2746.00 RUN TOTAL 41 BOWSPRING CENTRALIZERS - 1 per It on Jt #1 - #13 (On stop rings of Jt #1 & #2) and over collars on Its# 15,17,19,21,23,25,27,29,31 ) 33,35,37,39,41,43,45,47,49,51,53,55,57,59,61,63,65, 67,69. Use Best-o-Life 2000 pipe dope Remarks: Up Wt -150k Dn Wt - 137k Block Wt - 70k Supervisor: Donald Lutrick { ( 8PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM CCMPANY CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DATE: CD1-30 9 5/8" , 36# L-SO BTC 09/18/00 PAGE: RIG: 1 of 2 Doyon 19 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 36.77 26 39.11 51 37.07 76 39.67 101 126 151 176 2 34.98 27 38.49 52 37.23 77 37.40 102 127 152 177 3 42.84 28 37.50 53 37.14 78 38.09 103 128 153 178 4 36.15 29 38.02 54 40.89 79 104 129 154 179 5 37.16 30 38.22 55 37.22 80 105 130 155 180 6 37.30 31 33.77 56 37.08 81 106 131 156 181 7 35.91 32 35.61 57 39.20 82 107 132 157 182 8 36.17 33 35.63 58 37.72 83 108 133 158 183 9 34.67 34 35.73 59 38.33 84 109 134 159 184 10 37.03 35 37.06 60 37.21 85 110 135 160 185 11 37.08 36 37.01 61 36.24 86 111 136 161 186 12 37.18 37 37.25 62 37.00 87 112 137 162 187 13 37.93 38 35.92 63 37.04 88 113 138 163 188 14 34.58 39 37.27 64 37.26 89 114 139 164 189 15 39.19 40 36.11 65 40.77 90 115 140 165 190 16 39.03 41 39.15 66 35.70 91 116 141 166 191 17 37.71 42 36.28 67 39.06 92 117 142 167 192 18 39.19 43 38.84 68 37.05 93 118 143 168 193 19 39.20 44 35.58 69 39.06 94 119 144 169 194 20 37.01 45 37.23 70 39.56 95 120 145 170 195 21 37.09 46 36.63 71 36.55 96 121 146 171 196 22 37.14 47 35.99 72 37.05 97 122 147 172 197 23 38.70 48 36.84 73 37.15 98 123 148 173 198 24 39.64 49 39.01 74 37.25 99 124 149 174 199 25 38.61 50 35.91 75 37.03 100 125 150 175 200 Tot 938.26 Tot 924.16 Tot 942.86 Tot 115.16 Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 2920.44 DIRECTIONS: TOTAL JOINTS THIS PAGE = 78 FLOAT SHOE FLOAT COLLAR HANGER RKB If ( Phillips Alaska Drilling Cementing Details ~ Well Name: CD1-30 Report Dale: 09/1812000 Report Number: 5 Ria Name: Doyon 19 AFC No.: 998C13 Field: Alpine Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 9 518" 12.25 44° at TO 2736 2661 Centralizers State type used, intervals covered and spacing Comments: Total: 41 Bowsprlngs. Ran 1 per Jt on 1st 13 Jts and every other jt to surface. Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.6 23 25 51 15 Gels before: Gels after: Total Volume Circulated: 32/61 5/10 700 bbls Wash 0 Type: Volume: Weight: Comments: 40 8.5 ,BI~zan wIG sx nut plug ~)àC8r 0 Type: Volume: Weight: 'Comments: ARCO 845 SO 10.5 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: AS III LIte 70 405 10.7 4.42 Additives: 30% 0053, 0.6% D046, 1.5'1. DO79, 1.5% 5001, 50% D124, 9% BWOW DO44. Tall Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: G 70 231 15.8 1.15 Additives: 0.2% 0046, 0.3% D065, 1% SO01 p'~placement . 0 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: .Qc)mmehts: 9.5 9.5 150k Reciprocation length: Reciprocation speed: Str. WI. Down: 15 10 fpm 137k Theoretical Displacement: Actual Displacement: Str. WI. In mud: 205 206 Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:9/18/00 yes yes Time:01 :21 Remarks:Had full returns throughout job. Approx 80 bbls 10.7 cement to surface. Cement Company: Rig Contractor: Approved By: Dowell DOYON Donald Lutrick ,~' , ( Phillips Alaska Drilling AFC No. Date Rpt No 998C13 O9N7nOOO 4 Daily Drilling Report Rig Accept - hrs Days Since AcceptlEst: 2 1 2.5 09/161200012:00:00 AM Rig Relase - hrs: Well: CD1-30 Contraclor: DOYON Rio Name: Doyon 19 Depth (MDfTVD) Daily Cost $ 247580 last CSQ: 16" 0 114' 2746/2394 Prey Depth MD: 2025 Cum Cost $ 512212 Next Csg: 9 5/8. 0 2780' Progress: 721 Est Cost To Date $ 450000 Shoe Test: N/A Operation At 0600: NU BOPE Upcoming Operations: Test BOP. RIH. Test csg and FIT. MUD DATA MUD TYPE SPUD DRILLING DATA DEPTH BIT NO. 2746 1 BIT DATA BIT NO. EH8IS ACCIDENT (non-spill) N DRILLSIBOP DATA LAST BOPIDIVERT LAST BOPIDRILL TST 09/05/2000 0911612000 LAST H2S DRILL 08109/2000 LAST CONFINED SPACE 06121/2000 WEIGHT 9.6DDO VISCOSITY 54sqc ROTWT 144k PUWT 150k SIZE 12.25 MAKE HTC SIZE EMPLOYER LAST FIRE DRILL 09/0312000 LAST SPILL DRILL 09/17nooO MAKE SPILL N PVNP 25/15 GELS 5/13/16 APIWL 22.0 HTHP WL mV30 mln SOLIDS 8.0% HOLE VOLUME 185bbl MBT 27.5 ph 7.5 LGS 5.0% SOWT 140k AVG DRAG TYPE MXC1 SERIAL NO J72ZL DEPTH OUT 2746 DEPTH IN 114 FOOTAGE 2632 ADTIAST 15.24/6.9 WOB2 20.25 RPM 1 193 - 263 TFA .547 TYPE TYPE FUEL 81 WATER SERIAL NO VOLUME (gallons) FUEL USED 2642 MAX DRAG DEPTH OUT LAST SAFETY MTG 09/12/2000 DRILL WATER USED. BBLS POTABLE WATER USED. BBLS 290 TRQ BTM 8500 TRQ OFF 6500 PUMP PRES 2050 II I PUMP NO 1121 I LINER SZ 5.5161 I SPM 1 751751 I DEPTH IN 90 INJECTION INJECTION WELL CD1-Ð3 SOURCE WELL CD1-30 RATE (bpm) 2.5 PRESSURE (psi) 1248 INJECTION FLUIDS FOOTAGE WEATHER It PERSONNEL DATA ADT/AST 1 WOB2 TEMP of 28 WIND SPEED 13 . RPM 1 WIND DIRECTION 90° - ') TFA CHILL FACTOR of 8.85 . Water Base Muds 910 Diesel 50 PIT VOL 307 GPM2 26812971 I JETS JETS 1011211211811 IIIII PHILLIPS PERSONNEL 1 0 DAILY MUD $7270 SPS 1 III BIT COST 11910 BIT COST CONTRACTOR PERSONNEL 26 0 0 TOTAL VOL (bbl) 960 TOT FOR WELL (bbl) 27420 TOTAL MUD $23486 COMPANY MI SPP 1 III MUDWT 9.6111 DULL 41611 A GRADE EI11RGITD MISC PERSONNEL DULL III GRADE III 5 SERVICE PERSONNEL 15 TOTAL ,'I::;, ,".:"<:,:"!;;ì(:iF!~:iå'~1'J(;jf:ií'$}¡;;ßm&1::tiøaø;~jÞ'd,QøE~r::,,/'::;::<:[11 Drlg f/2025' to 2746'. ADT - 6.54 hrs. Circ and condition mud. POH to 1550'. TIght f/1912' to 1600'. RIH. No problems. Circ and condition mud. POH. Stand back BHA. RU to run 9 5/8. csg. 47 ~ 12:00 AM 08:30 AM 08:30 AM 09:30 AM 09:30 AM 11:00 AM 11 :00 AM 12:30 PM 12:30 PM 02:00 PM 02:00 PM 03:00 PM 03:00 PM 04:00 PM ,:.',;j4ØØâ~'i 8.50 1.00 1.50 1.50 1.50 1.00 1.00 " , :L::'OB$QODEt CRIL CIRC WIPERTRP CIRC TRIP _OUT BHA CASG . ':" .iJtQLg::S~ÇT::,'~I:'Ri;/Ä$~ÞR$ SURF Making Hole SURF Making Hole SURF Making Hole SURF Making Hole SURF Making Hole SURF Making Hole SURF Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing 04:00 PM 10:00 PM SURF PJSM. RIH w/9 5/8" csg to 2736'. Blow down top drive. CASG 6.00 10:00 PM 11:30 PM SURF Circ and condition mud for cement lob. PJSM. 1.50 CIRC 11:30 PM 12:00 AM CEMENT SURF Test lines to 2500 psi. Pump 40 bbls biozan pili w/6 sx nut plug for markerand 50 bbls 10.5 spacer.. 0.50 24.00 Supervisor: DONALD LUTRICK Daily Drilling Report: CD1-30 09/17/2000 Page 1 ) (' (' Phillips Alaska Drilling Daily Drilling Report AFC No. Date RptNo Rig Accept - hrs Days Since AccepVEsl: 3 I 3 Rig Relase . hrs: 998C13 09/1812000 5 09/16/2000 12:00:00 AM Well: CD1-30 Depth (MDfTVD) 3100/2644 Prev Depth MD: 2746 Progress: 354 Contractor: DOYON Daily Cost $182015 Cum Cost $ 694227 Est Cost To Date $ 675000 Rig Name: Doyon 19 Last CSg: 9 5/8" @ 2736' Next Csg: 7" ß 9567' Shoe Test: 16.0 Operation At 0600: Wiper trip at 3766'. Upcoming Operations: Drlg ~;...' ',MUD DATA ,;: -:.ORlLUNG DATA BIT DATA EH&S DRiLLS/BOP.DATA ' MUD TYPE DEPTH BIT NO BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOPiDRILL LSND 3100 2rr 'K.ý TST 09/0512000 09/1812000 WEIGHT ROTWT SIZE SIZE EM.A~YER LAST H2S DRILL LAST FIRE DRILL 9.6ppg 145k 8.5 " þ't.\ \L. 0810912000 0911912000 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 42sqc 160k HYC N SPACE 09/1712000 08/21/2000 PVNP SOWT TYPE TYPE TYPE :':~\;,i¿;:'<::',~,.":,::;:,;~~,~l &W~r~~;',L:?:':;,::::,:;,':D.;~;. 10/20 130k DS70FNPV GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 2648 8/15/16 22654 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRilL WATER USED - 1385 9.2 09/1212000 BBlS HTHP WL TRQ BTM DEPTH IN DEPTH IN ,,' POTABLE WATER 85 '.,' '". ._, ,','" " '," :',:,.,',' ml130 min 10500 2746 " INJEC'TION ' ' ;, USED. BBlS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL c,"::' :<,i,:,;, ,,'>..¡.~~¡g~~~EUÓ~¥À:;>')"'.,:'F ::\',:U:, 8.0% 1000 354 CD1-Ð3 HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 28 208bbl 156011 I 1.8/ .1 I CD1-30 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 13 17.5 11211 5 -10 . 3.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 200. 9.8 5.51611 193 - 263 - 1092 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 8.85 5.7% 731721 I .557 Water Base Muds 1540 PIT VOL GPM2 JETS JETS Fresh Water PHILLIPS 1 380 2611305 I I 11111 111 111111 III II 20 PERSONNEL 111 Diesel 40 DAILY MUD SPS 1 BIT COST BIT COST Other CONTRACTOR 25 $11038 30140130140 0 395 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $34524 180 1230 1210 I II I III 1995 250 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 14 MI 9.6111 I I I III 29415 PERSONNEL TOTAL 45 'ß.~\QeSQRIP.IIØN'\%j,ho{,~*~~::,: Bit, 6.75" Mach 1XL -1.20°, XO, CDR, MWD, ADN, NMS, 3 - CSNMDP, XO, 3 - HWDP, JArs, 25 - HWDP ~{1.:';;:~:\'i,: (,~~,};i;~;;' "~1~~;;;;ç'; Ú;C",i'>Xf;,!:'ÞN~Mf¡¡"~k'::J ^j,i¡ 'PR'LL~I.p,~:p'~] ~~~~~:.kl:):~'N'~&i,~f,(~J:'f;:,T. ¡' r :~:/¥f~~;!}i¡:::"<~;¡K:~¡~;'\linf.~ BHA NO 2 ,OD 'OlD, WEIGHT ",GRAPE': CON/IIEC;rIWf ",CLASS 2 , ,'LENGTtf " " .. BHA LENGTH 1106.56 5" 4.281 19.5 G.105 4-1/2 IF prem DATE LAST INSPECTED: HOURS ON JARS: 151 '\.~i'~1f1ME::" jï\\~'ENÐ};:¡:..:;".'<HOl,lRS <, "',,' ",: Of;lS,'CODE '; I,' . HOLES~GT':',::,IP,J;As.E,OPS, ': 'l:,:::,:','~',: -:r;,PP-E;BAT;lO.{\, l;ì,fJ~QM,ÇJI;JQP,::C~QOO:;;',,;,i;~;,,; \P:". 12:00 AM 01:30 AM 1.50 CEMENT SURF Casing and Pump 319 bbls 10.7 cement and 47 bbls 15.8 cement. Drop Cementing top plug. Pump 20 bbls H2O and rig displaced with mud. Bumped plugs. Floats OK. 01:30 AM 02:30 AM 1.00 CEMENT SURF Casing and RD cement head. LD LJ. Flush out dlverter. Cementing 02:30 AM 04:00 AM 1.50 NU_ND Pi Making Hole Clear floor. ND dlverter. 04:00 AM 04:30 AM 0.50 NU_ND Pi Making Hole NU well head. Test MMS to 1000 psi. OK. 04:30 AM 05:30 AM 1.00 NU_ND Pi Making Hole NU BOPE. 05:30 AM 10:30 AM 5.00 BOPE Pi Making Hole RU to test BOPE. Test all BOPE to 250 - 3500 psi wI annular to 2500 psi. Witness of test waived by AOGCC rep Jeff Jones, 10:30 AM 11:00AM 0,50 OTHER Pi Making Hole Install wear bushing. 11:00 AM 01 :00 PM 2.00 PREP Pi Making Hole RU DP equipment, PU and std back 30 Jts 5" DP. 01 :00 PM 02:30 PM 1.50 BHA Pi Making Hole MU and orient BHA. Suñace test MWD. 02:30 PM 04:00 PM 1.50 TRIP_IN Pi Making Hole PU DP fl shed and RIH to TOC at 2650', 04:00 PM 05:00 PM 1.00 GIRt P1 Making Hole Clrc and condition mud. 05:00 PM 06:00 PM 1.00 TEST_CSG P1 Making Hole Test csg to 2500 psi fl 30 min. OK. 06:00 PM 07:00 PM 1.00 CLN_OUT Pi Making Hole Drill out cement float equipment and 20' new formation to 2766'. 07:00 PM 08:00 PM 1.00 GIRt Pi Making Hole Circ and condition mud to balance mud wt. 08:00 PM 08:30 PM 0.50 TEST_CSG Pi Making Hole Peñorm 16.0 ppg EMW FIT. Daily Drilling Report: CD1-30 09/18/2000 Page 1 ~" \ 08:30 PM 09:00 PM 0.50 CIRC 09:00 PM 12:00 AM 3.00 DRIL 12:00 AM 24.00 P1 P1 Making Hole Making Hole t Displace to 9.6 LSND mud. Drtg f12766' to 3100'. ADT -1.8 hrs. Note: Accident. Anadrtll ) Daily Drilling Report: CD1~30 09/18/2000 Supervisor: DONALD LUTRICK Page 2 CASING TL~ T and FORMATION INTEGRITY TEST Well Name: CD1-30 9/18/00 Supervisor: Donald Lutrick Date: 0 Initial Casing Shoe Test Reason(s) for test: 0 Formation Adequancy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/811 36# J-55 BTC CSG Hole Depth: 2,7661 TMD 2,4081 TVD 2,7361 TMD 2,3871 TVD Casing Setting Depth: EMW= Mud Weight: 9.6 ppg 301 2418 - 790 psi - 0.052 x 2,387 + 9?9 EMW = 15.96 ppg J Length of Open Hole: Press 0.052 xTVD + Mud Weight Pump output = .101 BPS 2.800 psi 2.700 psi 2,600 psi 2.500 psi 2.400 psi 2.300 psi 2,200 psi 2,100 psi 2.000 psi L 900 psi 1,800 psi 1.700 psi w 1.600 psi ~ 1,500 psi en 1,400 psi ~ 1.300 psi 8: 1,200 psi 1,1 00 psi 1,000 psi 900 psi 800 psi loopsi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi Osll< Fluid Pumped = 1.1 bbls BLED~BACK = 1.0 bbls 717""/: ..1:\::': -,..:- . '.~" -- -U'1~ ,.,~:.,;,I,",..:""";: . +- I """",:---+-I-~_-+.- . ~ &- -.----, '------1. - ',*,,~, 'if--Jt=$o_,¡..~....iooo"¡"'~~ ~LEAK-OFF E::;- ~CASING TES; --LOT SHUT IN :;'v~~ .....-CASING TESi ::..;r ::-. ~I'V'= -+- TIME LINE 2st1< AslI< 6st'.c 8st1< 10stl< 12st1< 14st1< 16st1< 18511< 20511< 22511< 24511< 26511< 28511< 30511< 32511< 34511< 36511< 38511< 40511< STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE "'--------'----, .. ~-----r tOO oor ---- -~-----~--r " , , " '--t 1 , , 1 , 1---- - -+ I-- I f ~ I 0 atka I 90 psi I I I 0 atka I 80 psi I I-u I I I I I I I I I 2 stks I 230 psi I I I 2 stks I 190 psi t~~ 00 . .=J 4 ~tks I 400 p-~ I :- : t 4 atka I ~~ 460 psi t ~--__~_~tks i 520 psi i ¡ i 6 atka i 770 psi i 1------- i 8 atka i 600 psi ~ Iw~. I 8 atka I 970 psi I i-----------~ 10 atka rk?~9 psl__~ J i _10 stks I 1,120 psi ~C i-------~--I 11 atka t ...?~~-ps!._~ i i r 12 stk! I 1 ,270 psi . I-----------~-----.u . --~ I i 14 stks i 1,440 ~~--I i---___~~_r -I... -. -i I------w ..- ~_16stkS~ !---~------~---i-----1 1-- J. 18 atka 1,820 psi! I------~ mmm~__---l mnm ---i ~-- I 20 atka ° 2,030 psi , , I , i 22 atka 2,240 psi ¡- t---¡ 1 " I 24 atka I 2,470 psi .. - t----t-------... I rr ----t - !--~ ~---f -~ i .m -~-~- stks t 2,530 psi 'I ' , , , J-u --. I ... "'1 .- +-.! . , I ' , ~------t--------~t---------i J-----f-- , --m ----4 " 1 I , 1 I , I ' , , , 1_-- I ~-----~-t--------t-~-------I'- ----r-----------.-------------t , I --+ I I , , I r---------t---- --------... r~----~----t------ . t oo. -1 " 1"--1 I--~ r -~----""-----+-------~------I 1--------+---------- I , I , I SHUTINTIME ' , , I- u- .- I u_~~ I I--~-- I . 1 , 1 1 "00" '2530' r -. -to. ---- I - 00 t 1- 5:0 ~:~ -+-_~__j.r 2:520;J ~-----_.--t- I u_------I J- f- ..~-- ¡Ii i I 10.0 min 2,510 psi 1 I SHUTINTIME J . SHUTINPRESSUR~ 1 15.0min 2490osi ~O.O m~ ¡ 790 ~Si I I 20.0 min I 2 480 ~i I-- 17)min---_~::::._~~_¡~~~)2~ si ~J I~ 25.0 min ',~' 1 ~ '2:480 si ~.~2:0 -f!1.!.t]--i---t. 700 psi -~ I 30.0 min oot---- .! 2.475 psi I 3.0 mil]~_~__- -t 690 psi --~ I- r I ~ 4.0 min I I 690 ~si ~ L . ::' !:~ ê :: I lJ~-:ltj. . u -t :~~ ~:: -1 L- .:~:-: un ~.::: I i !.o ,,!In -I 00 -I 690 ~~ i- I I 1 ~;¡~J==f:::: J I: :-:::: "___m_" ::::.1 '::n _:- NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ( Casing Detail .PHILLIPS Alaska, Inc. 7" Intermediate CaBin A Subsidiary of PHILLIPS PETROLEUM COMPANY It Well: Date: CD1-30 9/26/00 J i DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.42 FMC 1111 X 711 Hanger 2.03 34.42 Jts 3 to 233 231 Jts 7" 26# L-80 BTCM Csg 9399.40 36.45 7" Davis Lynch Float Collar 1.40 9435.85 Jts 1 to 2 2 Jts 7" 26# L -80 BTCM Csg 81.04 9437.25 T' Davis Lynch Float Shoe 1.70 9518.29 9519.99 1 S8 centralizer per jt #1 - #18 1 S8 centralizer per jt #167..168-169 . 1 S8 centralizer every other jt #171 - #231 . ) Total - 52 centralizers - Leave Out it #234 - #238 Use Best-a-Life 2000 pipe dope Remarks: Up Wt - 310k Dn Wt ~ 165k Supervisor: Donald Lutrick . ( ~t PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETJ:10LEUM COMPANY ~. CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DATE: CD1-30 7.,26# L-80 BTCM 09/26/00 PAGE: RIG: 1 of 2 Doyon 19 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 40.69 26 37.29 51 40.69 76 38.91 101 40.86 126 41.47 151 41.47 176 41.70 2 40.35 27 41.31 52 41.59 77 41.71 102 41.32 127 40.14 152 41.53 177 40.36 3 40.75 28 40.43 53 37.66 78 41.66 103 40.71 128 41.25 153 41.51 178 40.56 4 40.43 29 41.23 54 40.03 79 41.69 104 40.52 129 39.53 154 41.50 179 40.32 5 38.90 30 41.60 55 41.53 80 41.31 105 37.86 130 41.50 155 41.91 180 40.73 6 41.70 31 40.91 56 41.68 81 38.54 106 40.73 131 41.69 156 41.53 181 41.35 7 41.40 32 40.69 57 41.77 82 38.94 107 41.34 132 41.54 157 41.22 182 41.66 8 41.24 33 41.20 58 41.34 83 41.34 108 40.74 133 41.47 158 41.65 183 41.41 9 41.13 34 41.32 59 41.70 84 39.46 109 40.09 134 41.09 159 41.33 184 38.63 10 41.78 35 41.36 60 40.17 85 39.64 110 41.29 135 41.55 160 39.03 185 41.43 11 40.70 36 41.37 61 40.71 86 41.56 111 38.75 136 41.35 161 41.78 186 41.51 12 41.95 37 40.18 62 40.79 87 36.67 112 41.71 137 41.75 162 41.68 187 41.55 ) 13 41.44 38 40.51 63 40.74 88 39.23 113 41.39 138 41.24 163 40.16 188 41.67 , 14 40.71 39 37.51 64 40.52 89 39.38 114 38.17 139 38.06 164 41.30 189 41.79 15 40.73 40 40.24 65 41.71 90 38.79 115 40.18 140 41.14 165 41.69 190 41.67 16 40.73 41 40.34 66 41.05 91 40.91 116 41.19 141 41.58 166 41.53 191 41.45 17 40.78 42 41.60 67 41.40 92 41.51 117 40.69 142 40.68 167 41.80 192 40.74 18 41.69 43 40.12 68 40.73 93 41.50 118 41.65 143 41.79 168 41.49 193 40.61 19 40.71 44 38.91 69 40.75 94 40.73 119 40.45 144 39.67 169 41.91 194 42.41 20 41.35 45 41.71 70 41.66 95 41.71 120 39.87 145 41.29 170 41.30 195 40.73 21 41.38 46 40.70 71 41.30 96 41.68 121 41.34 146 41.66 171 40.11 196 38.51 22 37.64 47 41.67 72 41.65 97 41.65 122 38.58 147 37.55 172 40.47 197 40.81 23 39.48 48 39.41 73 38.56 98 41.71 123 38.00 148 40.73 173 40.19 198 40.68 24 41.31 49 41.31 74 40.88 99 41.70 124 38.90 149 41.46 174 41.57 199 38.90 25 38.57 50 41.68 75 40.83 100 41.53 125 40.24 150 40.98 175 40.72 200 40.72 Tot 1017.54 Tot 1014.60 Tot 1021.44 Tot 1013.46 Tot 1006.57 Tot 1022.16 Tot 1030.38 Tot 1021 .90 TOTAL LENGTH THIS PAGE = 8148.05 DIRECTIONS: TOTAL JOINTS THIS PAGE = 200 f ~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COtv1PANY ( CASING TALLY ", ) WELL NUMBER: TUBING DESCRIPTION: DATE: CD1-30 7-, 26# L-80 BTCM 09/26/00 PAGE: RIG: 2 of 2 Doyon 19 Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 40.72 226 40.69 251 276 301 326 351 376 202 41.19 227 39.79 252 277 302 327 352 377 203 40.70 228 38.65 253 278 303 328 353 378 204 39.66 229 38.96 254 279 304 329 354 379 205 40.48 230 40.49 255 280 305 330 355 380 206 40.53 231 40.91 256 281 306 331 356 381 207 40.81 232 40.67 257 282 307 332 357 382 208 40.42 233 40.46 258 283 308 333 358 383 209 39.56 ~ ~ 259 284 309 334 359 384 210 40.76 æ& ~ 260 285 310 335 360 385 211 40.48 æ& 4&:55 261 286 311 336 361 386 212 40.17 ~ a9:-56 262 287 312 337 362 387 '~13 40.12 æ& ~ 263 288 313 338 363 388 .' 214 40.53 239 264 289 314 339 364 389 215 41.09 240 265 290 315 340 365 390 216 38.00 241 266 291 316 341 366 391 217 40.74 242 267 292 317 342 367 392 218 41.46 243 268 293 318 343 368 393 219 40.74 244 269 294 319 344 369 394 220 40.65 245 270 295 320 345 370 395 221 40.72 246 271 296 321 346 371 396 222 40.73 247 272 297 322 347 372 397 223 39.12 248 273 298 323 348 373 398 224 40.74 249 274 299 324 349 374 399 225 41.65 250 275 300 325 350 375 400 Tot 1011.77 Tot 522.94 Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 1534.71 TOTAL LENGTH = 9682.76 DIRECTIONS: TOTAL JOINTS THIS PAGE = 38.00 TOTAL JOINTS = 238.00 AVERAGE JT= 40.68 I (' It { Phillips Alaska Drilling Cementing Details ) Well Name: CD1-30 Report Date: 09/2612000 Report Number: 13 Rig Name: Doyon 19 AFC No.: 998C13 Field: Alpine Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 7" 8.5" 86. at TD 9520 9436 Centralizers State type used, Intervals covered and spacing Comments: Ran 52 straight blade centrallzel'$. I per Jt on 1st 18 Jts and every other Jt from 9 5/8" csg shoe to surface. Mud Weight: PV(prior cond): PV(afler cond): YP(prior cond): YP(after cond): Comments: 10.0/9.7 9 9 23 15 Gels before: Gels after: Total Volume Circulated: 9/12/14 8/10/11 700 bbls Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 bbls 8.5 Spacer 0 Type: Volume: Weight: Comments: ARCO 845 50 bbls 12.5 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: Additives: Tall Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: YIeld: .Commeilts: G 70 126 15.8 1.16 Additives: 0.2% D046, 0.25% D065, D.25% D800 and 0.18% D167 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: Comments: 6.5 6.5 310k Reciprocation length: Reciprocation speed: Str. WI. Down: 15' 10 fpm 165k Theoretical Displacement: Actual Displacement: Str. WI. In mud: 361 365 Calculated top of cement: CP: Bumped plug: Floats held: 8860' Date:9126/00 No Yes Time:02:08 Remarks:HAd full returns throughout Job. Reciprocated csg until wash rounded shoe, Cement Company: Rig Contractor: Approved By: Dowell DOYON Donald Lutrick ( AFC No. 998C13 Phillips Alaska Drilling RptNo 12 Rig Accept. hrs Days Since AccepVEst: 10/10 09/1612000 12:00:00 AM Rig Relase . hrs: Well: CD1-30 Date 09/2512000 Depth (MDITVD) Contractor: DOYON Daily Cost $ 240661 Rig Name: Doyon 19 Last Csg: 7" @ 9520' Operation At 0600: Test BOPE Upcoming Operations: RIH and drIll out cement and float equipment. MUD DATA MUD TYPE LSND WEIGHT 9.7PDa VISCOSITY 40sqc PVIYP 9/23 GELS 9/12/14 APIWL 5.2 I HTHP WL 12.0mll3O min SOLIDS 7.3% HOLE VOLUME 622bbl MBT 22.0 ph 9.2 LGS 4.8% ) PIT VOL 450 DAILY MUD $3017 TOTAL MUD $129874 COMPANY MI DRILLING DATA DEPTH BIT NO. 3 ROTWT PUWT SOWT AVG DRAG MAX DRAG TRQ BTM TRQ OFF PUMP PRES III PUMP NO 11211 LINER SZ 5.51611 SPM 1 III GPM2 III SPS 1 30140130140 SPP 1 III MUD WT III SIZE 8.5 MAKE HTC TYPE MXC09DX SERIAL NO G09DG DEPTH OUT 9531 DEPTH IN 8965 FOOTAGE 566 ADTIAST 15.23/13.07 WOB2 20 - 25 RPM 1 193.263 TFA .518 JETS 15115115111 BIT COST 12825 DULL 0111WTIA GRADE E III ER I DTF BIT DATA BIT NO. SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADTIAST 1 WOB2 . RPM1 - TFA JETS 11111 BIT COST DULL III GRADE III 953117075 Prev Depth MD: 9531 Cum Cost $ 1744763 Next Csg: N/A EH&S ACCIDENT (non-spill) N EMPLOYER SPILL N TYPE VOLUME (gallons) LAST SAFETY MTG 09/19/2000 " " INJECTION' INJECTION WELL CD1-45 SOURCE WEll CD1.30 RATE (bpm) 2 PRESSURE (psi) 1220 INJECTION FLUIDS Diesel 20 0 0 0 0 TOTAL VOL (bbl) 20 TOT FOR WELL (bbl) 1293 { Daily Drilling Report Progress: 0 Est Cost To Date $ 1725000 Shoe Test: DRILLS/BOP DATA LAST BOP/DIVERT LAST BOP/DRilL TST 09/25/2000 09/1812000 LAST H2S DRILL 08109/2000 LAST CONFINED SPACE 06/21/2000 "',J:;<','::~': '.,': :,~~EL&:~A~~:,"~:':',: ,:',:,':,:';~A~1í;;~:: FUEL USED 2200 LAST FIRE DRILL 09/19/2000 LAST SPILL DRill 09/17/2000 .. DRILL WATER USED - BBLS : POTABLE WATER USED. BBlS :,,~"";":,.:""'~', ,',\IV,~T.H~8;~:&;}"",,:""i ":':'::'~' -:";~",,, :"PI:RSONNELDATÄ"'" ",'..' ',,-,:, TEMP OF 30 490 85 WIND SPEED 12 WIND DIRECTION 3150 CHILL FACTOR of 12.83 PHILLIPS PERSONNEL 1 CONTRACTOR PERSONNEL 25 MISC PERSONNEL 5 SERVICE PERSONNEL 21 TOTAL 'Q1:IA\PE$ÇRIP.iTfQN'.>1'r:~:."'~(:;>!'."; Bit, 6.75" Mach 1X .1.50., CDR, NM5, MWD, 3. CSNMDP, XO, 3. HWDP, JARS, 25. HWDP : ;/-!>:;: ;\<);;,,~:;:,":;,:~t~,'k',:~î~:~'W~,j :~'!?i.;YJ¡'!;V; ;~;\~~i}'<:~>~'i.::.tDßllL'PIP:Þ.PA.'rA'W,~fMr:¥;.1.i.!.;xKij:':> ¡,~ ,:;,,{S~? ð';'~i; «j:¿<iJ;:Jì%f"W~;i!'~¡'h1~4' OD , ID ' WEIGHT GRADE CQ~N.ECTION, " CLASS ~", ':. LENGTH',', 5" 4.281 19.5 G.105 4.1/2 IF prem BHA NO BHA LENGTH DATE LAST INSPECTED: HOURS ON JARS: :".¡rlÍ!tIMEi ',;-~\~I+n'E:.ND.;: ,;; 12:00 AM 12:30 AM 12:30 AM 02:00 AM 02:00 AM 04:30 AM 04:30 AM 07:30 AM 07:30 AM 08:30 AM 08:30 AM 10:00 AM 10:00 AM 11:00 AM 11:00 AM 03:00 PM 03:00 PM 03:30 PM 03:30 PM 07:00 PM 07:00 PM 07:30 PM 07:30 PM 10:30 PM 10:30 PM 12:00 AM 207 hrs ,:'",":."I-!OURS, ," 0.50 1.50 2.50 3,00 1.00 1.50 24.00 1.00 4.00 0.50 3.50 0.50 3.00 1,50 3 1073,47 ,OPS:COPE: ' I,' WIPERTRP CIRC TRIP _OUT TRIP _OUT BHA OTHER PREP CASG CIRC CASG CIRC CA5G CIRC Daily Drilling Report: CD1-30 09/25/2000 52 ';:HOLESECT"".,IPHf\$E:OPS ,.'1 ,:,>,; r;\~,:"'~}QPE~TIONS:'FROMOOOO~:,QoQo>, ;"",' '";,/,t/},.:::,,, S1 P1 Making Hole Finish wlpertrlp. No problems. 51 P1 Making Hole Clrc sweep. Condition mud. 51P1 Making Hole POH w/5 stds, Pump dry job. POH to 3261'. 51P1 Making Hole POH LD excess 5" DP. 81 P1 Making Hole LD BHA. 51P1 Making Hole Flush out stack w/ wash tool. Pull wear bushing. Install thin wear bushing to run csg, RU to run 7" csg, 51P1 S1P1 S1P1 S1P1 S1P1 51P1 51P1 Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing PJSM. RIH W/7" csg to 3500'. CBU. RIH w/7" csg to 7000', CBU. RIH w/7" csg. MU hanger and land at 9520', RU cement head. Clrc and condition mud at 8 bpm. Page 1 ( ( Phillips Alaska Drilling Daily Drilling Report AFC No. Date RptNo Rig Accept. hrs Days Since AccepVEst: 11/11 Rig Relase . hrs: 998C13 09/2612000 13 09/1612000 12:00:00 AM Well: CD1-30 Depth (MDITVD) 953117075 Prev Depth MD: 9531 Progress: 0 Contractor: DOYON Dally Cost $ 209920 Cum Cost $1954683 Est Cost To Date $ 1925000 Ria Name: Doyon 19 last Csg: 7" @ 9520 Next Csg: NIA Shoe Test: 12.5 Operation At 0600: Displace to Flo-pro mud. Upcoming Operations: Drill horizontal. -~~:!MUD"DATA"" --DRllLlNG'DATA ' BIT DATA "., " EH&S" ,I" ,,' " DRILLSI aop DATA' ... ". MUD TYPE DE¡.>lH BIT NO, BIT NO, ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL KCLPLY 4 N TST 09/25/2000 09/2612000 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.2ppg 6.125 08109/2000 09/27/2000 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 45sqc SEC N SPACE 09/17/2000 06/21/2000 PVNP SOWT TYPE TYPE TYPE ' , :, ' ,F~EL:& W~!E~::~':':}\"::' :',>~JW;:: 12/20 FM2633 ,. : GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 1150 7/9/9 5009120 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED. 985 3.4 09/26/2000 BBLS HTHPWL TRQ BTM DEPTH IN DEPTH IN ',:- ' " , " POTABLE WATER 90 '!,~, :"<, ':' ~ ' , :' 10,Oml/30 min 9531 " INJEC110N ", USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL ': ~E~~TN~l~Ó\}fÄ"": '-:,',,', :,c>?;\': 6.3% 0 CD1-45 ' ' HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 25 312bbl I I I I I CD1-30 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 15 1121 I - - 3.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 270° 9.2 5.51611 - - 970 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 2.28 1.0% I I I .518 Water Base Muds 1019 PIT VOL GPM2 JETS JETS Diesel PHILLIPS 1 450 I II 151151151 I I I I III 40 PERSONNEL Other 231 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $43025 30140130140 18612 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $172899 I I I III I I I 1290 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 18 MI I I I II I I II 2583 PERSONNEL TOTAL 50 ! :":~ 'er~G.1j~M)i;\g* Bit, TBS, 4.75" Mach 1X (1.20°), NMS, 10' CSNMDP, MWD, PWD, 3 - NMCSDP, 3 - HWDP , ;',:,'",~~) '¡'<,:,;;-¡..;.;>,V !,~ ::"t~;.,-;:.,.(",:,,;:, :"";,'~,{~.íf,i.;'~t,~"-;::':':',Olill..tiPII;,',J;;'P.A1'¡ :t%;;tfg'i~~?i:~~¥'W' '~1:{<...:,:~' %;~~/.~:,:~i ï:':i:.\.,\~:ì:;t<~::' ~Î;i.:I~,,~¡;)f(;; 1i&'~ BHA NO 4 OD ,ID WEIGHT GRADE CONN,ECTIPN, CLASS 2': LEN,GTH" BHALENGTH 270.32 3.5" 2.766 13.3 5-135 3-1/2 I.F. Drem DATE LAST 3.5" 2.625 15.5 G-105 3-1/21.F. prem INSPECTED: HOURS ON JARS: ~1"ME;~)'}\I>'j\~iEND'" ';1' ~, ,HOURS",',:.' 'OpS CODE',' : HOLE SECT ':' :1f'HASEOPS ,; "~'","r',""i¡':':/'"',:>:,:;,'..OP..ERA.rIONs.:F.ROM.Ø090~:,QQPQ/':: '. " /,,:"';, "::' 12:00 AM 12:30 AM 0.50 CIRC 51P1 Casing and Clrc and condition mud. Cementing 12:30AM 02:30 AM 2.00 CEMENT S1P1 Casing and PJSM. Test lines to 3500 psi. Dowell pumped 20 bbls Cementing pre.flush, 50 bbls 12.5 spacer, bottom plug,26 bbls 15.8 cement, top plug, 20 bbls H2O and 345 bbls mud. Did not bump plug, Floats OK. 02:30 AM 03:00 AM 0.50 OTHER S1P1 Casing and RD csg and cementing tools. LD LJ. Cementing 03:00 AM 04:00 AM 1.00 OTHER S1P1 Casing and Pull wear bushing. Install packoff. Test to 5000 psi. Cementing 04:00 AM 05:00 AM 1.00 BOPE PROD Making Hole Change top rams to 3 1/2" x 6", Change over top drive to 3 1/2". Install corrosion ring. 05:00 AM 10:30 AM 5.50 BOPE PROD Making Hole Test all BOPE to 250 . 3500 psi wI annular to 2500 psl.RD test equipment. Install wear bushing. Witness of test was waived by AOGCC rep Lou Gramaldl. 10:30 AM 12:00 PM 1.50 BHA PROD Making Hole MU and orient BHA. 12:00 PM 09:30 PM 9.50 TRIP_IN PROD Making Hole PU and RIH w/3 1/2" DP. Tag up at 9280'.(Shallow test MWD at 1050') 09:30 PM 10:30 PM 1.00 CIRC PROD Making Hole tau. 10:30 PM 11 :30 PM 1.00 TEST_CSG PROD Making Hole Test csg to 3500 psi fl 30 min. 11:30 PM 12:00 AM 0.50 CLN_OUT PROD Making Hole Drill out cement fl9280' to 9323'. 24.00 Daily Drilling Report: CD1-30 09/26/2000 Page 1 CASING', ...3T and FORMATION INTEGRITY TEST Well Name: CD1-30 Date: 9/26/00 ._~. Supervisor: Donald Lutrick Reason(s} for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight EMW= Leak-off Press. + Mud Weight 0.052 x TVD 7" 26# L-80 BTCM CSG TOC Hole Depth: 8,8601 TMD 6,7631 TVD 6,1241 Mud Weight: 9.7 ppg Length of Open Hole Section: + 9.7 ppg Casing Size and Description: 9 5/8" 36# J-55 BTC CSG X Casing Setting Depth: 2,7361 TMD 2,3871 TVD = 636 psi 0.052 x 2,387' EMW for open hole section = 14.8 ppg "--- NO #2 Pump output = 0.0997 bps Used cement unit Ria pump used Fluid Pumped = 1.3 bbls Fluid Bled Back = 0.5 bbls W D:: ~ ~ 400 psi w 0:: a.. 800 psi 700 psi 600 psi 500 psi 300 psi 200 psi 1 00 psi 0 psi 0 10 ~ LEAK-OFF TEST ~CASING TEST .-+- LOT SHUT IN TIME -r- CASING TEST SHUT IN TIME -+-TIME UNE 20 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above BARRELS Modified by Scott Reynolds LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ('r - -, .--~-., I I 0 I 0 pSI I ---------------I-- .f-- -f I I 1 I 86 psi I I-------------f---------------~_. I I I 2 I 111 psi I 1------ I . I , 1 I 3 I 152 psi I }. . ---+--_u L I m-f I I 4 I 212 psi I I---------------f------._..L'."~- --f I I 5 I 263 psi I -------------f---~ I I I I 6 I 328 psi I ----.. -- I I -f I 1 7 I 379 psi I t u~ .-t-- 8 L~"t 449 psi t --------------4---. ... .f--- --f I I 9 I 545 psi I I-------------f--- I - I I I 10 I 611 psi I I--------~ -- I I I I 11 I 636 psi I -----------I --+ --f I I 12 I 636 psi I 1-----4--- i -I I I 13 I 636 psi I 1--------4 I ~ I I 13.5 I 631 psi I -------------- i .+-- ---f 1 1 1 1 1 I 1 1 'r---------t - I . n ---f 1 I 1 1 1 1 1 .. - 4----- I -----1 . 1 1 I 1 1 1 1 -_nu__- I. .. .f-- --------1 1 1 1 1 1 1 1 I ------I---- --- +--------1 1 1 1 1 I I I I 1--------1----+ ----f I 1 1 1 I I 1 I ----------1---------__-+-_r rrY ----f I . I I 1 I 1 I I- ._.~- f ~------------I 1 1 1 I }. . ~ - i._.......~-~_..+.................................i 1 I 1 I I I I I ~_~~_I!!E!"E I - ~!!.l1T IN PRESSUR.E ~-- 0.0 min i --+ 631 psi i 1 1.0 min I I 576 psi I ¡---- . 1-- ~ - I --:--; 1 2.0 mln 1 1 565 pSI 1 1---" -~ I --- I I 3.0 min I I 560 psi I -------I-". I . ---I I- 4.0 min I I ~55 P~i I 5.0 min I I 550 psi I ¡- . I tn_:--; 1 6.0 mJn 1 1 545 pSI 1 I . I'" -- - I :n_t 1 7.0 mJn I 1 540 pSI 1 I- or-iF I f I 8.0 min I I 535 psi I I- I ~----f I j 9.0 min I i 535 psi f l 10.0 min I ; 530 P8!LJ .PHILLIPS Alaska, Inc. A Slbsldiary 01' PHILLIPS PETROLEl-M COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE .-------~---r- ' I ~-----¡-~~!k.~~- 0 psi-i I =t' I I I- - ------- --------1 ~---------- ----t-----~ I l' I I 1---------------- ------------f---------------i I I I 1--------------- ---------------+-------------1 I I I I I I I /'"""'" ~--------t--------i-----------i . I 1 I 1 ! 1 I I-------------t------------f-----------i 1 I 1 1 1 I I I }------------t-----------+--------------f I I I I 1-- - -- -- --- 1-- - ------- --- f - ----- --------1 I I I , I I 1 I 1---- ---- ---- - - - - I - ------ - ------1 ---- --- -- - ----1 1 I 1 1 1 1 1 1 1---- - --- - -- - t--- ----- ----f---- - ---1 1 . I I 1 I I 1------ -- - --- 1-- - -- -- -- ---I ---- -- - ------i 1 ¡II I I I 1---------------- --------------f------------~ I 1 I 1 1 1 I 1 I----------------f---------------I----------------i I I I I 1--- - -- -- --- - - -- I -- - - -- -- - - - --I -- ----------i I I I I 1---- ---- --1----- - -- - ----1--- -------1 I I I . I 1 1 1 1----- ----------f---- - -- -- ---+--------------1 I 1 I 1 1 1 I 1 ~--------------I---------------+---------------i 1 1 I 1 I 1 1 I 1------- - -----1 -- - --- --- -- ----1----- ----------1 . 1 I I ! ! I I i SHUT IN TIME i SHUT IN PRESSURE ~-----------I---------------T-----------' I O.Omin I I 0 psi I t-~----I--------------t---------------1 1 1.0 mln I 1 1 ¡ 2.0 min¡---------¡-------1 ~. 1---- ---------f-------i I 3.0min I I I I- - - -- - - - f-- - -- ----- - -f--- - - --~ I 4.0min I I I I----------f---- t ----1 I 50 . 1 I I---~~---+-- ----------+--- ------i I 6.0min I I I I--------------I--------------+-------------~ I 7.0min I I I 1---------+---------------+-------1 I 8.0min I I I 1-- --1-----------1---------1 I 9.0min I I I ~-- -+-------f-----------I I 10.0 min 1 I I 1-------+- -- -----f------------1 I---! 5. 0 f!!L'!_¡___--~----~ I 20.0 min I I I t t----- I ; 1 25.0 min t- I I t - - I ~-f L 30.0 p1i'!.L----_l--__l NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Permit to Drill 2001320 MD 12850 -' TVD DATA SUBMITTAL COMPLIANCE REPORT 1116~2003 Well Name/No. COLVILLE RIV UNIT CD1-30 Operator CONOCOPHILLIPS ALASKA INC 7046 ""'"' Completion Dat 10/1/2000 ..~ Completion Statu 1-OIL Current Status 1-OIL APl No. 50-103-20348-00-00 UIC N _ REQUIRED INFORMATION Mud Log N._~o Sample N._~o Directional Survey ~ y~./~ _; DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval Start Stop 2700 12850 (data taken from Logs Portion of Master Well Data Maint C C L L L L L L L L R R L L C C L L L L R R 9793 ~ FINAL 2 FINAL 5 FINAL ~ TVD 2 FINAL ~MD 5 FINAL SRVY RPT'-'''''~ . o~,o~r~ Production 5 FINAL 9~5~''~ FINAL c.~Al~my~es MD 2/5 FINAL ~ay Res TVD 2/5 FINAL c..~Y RPT 2720 2720 2720 2720 2720 2720 0 9100 2746 2746 2746 0 9504 9461 9461 9461 9461 9461 9505 12768 12850 12850 12850 12850 Open CH CH CH CH CH OH CH CH CH CH OH OH I Dataset CH Received Number Comments Open 1/3/2001 09845 "'~-~0-12850 1/3/2001 0979~2720-9504 /~1 1/3/2001 9793t-'~2720-9461 Digital Data 1/3/2001 2720-9461 BL, Sepia 1/3/2001 2720-9461 BL, Sepia 1/3/2001 2720-9461 BL, Sepia 1/3/2001 2720-9461 BL, Sepia 10/9/2000 SCHLUM 0-9505 PH 9/16/00 THRU 6/15/2001 9100-12768 BL, Sepia 1/312001 9845 .~'~-12850 Digital Data 1/3/2001 2746-12850 BL, Sepia 1/3/2001 2746-12850 BL, Sepia 10/9/2000 SCHLUM 0-12850 9/16/00 THRU ...... Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Permit to Drill DATA SUBMITTAL COMPLIANCE REPORT 2001320 Well Name/No. COLVILLE RIV UNIT CD1-30 1/16/2003 MD 12850 TVD 7046 Well Cored? Y ~) Chips Received? ~ Analysis ~ R ~.c.~.iv~.d ? Operator CONOCOPHILUPS ALASKA INC Completion Dat 10/1/2000 Completion Statu 1-OIL Current Status Daily History Received? ~.~N Formation Tops (~/N 1-OIL APl No. 50-103-20348-00-00 UIC N Comments: Compliance Reviewed By: Date: (~,, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 430' FNL, 2910' FEL, Sec. 5, T11N, R5E, UM 5. Type of Well: Development _X Exploratorym StratJgraphic_ Service__ (asp's 385794, 5975699) 6. Datum elevation (DF or KB feet) RKB 36' feet 7. Unit or Property name Colville River Unit 8. Well number CD1-30 At top of productive interval 2098' FNL, 2129' FWL, SEC. 31, T12N, R5E, UM At effective depth At total depth 68' FNL, 4420' FEL, Sec. 31, T12N, R5E, UM (asp's 380711, 5978307) (asp's 379073, 5981447) 9. Permit number / approval number 200-132 / 301-109 10. APl number 50-103-20348 11. Field / Pool Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 114' SURF CASING 2746' PROD CASING 9520' OPEN HOLE 3330' Size 16" 9-5/8" 7' 6.125' 12850 7O46 12850 7046 feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured Depth True vertical Depth 10 cu yds Portland Type 3 114' 114' 405 Sx AS III Lite, 231 Sx Class 2746' 2394' 12e Sx C~ass G 9520' 7072' 9520'-12850' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) 4-1/2". 12.6#, L-80 Tbg O 9232' MD. Packers & SSSV (type & measured depth) BAKER 4.5 X 7' S-3 PACKER O 9144' MD. CAMCO BAL-O ~ 1786' MD. RECEIVED JUN 2,, 1 ' 00! Alaska Oil & Gas Cons. Commission Anchoraqe 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl .3862 Representative Daily Average Production or Injection Data Gas-Md Water-Bbl 4322 0 4216 4888 0 Casing Pressure Tubing Pressure 313 239 15. Attachments Copies of Logs and Surveys run m Dally Report of Well Operations __X 16. Status of well classification as: Oil mX Gas m Suspended Service 17. I her .~ly certify that the foregoing is true and correct to the best of my knowledge. Signed t Title Alpine Production Engineer Michael Erwin Prepared by Sharon AIIsup,-Drake 263.4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Operations Summary CD1-30 51412001: FORMIC ACID TREATMENT COMPLETED. 179 BBLS OF 8% FORMIC ACID USED W/139 BBLS SPRAYED AND LAYED IN ACROSS THE OPEN HOLE SECTION FROM 12375'- 9520', THEN SQUEEZED IN THE REMAINING 40 BBLS AT THE TAIL END. UTILIZED BOTH THE PIPE STRAIGHTENER AND FDR TO MAKE DEPTH OF 12375'BUT SHORT OF TD @ 12850'. RETURNS .75 TO 1 DURING THE JOB. FREEZE PROTECTED WELLBORE DOWN TO 2000' W/DIESEL. 5/4/2001 POST FORMIC ACID TREATMENT FLOWBACK COMPLETED. FLOWED BACK 150 BBLS OF DIESEL, 140 BBLS OF ACID/BRINE, 160 BBLS OF CRUDE, & 152 MSCF OF GAS.UTILIZED L/G TO GET THE WELL KICKED OFF. AS ACID WATER CAME BACK IT WAS CARRYING SOLIDS/EMULSION W/PH OF 3. CLEANED UP TO 100% CRUDE @ THE END OF FLOWBACK. TURNED WELL INTO THE FACILITY FOR PRODUCTION. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _X Change approved program _ Pull tubing _ Variance_ Perforate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box100360 Anchorage, AK 99510-0360 4. Location of well at surface 430' FNL, 2910' FEL, Sec. 5, T11N, R5E, UM At top of productive interval 2098' FNL, 2129' FWL, SEC. 31, T12N, R5E, UM At effective depth At total depth 68' FNL, 4420' FEL, Sec. 31, T12N, R5E, UM 5. Type of Well: Development ._X Exploratory m Stratigraphic m Service._ (asp's 385794, 5975699) (asp's 380711, 5978307) (asp's 379073, 5981447) 6. Datum elevation (DF or KB feet) RKB 36' feet 7. Unit or Property name Colville River Unit 8. Well number CD1-30 9. Permitnumber/approvalnumber 200-132 10. APInumber 50-103-20348 11. Field / Pool Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured 12850 feet Plugs (measured) true vertical 7046 feet Effective depth: measured 12850 feet Junk (measured) true vertical 7046 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 114' 16" 10 cu yds Portland Type 3 114' 114' SURF CASING 2746' 9-5/8" 405 Sx AS III Lite, 231 Sx Class 2746' 2394' G PROD CASING 9520' 7" 126 Sx aass C 9520' 7072' OPEN HOLE 3330' 6.125" 9520'-12850' OPEN HOLE Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 Tbg @ 9232' MD. BAKER 4.5 X 7" S-3 PACKER @ 9144' MD. CAMCO BAL-O @ 1786' MD. RECEIVED APR 2, 7 2001 13. Attachments Description summary of proposal __X Detailed operations program _ BOP sketch 15. Status of well classification as: 14. Estimated date for commencing operation May 4, 2001 16. If proposal was verb. ally approved ..._ Name of approver ~"~'" '1" ' Date approved Oil ._X Gas _ Suspended Service 17. I hereby, certify that the foregoing is true and correct to the best of my knowledge. Signed'~' ! "b ~ J"';~",,.~-~'~-~-~/ . . Title: Alpine Production Engineer Michael Efwin Questions? Call Michael Erwin @ 265-1478. Date Prepared by Sharon AIIsu~-Drake 263-4612 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance Mechanical Integrity Test~ Subsequent form required 10- _ Approvgd___by.oxd.e,~,,okt_h.e. ,,C,.q[~j~,sion I Villi i~/-,-~./~,~ i'~;~¥ ~11 ORIGINAL SIGNkL, .' - ' ' ....... g"l' l gl I I/'AL_ Commissioner JApproval no. , oL - t oq ~,.l~.,/J..llVii i i1'ii ii~ll i,.l~..~nll.= Stimulation Procedure Colville River Field CD1-30 Conversion operations will commence following ice road construction on or about April 1, 2001. Completion is expected on or about May 15, 2001. This procedure is designed to clean out and stimulate a newly drilled producer. The goal is to remove filtercake, drilled solids, and polymer from the openhole completion. - ~ 1. RU coil tubing unit. GIH with jet nozzle into the 6-1/8" open hole to circulate and wash the hole clean of debris or sand with diesel. e Spot +/-150 bbl. of DS 8% formic acid mixed in a 6% KCL base fluid in the openhole interval. "~ ~ 3. POOH and RD coil tubing. 4. Allow the breaker to soak for 4-6 hours. 5. Return the well to production. CTD BOP Detail ~ CT Injector Head Methanol Injection tis 7" WLA Quick onnect ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ I '-' 7' Riser I i I I 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic Hyddl Model B Flanged Fire Resistant Kelly Hose to Dual Choke Manifold HCR Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure 3/8" Slips 2 318" Pipes Kill line check valve ' Fire resistant Kelly HOSe to Flange by Hammer: up 1/4 Turn Valve on DS Hardline to Standpip manifold 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate' BOPE Manual over Hydraulic XO Spool $1/8" x 7.1/6' or as necessary 2' Side outlets 2" Combi Pipe/slip 2 flanged gate valves Single or Double Manual Master Valves THA 7" Annulus 9 5/8" Annulus' Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'I'TN: Sherrie NO. 664 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine 11 ~2~00 Color Well Job # Log Description Date BL Sepia Prints CD CD1-30 20422 GR/CDR/ADN/IMPULSE 000930 1 CD1-30 20422 MD ARRAY RES 000930 I 1 CD1-30 20422 TVD ARRAY RES 000930 I 1 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ] '1/2/OO Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 664 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-30 PB1 20421 GR/CDR/ADN 000922 1 CD1-30 PB1 20421 MD CDR 000922 I 1 CD1-30 PB1 20421 TVD CDR 000922 I 1 CD1-30 PB1 20421 MD ADN 000922 I 1 CD1-30 PB1 20421 TVD ADN 000922 I I DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 664 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine 11/2/00 Color Well Job # Log Description Date BL Sepia Prints CD CD1-30 20422 GR/CDR/ADN/IMPULSE 000930 1 CD1-30 20422 MD ARRAY RES 000930 I 1 CD1-30 20422 TYD ARRAY RES 000930 I I Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 664 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine 1112/00 Color Well Job # Log Description Date BL Sepia Prints CD CD1-30 PB1 20421 GR/CDRIADN 000922 1 CD1-30 PB1 20421 MD CDR 000922 I 1 CD1-30 PB1 20421 TVD CDR 000922 I 1 CD1-30 PB1 20421 MD ADN 000922 I 1 CD1-30 PB1 20421 TVD ADN 000922 I I SIGNED~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well , "_",':" ":'.'i:'!:;'i:i' ~ Classification of Service Well Oil E~ Gas D Suspended D Abandoned r-~ service ~1 !-~.O.-:'~T.~ Phillips Alaska, Inc. ..2.5 ................ -~.,~ 200-132 RECEIVED 8' APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20348,-00 4. Location of well at surface .9. Unit or Lease Name 430' FNL, 2370' FWL, Sec. 5, T11 N, R5E, UM (ASP: 385795, 5975700) J A N 0 3 ;~ 0 01 co~v,~, ,ive~ Un*~ At Top Producing Interval 10. Well Number 3135' FNL, 2095' FWL, Sec. 31, T12N, R5E, UM (ASP: 380678, 5978355) CD1-30 & CD1-30PB1 At Total Depth Alaska 0ii & Gas Cons. Commission 11. Field and Pool 69' FNL, 440' FWL, Sec. 31, T12N, RSE, UM (ASP: 379073, 5981447) Allchorage Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool RKB 36 feetI ADL 25558, 25559 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions September 16, 2000 September 29, 2000 October 1,2000 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 12850' MD/7046' TVD 12850' MD/7046' TVD YES r~l No D~ I 1786' feetMD 1627' 22. Type Electric or Other Logs Run GR/Res/Neut/Dens 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO"I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 10 cu ydsPortland Type III 9.625" 36# J-55 Surface 2746' 12.25" 405 sxAS III Lite & 231 sx Class (3 7" 26# L-80 Surface 9520' 8.5" 126 sx Class G CD1-3o PB1 cement plug dressed off to 8960' to start CD1-30 sidetrack 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 9232' 9144' Open hole completion 6.125" OH from 9520'-12850' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9503'-8992' Plug #1:40.5 bbb 15.8 cement 8992'-8424' Plug #2:40.4 bbls 17.0 Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Flowing Date of Test Hours Tested Production for OIL*BBL GAS-MCF WATER-BBL CHOKE SIZE JGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER*BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORiGiNAL Submit in duplicate 29. 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. Alpine D 9301' 7026' Base Alpine 9362' 7046' N/A RECEIVED JAN 0 3 ZOO1 AJaska Oil & Gas Cons. Commission Anchorage 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Reynolds 265-6253 Signed ~;~,.'~, O~, Title Alpine Drilling Team Leader Date G. C. Alvord Prepared by Sharon AIIsup-Drake 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ORIGINAL Date: 11/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CD1-30 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT SPUD:09/16/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20348-00 09/14/00 (D1) TD/TVD: 114/114 SUPV:DONALD LUTRICK MW: 0.0 VISC: 0 PV/YP: 0/ 0 (114) REPLACE ELECTRICAL CABLES APIWL: 0.0 Move sub base over CD1-30. Work on routing new electrical cables. Service drawworks. 09/15/00 (D2) TD/TVD: 114/114 SUPV:DONALD LUTRICK MW: 0.0 VISC: 0) PREP TO SPUD WELL. Continue to prepare well. 0 PV/YP: 0/ 0 APIWL: 0.0 09/16/00 (D3) MW: 9.6 VISC: 180 PV/YP: 20/41 APIWL: 13.6 TD/TVD: 2025/1880 (1911) DRLG AT 2527' SUPV:DONALD LUTRICK Function test diverter system. Pre-spud meeting. Drilling from 114' to 2025' 09/17/00 (D4) MW: 9.6 VISC: 54 PV/YP: 25/15 TD/TVD: 2746/2394 (721) NU BOPE SUPV:DONALD LUTRICK APIWL: 22.0 Drilling from 2025' to 2746'. Circ and condition mud. POH to 1550'. Tight from 1912' to 1600'. RIH. No problems. Circ and condition mud. POH. RU to 9-5/8" casing. PJSM. RIh w/9-5/8" casing to 2736'. Circ and condition mud for cement job. PJSM. Pump biozan pill with nut plug. 09/18/00 (D5) MW: 9.6 VISC: 42 PV/YP: 10/20 TD/TVD: 3100/2644 ( 354) WIPER TRIP AT 3766' SUPV:DONALD LUTRICK APIWL: 9.2 Pump cement. Bumped plugs. Floats OK. ND diverter. NU BOPE and test to 250/3500 psi. RIH to TOC at 2650'. Circ and condition mud. Test casing to 2500 psi, OK. Drill out cement, float equipment and 20' new formation to 2766'. Circ and condition mud to balance mud wt. Perform 16.0 ppg EMW FIT. Displace to LSND mud. Drilling from 2766' to 3100'. 09/19/00 (D6) MW: 9.6 VISC: 42 PV/YP: 11/16 TD/TVD: 5706/4497 (2606) DRLG AT 6500' SUPV:DONALD LUTRICK APIWL: 5.2 Drilling from 3100' to 3765'. Circ sweep. Wiper trip to shoe. No problems. Drilling from 3765' to 5289'. Circ sweep. Wiper trip to 3670'. No problems. Drilling from RECEIVED JAN 0 2 2001 Alaska 0tl & Ga~ Cons. Commission Anchorage Date: 11/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 09/20/00 (D7) TD/TVD: 5706/4497 ( SUPV:DONALD LUTRICK MW: 9.7 VISC: 42 PV/YP: 8/23 0) DRLG AT 7450' APIWL: 4.2 Drilling from 5706' to 6716'. Circ sweep. Wiper trip to 5277'. Drilling from 6716' to 7097'. Top drive would not rotate right or left. Troubleshoot electrical and repair top drive. Wiper trip to shoe. 09/21/00 (DS) MW: 9.6 VISC: 40 PV/YP: 7/20 APIWL: 5.5 TD/TVD: 9032/6888 (3326) CIRC AT 9505'. (TD) SUPV:DONALD LUTRICK Finish wiper trip to shoe. Drilling from 7097' to 8525' Circ sweep. Wiper trip to 7095'. Tight at 7680'. Backream from 7668' to 7573'. Drilling from 8525' to 9032'. 09/22/00 (D9) MW: 9.7 VISC: 40 PV/YP: 9/16 APIWL: 5.8 TD/TVD: .9505/7225 (473) POH W/ MULESHOE. SUPV:DONALD LUTRICK Drilling from 9032' to 9505'. Circ lo/hi vis sweep. Wiper trip to 7400'. No problems. Circ lo/hi vis sweep. POH. RIH w/muleshoe. Circ and condition mud to balance mud weight. Prep to spot plug $1. 09/23/00 (D10) TD/TVD: 8940/6728 ( SUPV:DONALD LUTRICK MW: 9.7 VISC: 43 PV/YP: 10/19 0) DRLG AT 9050' APIWL: 6.2 Pump cement to balance plug. POH to 8992'. Circ out contaminated cement. Pump cement to balance plug. POH to 8424'. Circ out contaminated mud. POH w/muleshoe. MU and orient BHA. Shallow test MWD. Tools not communicating. Check tool connections. Shallow test MWD, OK. RIH to 8111'. Ream from 8111' to TOC at 8440'. Drill out cement from 8440' to 8940'. 09/24/00 (Dll) TD/TVD: 9531/7075 ( 591) POH SUPV:DONALD LUTRICK MW: 9.6 VISC: 40 PV/YP: 8/25 APIWL: 5.0 Drilling cement from 8940' to 8960'. Time drill from 8960' to 8990' to sidetrack well. Drilling from 8990' to 9531' Bit stopped drilling. Suspect broken shaft in motor. Circ sweep. Reciprocate pipe. Did not rotate. Wiper trip to 7400'. No problems. 09/25/00 (D12) TD/TVD: 9531/7075 ( SUPV:DONALD LUTRICK MW: 9.7 VISC: 40 PV/YP: 9/23 0) TEST BOPE APIWL: 5.2 Finish wiper trip. No problems. Circ sweep. Condition mud. POH. Pump dry job. POH to 3261'. POH. RU to run 7" casing. PJSM. RIH w/7" casing. SBU. Continue running in hole w/7" casing. Sirs and condition mud. RECEIVED JAN 2001 Alaska Oil & Gas Cons. CommissiOn 'Anch~ Date: 11/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 09/26/00 (D13) TD/TVD: 9531/7075 ( SUPV:DONALD LUTRICK MW: 9.2 VISC: 45 PV/YP: 12/20 0) DISPLACE TO FLO-PRO MUD. APIWL: 3.4 Circ and condition mud. PJSM. Pump cement, bottom plug and top plug. Install packoff and test to 5000 psi. Test all BOPE to 250/3500 psi. RIH and tag up at 9280'. CBU. Test casing to 3500 psi. Drill out cement from 9280' to 9323' 09/27/00 (D14) MW: 9.2 VISC: 46 PV/YP: 12/24 APIWL: 4.0 TD/TVD:10723/7070 (1192) DRILLING 6-1/8" HOLE FROM 11129' SUPV:DAVID BURLEY Drill out cement and float equipment from 9323' to 9531' Drill 20' of new hole to 9551'. Circ hole clean. Performed FIT to 12.5 ppg. PJSM. Changed hole over to 9.2 ppg Flo-Pro fluid. Drill 6.125" hole from 9551' to 10723'. 09/28/00 (D15) MW: 9.2 VISC: 47 PV/YP: 12/25 APIWL: 3.6 TD/TVD:12082/7052 (1359) DRILLING AHEAD FROM 12375' SUPV:DAVID BURLEY Drill from 10723' to 11314'. Pumped low/high vis sweeps and circ hole clean. Pump out to shoe, monitor well, RIH, no problems. Drill from 11314' to 12082' 09/29/00 (D16) MW: 9.2 VISC: 28 PV/YP: 0/ 0 TD/TVD:12850/7046 (768) LAYING DOWN 3-1/2" DRILL PIPE. SUPV:DAVID BURLEY APIWL: 0.0 Drill from 12082' to 12850' TD. Pumped low/high vis sweeps and circ hole clean, monitor well. Pump out to shoe, no problems. RIH to 12787', no problems. Precautionary ream from 12787' to 12850'. Pumped low/high vis sweeps and circ hole clean. PJSM. Changed well over to 9.2 ppg KC1 brine. 09/30/00 (D17) MW: 9.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12850/7046 ( 0) MU "EMERGENCY TUBING HANGER" AND SSSV CONTROL LINES. SUPV:DAVID BURLEY Complete displacement to 9.2 ppg brine. POH to 11500', spotted Flo-Pro pill in open hole. POH to 9168', monitor well, 12 bph losses, pumped 9.6 ppg brine. POH. RU to run 4.5" tubing. PJSM. RIH with 4.5" completion equipment. 10/01/00 (D18) TD/TVD:12850/7046 ( SUPV:DAVID BURLEY MW: 0.0 VISC: 0 PV/YP: 0/ 0 0) RIG RELEASED @ 20:00 HOURS. APIWL: 0.0 Change out tubing hanger and land tubing. Attempted to test hanger seals, top seal leaked. Change out tubing hanger with compression seals. Seals tested good to 5000 psi. ND BOPE. Tested tree to 5000 psi. PJSM. Set packer and test tubing to 3500 psi. Test casing to 3500 psi. Displaced well with brine and diesel. Released rig ~ 2000 hrs. 10/01/00 RECEIVED J. N 2001 Alaska Oi! ~ Ga~ Cons. Commission Anchorage SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00048 Company PHILLIPS ALASKA, INC~. .. Rig Cbntractor & NO. Doyon Drilling Co.- Rig: #19 Well Name & No. PAD CD#I/30PH1 / 30 Survey Section Name Definitive Survey WELL DATA Sidetrack No, Page 1 Field ALPINE FIELD of 4 BHI Rep. MILCHAK ! GEHRES Target TVD - - Target Description Target Direction (F'r) Target Coord. N/S Slot Coord. N/S -33~.85 Target Coord. E/W Slot Coord. E/W auil~Walk\DL per: 100ft~ 30mE1 !om~ Vert. Seo..Azim. SURVEY DATA (DO) Date .- 16-SEP-O0 16-SEP-00 16-SEP-00 16-SEP-O0 16-SEP-OO 16-SEP-00 16-SEP-00 16-SEP-O0 16-SEP-O0 16~SEP-OO 16-SEP-00 16-SEP-00 '16-SEP-O0 16-SEP-O0 16-SEP-00 16-SEP-00 16-SEP-00 16-SEP-O0 16-SEP-00 17-sEP'00 17-SEP-00 17-SEP-00 17-SEP-O0 Survey Depth 0.00 114,00 265.00 446.00 565.00 655.00 743.00 832.00 924.00 1013.00 1109.00 1203.00 1300.00 1395.00 1489.00 1585.00 1680.00 1775.00 1870.00 1965.00 2060.50 2155.96 2251.00 2346.00 Hole Course Vertical Direc. tion Length . TVD Section (DO) - (FT) (FI~ 0.00 0.00 0.00. 0.00 114.00 114.00 0.00 289.00 .151.00 264.92 -4.06 290.00 181.00 445.15 -19.49 290.14 119.00 ' 563.08 292.62 90.00 652,11 295.17 88;00 ' 739.07 294.91 3o2.05 300.07 89.00 826.82 92.00 917.18 89.00 '1003.97 .. 2cJ6.00 96.00 1096.32 294.37 94.00 1.185.30 294.84 97.00 1275.81 296.61 .95.00 1362.84 298.30 94.00 1446.85 -34.45 ' -46.80 -59.17 -72.69 -87.93 -104.88 -128.14 . . -155.69 -187.53 -221.98 -259.56 298.29 96.00 1530.27 -301.60 297.54 '- 95.00 1610.95 295.64 95.00 1689.59 293.62 95.00 1764.78 293.64 -.~95.00 1836.73 295.71 95.50 297.25 95.46 296.33 '95.04 297.21 95.00 1906.96 1975.65 2042.98 -346.16 -394.05 -447.06 -504.i3 -563.19 -622.82 -683.00 Grid Correction 0.000 2461.78 Magn. Declination 25.000 90.58 Magn. to Map Corr.' 25.000 Total Coordinate N(+) / S(-) E(+) / W(-) 0.00 0.00 0.00 0.00 1.39 -4.05 6.89 -19.42 12.34 -34.32 17.16 -46.63 22.63 -58.94 28.91 -72.40 37.20 -87.56 47.31 -104.41 59.52 -127.55 72.38 -154.96 86.90 -186.66 103.46 -220.94 122.92 -258.33 145.43 -300.14 i68.90 .-344.46 192.72 -392.12 216.86 -444.89 241,72 -501.71 268.75 -560.50 298.31 -619.83 328.54 -679;71- 2109,88 -743'.52 358.92 -739.93 Depths Measured From: RKBJ~ MSL~ SSu Calculation Method MINIMUM CURVATURE Map North to: OTHER Build Rate Walk Rate Build (+) Right (+) Drop (-) Left (-) 0.00 2.15 2.13 0.55 0.95 0.12 0.48 2.76 0.34 2.90 1.45 -0.29 1.29 7.76 2.97 -2.22 3.64 -4.24 2.61 -1.73 2.16 0.48 3.18 1.86 Comment TIE IN POINT 8' M1C 1.4 DEG AKO 3.20 1.80 3.13 -0.01 1.52 -0.79 3.22 -2.00 4.23 -2.13 2.29 O.O2 1.71 2.17 1.06 1.61 0.84 -0.97 -0.12 0.93 : .... SURV CALC-U TION AND"FIELDWORKSHEET Job.o. · '."::'Company PHILLIPS'ALASKA; inc. Rig Cbntractor & No. Doyon Drilling Co.- Rig: #19 Well Name & NO. PAD CD#1/3oPH1 /30 Survey Section Name Definitive Survey WELL DATA Sidetrack No. Page 2 Field ALPINE FIELD BHI Rep. MILCHAK ! GEHRES of 4 Target TVD . (F-r) Target Coord. N/S- . Slot Coord. N/S -33~.85 Grid Correction 0.000 Target Description Target Coord. F_/W Slot Coord. E/W 2461.78 Magn. Declination 25.000 Target Direction' :(DD) auil~Walk\DL per: lOOft[~ 30ml'-I lO'm[-] Vert. Sec. Azim. 90.58 Magn. to Map Corr. ' 25.000 Survey Date Depth (FT) 17-SEP-O0 2442.00 17-SEP-00 2537.00 17-SEP-O0 2630.00 17-SEP-O0 2686.00 18-sEP-00 2834.00 18-sEP-O0 2929.00 18-SEP-00 3023.00 19-SEP-O0 3120.00 19-SEP-00 3214.00 19-SEP-00 3308.62 19~SEP-O0 3405.00 19-SEP-O0 3500.00 19-SEP-O0 3595.00 19-SEP-O0 3686.00 '19-sEP-O0 3784.00 · -. 19-SEP;O0 3880.00 19'SEP-00 3975.00 19-SEP-O0 4071.00 19-SEP-O0 4167.00 !9-SEP-O0 4263.00 :.19'SEP.O0. 4356.00' '.19-$EP-00 4452.00 I' 19-SEP-O0 4547.00 ".1-:~-~-EP----~ 4640.l~)0" SURVEY DATA Total Coordinate Hole Course Vertical Direction Length TVD Section N(+) / S(-) E(+) I W(-) (DD) (FT) (FT) (FT) (Fl) 295.31 96.00 2177.79 295.72 · 95.00 2245.21 295.98 93.00 2311.20 295.27 56.00 2351.03 292.20 148.00 2457.40 29;4.07 95.00 2525.30 293.62 94~00 2591.41 97.00 2659.52 94.00 293.83 295.47 2725.92 2792.99 298.68 .94.62 :_ 294.62 98.38 2651.40 294.21 95.00 2929.24 295.06 95.00 2997.17 292.30 91.00 3062.43 292.96 98.00 3133.29 295.51 96.00 3202.62 295.18 .... 95.00 3271.12 298.45 96.00 3339.63 297.02 96.00 3407.28 296.61' -.~.'~.. 96.00 3475.12 3541.06 ' 3609.21 3676.66 .-804.67 · '-865.36 -924.62 -960.28 -1054.87 -1116.22 -1177.62 -1241.12 -1301.87 -1362.11 -1423.60 -1434.43 -1545.08 -1603.40 -1666.14 -1726.96 -1786.73 -1847.55 -1908.69 -1969162 -2028.76 -2089.83 -2150.32 295,75 93.00 296.23 96.00 295.48 95.00 295.12 93.00 3742.73 -2209.78 388.94 -800.77 417.78 -861.1.8 446.35 -920.15 453.37 -955.64 504.81 -1049.82 530.92 -1110.91 657.94 -1172.03 585.73 -1235.26 613.47 -1 295.72 642.81 ' -1355.67 672.20 -1416.87 699.69 -1477.42 727.37 .-1537.79 752.85 -1595.86 778.89 -1658.34 806.15 -1718.89 834.33 .-1 778.38 863.62 -1838.91 894.26 -1899.74 924.91 -1950.36 -953.84 -2019.21 983.47 -2079.98 1012.64 -2140.18 1040.61 '-2199.36 Depths Measured From: RKB ~ MSLr-I SSu Calculation Method MINIMUM CURVATURE Map North to: OTHER Build Rate Walk Rate Build (+) Right (+) Drop (-) Left (-) -0.43 -1.98 0.05 0.43 -0.04 0.28 · 0.45 -1.27 Comment -0.64 -2.07 6 3/4' M1XL 1.2 DEG AKO 1.66 1.97 0.30 -0.48 -0.10 0.22 · 0.63 1.74 0.21 1.28 -0.35 -2.14 -0.41 -0.43 0.26 0.89 · 0.65 -3.03 -0.41 0.67 0.58 2.66 · 0.39 -0.35 1.64 1.32 -0.11 0.59 .0.22 -0.43 · 0.18 -0.92 0.02 0.50 -0.03 -0.79 .0.04 -0.39 SURV CALCULATION' AN'DFIELD'iWORKSHE Job No. 045000048 Sidetrack No. Page 3 o~ 4 ComPany PHiLLIPS:ALASKA, IN~. Well Name & NO: PAD cD~I/3OpF-I1 /30 Rig CbntractOr & No. Ooyon-Drilling Co. - Rig: #19 Survey Section Name Definitive Survey ' . . WELL DATA Field ALPINE FIELD BHI Rep. MILCHAK / GEHRES Target TVD Target DescriPtion Target Direction Target C°ord. N/S . Slot Coord. N/S -335.85 Grid Correction Target Coord. F_/W Slot Cooed. E/W 2461.78 Magn. Declination Build~Walk\DL per: lOOffr~ 30m0 lomE] Vert. Sec. Azim. 90.58 Magn. to Map Corr. SURVEY DATA Survey Date ' DePth {F'r) . i9-SEp-o0 4737.00 19-SEP-00 4832.00 19-sEp-OO' 4927.75 19,SEP-00 5022.00 ig-SEP-o0 5118.66 . . . 1990EP-oo 5207.99 19-SEP-O0 5308.79 19-SEP-O0 5498.97 19-SEP-O0 5689.00 20'SEP-O0 5879.15 20~SEP-O0 6069.93 20-SEP-00 6260.46 20-SEP-O0 6449.71 .. . . . . '.20-SEP-00 6641.11 :'20-SEP-00 6736.38 20-SEP-O0 6925.35 21-SEP-00 7116.86 .... 21 -SEP-O0 7307.32 21-SEP-00 7402.13 . . '21-SEP-O0 7592.91 .... : 2~-~EP-(~ 7782.43 ~;973.24 .. '21 -~EP-00 8163.61 21 -SEP-O0 8353.97 :.. Total Coordinate Hole Course DirectiOn Length . TVD N(+) / S(-) E(+) / W(-) (DD) - ~ '(FT') (FT) (Fi') . 295.79 97.00 3811'.71 295.25 · 95.00 3879.63 294.15 95.75 3948.34 294.36 94;25 4016.40 295.42 '96.66 ~1085.03 Vertical Section -2271.65 -2331.97 ;2392.74 -2452.45 -2514.46 -2572.77 295.28 89.33 4147.13 1069.92 -2260.93 1098.59 -2320.97 1126.41 -2381.46 1153.19 -2440.90 1181.85 -2502.63 1209.34 -2580.66 1241.00 -2625.58 1300.44 -2747.92 1356.72 -2869.62 1409.72 ' -2991.41 1464.36 -3113.31 1522.83 -3234.05 1581.40 -3353.09 1638.62 -3472.99 1667.55 -3532.30 1727.74 -3648.90 1788.48 -3766.95 296.51 100~80 4217.17 -2638.30 295.42 190.18 4350.36 -2760.94 294.21 190.03 4485.02 -2883.20 ' 292.82 190.15 462i .07 -3005.53 .. 295.45 190.78 4757.28 -3127.97 296.23 190.53 4892.57 -3249.30 296.16 189.25 5027.52 -3368.93 294.86 191.40 5165.30 -3489.40 297.14 95.27 5234.02 -3549.00 297.46 188.97 5370.00 -3666.21 297.00 <-191.51 5508;02 -3784.86 297.07 190.46 5645.55 -3902.83 296.40 94.81 5714.38 -3961.35 295.40 -'~190.78 5852.98 .4079.86 295.88 189.52 5989.98- -4198.48 294.87 190.81 ' 6128.06 296.15 190.37. 6264.59 295.56 190.36 6400.35 -4318.03 -4438.31 -4558.98 .... . ..... 1 648.37 -3884.32 1877.7O -3942.54 1934.97 -4060.48 1991.63 .4178.53 2048.07 -4297.51 2105.22 -4417.22 '-4537.31 2163.42 0.000 25.000 25.000 Depths Measured From: RKB I~ MSLF'I SS~ Calculation Method MINIMUM CURVATURE Map North to: OTHER Build Rate Build (+) Orop (-) Walk Rate Right (+) Left (-) -0.07 0.69 -0~40 -0.57 -0.42 -1.15, -0.19 0.22 2.22 1.10 0.29 -O.16 -0.20 1.22 -0.36 -0.57 -0.34 -0.64 · 0.26 -0.73 0.40 1.38 · 0.07 0.41 Comment · 0.19 -0.04 -0.39 -0.68 0.54 2.39 -0.13 0.17 0.03 -0.24 · 0.14 0.04 -0.41 -0.71 0.17 -0.52 0.14 0.25 -0.20 -0.53 0.76 0.67 -0.41 -0.31 SURVEY-CALCULATION.AND FIELD WORKSHEET Job'No. Company PHILLIPS ALASKA. INC. Rig Contractor & No. Doyon Drilling Co.- Rig: #19 Well Name & No. PAD CD#!/3OPH1 / 30 Survey Section Name Definitive Survey WELL DATA Sidetrack No. Page 4 Field ALPINE FIELD BHI Rep. MILCHAK / GEHRES e4 4 Target TVD Target Description Target Direction (FT) Date ' 21 -SEP-00 21 -SEP-00 '21 -SEP-00 21 -SEP-00 22-SEP-00 22-SEP-00 22-SEP-00 22-SEP-00 Survey Depth {F~) 8448.97 8639.69 8829.66 8965.01 9211.37 9400.44 9505.00 Target Coord. N/S. Slot Coord. N/S Target Coord. E/W Slot Coord. E/W Build, Walk\DE per; lOOft[~ 3omE] 10ml-I Vert. Sec. Azim. SURVEY DATA Hole Course Direction Length TVD (DO) . (FT) (FT) 295.04 95,.0~ 6468.75 294.96 _ 190.72 6607.25 . 296.53 189.97 6743.91 295.76 135.35 6840.33 296.06 246.36 '7016.85 296.22 189.07 7151.1 2 Vertical SectiOn -4618.86 -4738.25 -4857.65 -4943.33 -5098.67 -5218.75 -5238.13 -5285.93 295.40 30.20 :7172.41 295.40 .74.38 7224.91 -335.85 Grid Correction 0.000 2461.78 Magn. Declination 25.000 90.58 Magn. to Map Corr. ' 25.000 Total Coordinate N(+) ! S(-) 2191.59 2247.00 2304.34 2346.20 2421.29 2479.94 2489.26 2511.85 .. E(+) I W(-). -4596.91 -4715.74 -4834.57 -4919.84 -5074.42 -5193.91 -5213.20 -5260.77 Depths Measured From: RKB ~] MSLr-] SS~; Calculation Method MINIMUM CURVATURE Map North to: OTHER Build Rate Walk Rate Build (+) Right (+) Drop (-) Left (-) Comment -0.37 -0.55 -0.38 -0.04 0.95 0.~, -0.49 -0.57 0.00 0.12 0.55 0.08 -0.60 -2.72 0.00 0.00 Projected Data- NO SURVEY WELL DATA - . Target TVD · (FT) Target Coord. N/S Slot Coord. N/S -335.85 Grid Correction 0.000 Target Description Target Coord. E/W Slot Coord. F_JW 2461.78 Magn. Declination 25.000 Target Direction' (OD) auild\Walk\DL per:.lOOft[~ 30m0 1OmOVert. Seo..Azim. 331.90 Uagn. to Map Corr. ' 25.000 Survey Date Depth 8965.01 24-SEP-00 8994.90 24'SEP-O0' 9027.68 24-SEP-O0 9058.79 24-SEP-O0 9089.74 24-SEP-O0 9123.00 24-SEP-00 9153.75 24-SEP-O0 9185.71 24-SEP-00 9218.24 24-SEP-O0 9248.55 24-SEP-00 9279.49 24-SEP-O0 9314.63 24-SEP-O0 9344.14 24~SEP-O0 9376.70 24-SEP-O0 9410.56 24-SEP-O0 9442.32 24-SEP-O0 9459.69 27-SEP-O0 9584.90 27-SEP-O0 9679.36 27-SEP-O0 9773.46 27-SEP-00. 9866.52 27-SEP-O0 ' l)960.75 27-SEP-00 10054.38 27-SEP-O0 10150.33 SURVEY DATA Hole Course Total Coordinate Walk Rate Right (+) Direction Length TVD N(+) /S(-) Left (-) (DO) . (FT) (Fr') (FT) '295.76 . . 6840.33 301.23 . 29.89 6861.48 32.78 6883.98 304,36 307.11 31.11 6904.46 308.85 30.95 '6923.88 31 i .27 33.26 6943.62 313.32 30.75 6960.80 315.92 3! .96 6977.50 3i7.65 32.53 6993.15 320.06 · 30.31 7006.48 321.85 30.94 7018.74 324.16 35.14 '7031.05 325.20 29.51 7040.17 326.29 32.56 7048.90 327.15 33.86 7056.45 327.86 31.76 7062.25 328.57 17.37 7064.92 330.28 125.21 7078.66 329.51 .94.46 7083.98 330.43 ~ 94.10 7087.10 331.O0 93.06 7088.15· 330.88 94.23 7087.53 Vertical Section 4387.52 4404.59 4425.42 4446.43 4468.46 4493.30 4517.33 4543.34 4570.87 4597.39 4625.28 4657.79 4685.63 4716.81 4749.68 4780.81 4797.94 4922.25 5016.50 5110:49 5203.52 5297.73 5391.34 5487.25 330.61 93.63. 7086.73 ... 330.22 '95.95 7085.26 2346.20 2356.29 2369.20 2382.68 2397.72 2414.95 2432.11 2451.25 2472.04 2492.54 2514.60 2540.89 2563.78 2589.71 2617.30 2643.64 2658.23 2765.35 2846.94 2928.36 3009.52 3091.88 3173.57 3257.00 Build Rate Build (+) E(+) / W(-) (F~ Drop (-) -4919.84 '4938.39 5.02 -4958.42 5.61 '4977.41 7.94 -4996.41 7.11 -5016.88 8.00 -5035.74 7.32 -5055.13 8.39 -5074.64 8.61 ' -5092.55 8.51 -5110.44 9.24 -5130.23 8.0O -5146.46 7.49 -5164.11 8.29 -5182.22 7.74 -5198.99 6.77 -5208.03 6.45 -5271.32 3.21 -5318.62 2.25 -5365.68 0.55 -5411.20 2.13 -5456.97 0.07 -5502.72 '-5550.09 Depths Measured From: RKB ~ MSLE] SS~- Calculation Method MINIMUM CURVATURE Map North to: OTHER Comment TIE IN POINT 18.30 6 3/4' M1X 1.5 DEG AKO 9.55, 8.84 5.62 7.28 6.67 8.14 5.32 7.95 5.79 6.57 3.52 3.35 2.54 2.24 4.09 1.37 4 3/4' M1X 1.2 DEG AKO -0.82 0.98 0.61. -0.13 0.18 -0.29 0.61 -0.41 SURVEY CALCULATION AND FIELD WORKSHEET Job No. Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Well Name & No. PAD CD#1/30PH1 / 30 Survey Section Name CD1-30 MWD WELL DATA Sidetrack No. I Page 2 Field ALPINE FIELD BHI Rep. MILCHAK / GEHRES of 3 Target 'I'vD Target Description Target Direction (FT} Target-Coord. N/.S Slot Coord. N/S -335.85 Grid Correction 0.000 Target Coord. E/W Slot Coord. E/W 2461.78 Magn. Declination 25.000 (DD) Build\Walk\DE per: 100ft[~ 30m[~ 10mu Vert. Sec..Azim. 331.90 Magn. to Map Corr. ' 25.000 SURVEY DATA Date ' 27-SEP _-00 27-SEP-00 27-SEP-00 27-SEP-O0 27-SEP-O0 27~SEP-O0 28-SEP-O0 28-SEP-O0 28-SEP-00 28-SEP-O0 28-SEP-O0 28-SEP-O0 28-SEP--O0 28-SEP-00 28-SEP-O0 28-SEP-O0 28-SEP-O0 28-SEP-O0 28-SEP-O0 28-SEP-00 29-SEP-00 29-SEP-O0 29-SEP-00 29-SEP-O0 Survey Depth 10246.72 10339.01 10431.00 10525.00 10617.00 10710.00 10803.00 10894.00 10986.00 11077.47 11170.67 11259.42 11356.51 11450.11 11542.27 11633.51 11726.00 11818.17 11910.10 12001.50 12095.97 MWD l 12278.63 . 'MWD 112369.00 91.81 i Hole Course Total Coordinate Build Rate Walk Rate Direction Length TVD N(+) /S(-) E(+) /W(-) Build (+) Right (+) (DD) (F'r) . (Fr) (F'r) (F~ Drop (-) Left (-) 330.47- 96;39 7083.21 330.61 92.29 7080.89 330.14 91.99 7078.11 329.96 94.00 7074.99 331.58 92.00 3'072.50 Vedical Section 5583.58 '5675.81 5767.73 5861.63 5953.57 332.25 93.00 7071.03 6046.56 332.15 93.00 7089.86 6139.55 331.90 91.00 7068.66 6230.54 331.93 92.00 7067.43 6322.54 332.01 ' 91.47 7066.17 6414.00 331.92 93.20 7084.76 · 6507.19 .331.93 88.75 7063.01 6595.92 331.91 97.09 7061.20 '6692.99 331.47 93.60 7080.17 6786.59 331.92 92.16 7059.56 6878.74 332.62 91.24 7059.18 332.26 92.49 7059:12 332.43 92.17 7058.46 331.82 91.93 7056.63 7054.39 . . '7052,01 7050.34 332.15 ~-~ 91.40 331.69 94.47 332.58 90.39 332.46 92.27 333.59 90.37 7O49.35 7047.46 3340.74 -5597.77 3421.07 -5643.15 3501.00 -5688.60 3582.41 -5735.50 3662.66 -5780.41 3744.70 -5624.18 3326.96 -5667.56 .3907.32 -5910.24 3988.47 -5953.55 4089.21 -5996.53 '4151.46 -6040.33 4229.75 -6082.09 4315.40 -6127.78 4397.80 -6172.17 4478.94 · -6215.86 6969.98 4559.70 '-6258.32 7062.46 4641.69 -6301.11 7154.63 4723.33' -6343.89 7246.54 4804.58 -6386.86 7337.91 4885~24 -6429.78 7432.35 4968.57 -6474.23 7522.72 5048.46 -6516.47 '7614.98 '5130.31. -6559.05 7705.31 5210.83 -6600.03 Depths Measured From: RKB ~ MSL[-I SS[:] Calculation Method MINIMUM CURVATURE 1 Map North to: OTHER i Comment _i 0.10 0,26 0.37 0.15 0.26 -0.51, 0.11 -0.19 -0.86 1.76 -0.~5 O.72 0.15 ' -0.11 -0.08 -0.27 0.11 0.03 -0.08 0.09 0.26 -0.10 0.32 0.01 -0.42 -0.02 -0,48 -0.47 -0.08 0.49 -0.22 0.77 -0.23 -0.39 1.04 0.18 0.55 -0.66 0.O1 0.36 0.06 -0.49 -0.91 0.98 -0.08 -0.13 1.36 1.25 SURVEY CALCULATION AND FIELD WORKSHEET Job No. Company PHILLIpS-ALASKA. INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Well Name & No. PAD CD#1/3OPH1 / 30 - Survey Section Name CD1-30 MWD WELL DATA Sidetrack No. 1 Page 3 Field ALPINE FIELD BHI Rep. MILCHAK / GEHRES of 3 Target 'I'VD Target DescriPtion Target Direction Target Coord. N/S Slot Coord. N/S -335.85 Grid Correction 0.000 Target Coord. E/W' Slot Coord. E/W 2461.76 Magn. Declination 25.000 (OD) Build,Walk\DE Per: lOOft[~ 30m~ .1OmD Vert. Sec..Azim. 331.90 Magn. to Map Corr. ' 25.000 SURVEY DATA Survey Hole Course Vertical Total Coordinate Date. Depth Direction Length ~I'VD Section N(+) / S(-) E(+) / W(-) (F/) (OD) (Fl) . (F~ (F~ 29-SEP-O0 12460.00 334.22 91.00 7044.86 7796.22 5292.52 -6640.04 29-SEP-O0 12553.00 334.40 93.00 7043.53 '7889.12 5376.32 -6680.35 29-SEP-O0 12644.00 334.29 91.00 7043.61 7980.04 5458.35 -6719.75 29-SEP-O0 12737.00 334.66 93.00 7044.41 8072.94 5542.27 -6759.82 29-SEPt. 12798.00 334.75 61.00 7045.36 8133.86 5597.41 -6785.88 29'SEP-O0 12850.00 33~t.75 52.00 7046.32 8185.79 5644.44 -6808.06 Depths Measured From: RKB ~] MSL[-] SSI- Build Rate Walk Rate Build (+) Right (+) Drop (-) Left (-) Calculation Method MINIMUM CURVATURE Map North to: OTHER -0.37 0.69 -1.40 0.19 -0.4s -o.12, -0.48 0.40 -0.56 O. 15 0.00 0.00 Comment Projected Data - NO SURVEY ANADRILL SCHLUMBERGER Survey report Client ................... : PHILLIPS Alaska, Inc. Field .................... : Colville River Well ..................... : CD1-30 API number ............... : 50-103-20348-00 Engineer ................. : Nutter Rig: ........................ : Doyon 19 State: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : 0.00 ft DF above permanent ....... : 55.80 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 331.90 degrees 29-Sep-2000 13:02:57 Page 1 of 6 ORI$1NAL Spud date ................ : 16-Sep-00 Last survey date ......... : 29-Sep-00 Total accepted surveys...: 129 MD of first survey ....... : 0.00 ft MD of last survey ........ : 12850.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 14-Sep-2000 Magnetic field strength..: 1147.16 HCNT Magnetic dec (+E/W-) ..... : 25.64 degrees Magnetic dip ............. : 80.54 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.16 HCNT Reference Dip ............ : 80.54 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.64 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.64 degrees (Total az corr= magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6 lB 48] ANADRILL SCHLUMBERGER Survey Report 29-Sep-2000 13:02:57 Page 2 of 6 Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 1 0.00 0,00 0,00 2 114.00 0,00 0,00 3 265,00 3,25 289.00 4 446.00 7,10 290,00 5 565,00 8.23 290.14 Course TVD Vertical Displ Displ length depth section +N/S- +E/W- (ft) (ft) (ft) (ft) (ft) 0,00 0,00 0,00 0,00 0.00 114,00 114,00 0.00 0,00 0.00 151,00 264.92 3.14 1.39 -4.05 181,00 445,15 15,23 6.89 -19,42 119.00 563.08 27.05 12,34 -34,32 Total At displ Azim (ft) (deg) 0.00 0,00 0.00 0,00 4.28 289,00 20,60 289,54 36,48 289.77 DLS Srvy Tool (deg/ tool qual 100f) type type 0,00 TIP - 0,00 Proj - 2,15 GYR - 2.13 GYR - 0,95 MWD 6-axis 6 655.00 8,66 292.62 90,00 7 743,00 8.96 295,17 88.00 8 832.00 10,25 294.91 89.00 9 924,00 11,44 302.05 92.00 10 1013.00 14,08 300,07 89.00 652.11 739.07 826.82 917,18 1003.97 37.10 17,16 -46,63 47.72 22,63 -58,94 59,60 28,91 -72,40 74.06 37,20 -87.56 90.91 47,31 -104,41 49.69 290,21 63,14 291,00 77,96 291,77 95,13 293,02 114.63 294.38 0,63 MWD 6-axis 0,56 MWD 6-axis 1,45 MWD 6-axis 1.95 MWD 6-axis 3,01 MWD 6-axis 11 1109.00 17.57 296.00 96.00 1096.32 12 1203,00 20.02 294,37 94,00 1185,30 13 1300.00 22,12 294,84 97,00 1275,81 14 1395,00 25.14 296.61 95,00 1362.84 15 1489.00 28,15 298.30 94.00 1446.85 112.58 59.52 -127.55 136,83 72,38 -154,96 164,58 86,90 -186,66 195.33- 103,46 -220,94 230.11. 122~92 -258,33 140.75 295,02 171.03 295,04 205,90 294,97 243,97 295,09 286,08 295,45 3,81 MWD 6-axis 2,67 MWD 6-axis 2,17 MWD 6-axis 3,27 MWD 6-axis 3,30 MWD 6-axis 16 1585.00 31,15 298.29 96.00 1530.27 17 1680,00 32.59 297.54 95,00 1610.95 18 1775,00 35,65 295.64 95.00 1689,59 19 1870.00 39,67 293,62 95,00 1764,78 20 1965.00 41.85 293.64 95,00 1836.73 21 2060,50 43,48 295,71 22 2155,96 44,49 297,25 23 2251,00 45.29 296,33 24 2346.00 45.18 297.21 25 2442,00 44.77 295.31 95.50 95,46 95,04 95.00 96.00 1906.96 1975,65 2042,98 2109,88 2177.79 269.66 145.43 -300,14 311,24 168.90 -344,46 354.70 192.72 -392,12 400,84 216.8.6 -444.88 449,54 241.72 -501.71 501,08 268.75 -560,50 555,10 298.32 -619,83 609,97 328,54 -679,71 665,13 358.92 -739,93 720,27 388.94 -800.77 333.52 295,85 383.65 296,12 436,92 296,17 494,92 295,99 556.90 295,72 621,60 295,62 687,88 295,70 754.95 295,80 822,39 295,88 890,23 295,91 3,13 MWD 6-axis 1.57 MWD 6-axis 3,41 MWD 6-axis 4,43 MWD 6-axis 2.29 MWD 6-axis 2,25 MWD 6-axis 1.54 MWD 6-axis 1,08 MWD 6-axis 0.67 MWD 6-axis 1,46 MWD 6-axis 26 2537,00 44.82 295,72 95,00 2245,21 27 2630.00 44.78 295,98 93,00 2311,20 28 2686,00 44,53 295,27 56,00 2351,03 29 2834,00 43,59 292,20 148,00 2457,40 30 2929.00 45.17 294,07 95,00 2525,30 [(c)2000 Anadrill IDEAL ID6 lB 48] 774,16 417,78 -861.18 827,14 446,35 -920,15 858,87 463.37 -955.64 939,78 504.81.-1049.82 991,59 530.92 -1110,91 957,16 295.88 1022.-69 295,88 1062,05 295.87 1164.88 295,68 1231,26 295.54 0.31 MWD 6-axis 0.20 MWD 6-axis 1,00 MWD 6-axis 1,58 MWD 6-axis 2,16 MWD 6-axis ANADRILL SCHLUMBERGER Survey Report 29-Sep-2000 13:02:57 Seq Measured Incl Azimuth Course TVD Vertical ~ depth angle angle length depth section - (ft) (deg) (deg) (ft) (ft) (ft) 31 3023.00 45.45 293.62 94.00 2591,41 1044.21 32 3120.00 45.35 293.83 97.00 2659.52 1098.51 33 3214.00 44.76 295.47 94.00 2725.92 1151.46 34 3308.62 44.96 296.68 94.62 2792.99 1205.58 35 3405.00 44.62 294.62 96.38 2861,40 1260.33 95.00 95.00 91.00 98.00 96.00 36 3500.00 44.23 294.21 37 3595.00 44.48 295.06 38 3686.00 43.89 292.30 39 3784.00 43.49 292.96 40 3880.00 44.05 295.51 95.00 96.00 96.00 96.00 93.00 2929.24 2997.17 3062.43 3133.29 3202.62 3271.12 3339.63 3407.28 3475.12 3541.06 41 3975.00 43.68 295.18 42 4071.00 45.25 296.45 43 4167.00 45.14 297.02 44 4263.00 44.93 296.61 45 4356.00 44.76 295.75 1313.10 1365.95 1415.78 1468.18 1520.75 1573.63 1627.97 1683.66 1739.24 1792.48 46 4452.00 44.78 296.23 96.00 3609.21 1847.24 47 4547.00 44.75 295.48 95.00 3676.66 1901.33 48 4640.00 44.71 295.12 93.00 3742.73 1953.88 49 4737.00 44.64 295.79 97.00 3811.71 2008.74 50 4832.00 44.26 295.25 95.00 3879.53 2062.30 Displ Displ +N/S- +E/W- (ft) (ft) 557.94 -1172.03 585.73 -1235.26 613.47 -1295-.72 642.81 -1355.67 672.20 -1416.87 51 4927.75 43.86 294.15 95.75 3948.34 2115.34 52 5022.00 43.68 294.36 94.25 4016.40 2166.96 53 5118.66 45.83 295.42 96,66 4085.03 2221.31 54 5207.99 46.09 295.28 89.33 4147.13 2272.89 55 5308.79 45.89 296.51 100.80 4217.17 2331.54 699.69 -1477.42 727.37 -1537.79 752.85 -1595.86 778.89 -1658.34 806.15 -1718.89 56 5498.97 45.20 295.42 190.18 4350.36 57 5689.00 44.56 294.21 190.03 4485.02 58 5879.15 44.07 292.82 190.15 4621.07 59 6069.93 44.83 295.45 190.78 4757.28 60 6260.46 44.69 296.23 190.53 4892.56 834.33 -1778.38 863.62 -1838.91 894.27 -1899.74 924.91 -1960.36 953.84 -2019.21 983.47 -2079.98 1012.64 -2140.18 1040.61 -2199.36 1069.93 -2260.93 1098.59 -2320.97 1126.41 -2381.46 1153.20 -2440.90 1181.85 -2502.63 1209.34 -2560.66 1241.00 -2625.88 2441.46 2548.42 2652.55 2758.16 2866.61 1300.44 -2747.92 1356.72 -2869.62 1409.73 -2991.41 1464.36 -3113.31 1522.83 -3234.05 Page 3 of 6 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 1298.05 295.46 0.45 MWD 6-axis 1367.09 295.37 0.19 MWD 6-axis 1433.61 295.34 1.39 MWD 6-axis 1500.35 295.37 0.93 MWD 6-axis 1568.24 295.38 1.55 MWD 6-axis 1634.73 295.34 0.51 MWD 6-axis 1701.14 295.31 0.68 MWD 6-axis 1764.53 295.26 2.21 MWD 6-axis 1832.15 295.16 0.62 MWD 6-axis 1898.54 295.13 1.93 MWD 6-axis 1964.37 295.13 0.46 MWD 6-axis 2031.61 295.16 1.88 MWD 6-axis 2099.69 295.21 0.44 MWD 6-axis 2167.59 295.26 0.37 MWD 6-axis 2233.16 295.29 0.68 MWD 6-axis 2300.77 295.31 0.35 MWD 6-axis 2367.66 295.32 0.56 MWD 6-axis 2433.11 295.32 0.28 MWD 6-axis 2501.31 295.32 0.49 MWD 6-axis 2567.84 295.33 0.56 MWD 6-axis 2634.42 295.31 0.90 MWD 6-axis 2699.61 295.29 0.25 MWD 6-axis 2767.65 295.28 2.35 MWD 6-axis 2831.87 295.28 0.31 MWD 6-axis 2904.36 295.30 0.90 MWD 6-axis 3040.10 295.33 0.55 MWD 6-axis 3174.18 295.30 0.56 MWD 6-axis 3306.95 295.23 0.57 MWD 6-axis 3440.50 295.19 1.04 MWD 6-axis 3574.65 295.21 0.30 MWD 6-axis [(c)2000 Anadrill IDEAL ID6 lB 48] ANADRILL SCHLUMBERGER Survey Report 29-Sep-20'00 .13:02:57 Page 4 of 6 Seq Measured Incl Azimuth Course TVD ~ depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 61 6449.71 44,33 296,16 189,25 5027,52 62 6641.11 43.59 294.86 191,40 5165,30 63 6736,38 44,10 297,14 95,27 5234,02 64 6925,39 43,86 297,46 189,01 5370,02 65 7116,86 43,91 297.00 191.47 5508.02 vertical section (ft) 2974.34 3081.30 3134.75 3242,79 3351.95 66 7307,32 43,64 297.07 190.46 5645.55 3460,06 67 7402,13 43.25 296.40 94.81 5714,38 3513.36 68 7592,91 43.57 295.40 190,78 5852.98 3619.42 69 7782,43 43,84 295.88 189,52 5989.98 3725,01. 70 7973.24 43,45 294,87 190.81 6128,06 3830.84- Displ Displ +N/S- +E/W- (ft) (ft) 1581,40 -3353,09 1638.63 -3472.99 1667.56 -3532,30 1727,75 -3648.93 1788,48 -3766.95 1848,38 -3884,32 1877,71 -3942.54 1934,97 -4060.48 1991,63 -4178,53 2048.07 -4297.51 Total At displ Azim (ft) (deg) 3707,30 295,25 3840,15 295,26 3906.13 295.27 4037.30 295,34 4169.96 295,40 4301.67 295.45 4366.85 295.47 4497.95 295.48 4628,90 295,48 4760.59 295.48 DLS Srvy Tool (deg/ tool qual 100f) type type __ 0.19 MWD 6-axis 0,61 MWD 6-axis 1.74 MWD 6-axis 0,17 MWD 6-axis 0.17 MWD 6-axis 0.14 MWD 0.64 MWD 0.40 MWD 0.23 MWD 0,42 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 71 8163.61 44,90 296.15 190',37 6264,59 72 8353,97 44,12 295.56 190.36 6400,34 73 8448.97 43,77 295,04 95.00 6468.75 74 8639,69 43,09 294.96 190.72 6607.25 75 8829,66 44,90 296,53 189,97 6743,91 3937,64 2105,22 -4417,22 4045,54--2163.42 -4537,31 4098,47 2191.59 -4596.91 4203,32 2247.01 -4715,74 4309,86. 2304.34 -4834,57 . 76 8965.01 44.24 295.76 135.35 6840.33 4386,95 77 8994,90 45,74 301.23 29.89 6861.48 4404,58 78 9027,68 47,58 304.36 32.78 6883.98 4425,41 79 9058,79 50,05 307.11 31.11 6904,47 4446,43 80 9089.74 52.25 308.85 30.95 6923,88 4468,46 81 9123,00 54,91 311,27 33.26 6943.63 4493.30 82 9153.75 57,16 313.32 30.75 6960.81 4517,32 83 9185.71 59,84 315,92 31,96 6977,51 4543,34 84 9218.24 62,64 317.65 32,53 6993.16 4570,87 85 9248,55 65.22 320,06 30.31 7006.48 4597,39 86 9279.49 68.08 321.85 30.94 7018,74 4625,27 87 9314,63 70,89 324.16 35.14 7031,06 4657,78 88 9344,14 73,10 325,20 29.51 7040,18 4685,62 89 9376,70 75,80 326,29 32,56 7048.91 4716.81 90 9410.56 78.42 327,15 33,86 7056,46 4749,68 2346.20 -4919.83 2356,28 -4938.39 '2369.20 -4958.41 2382.,88 -4977,41 .2397,72 -4996.40 4893,24 295,48 5026,69 295,49 5092,61 295,49 5223,72 295,48 5355,66 295,48 5450.63 295,50 5471,72 295,51 5495.36 295,54 5518,40 295,58 5541.94 295.64 2414,95 -5016.88 5567,85 295,70 2432.11 -5035,73 5592.30 295,78 '2451.25 -5055,12 5618,08 295,87 2472.04 -5074,64 5644,73 295.97 2492.54 -5092,54 5669,81 296,08 2514.60 -5110.43 5695.59 296.20 2540,89 -5130,23 5724,97 296,35 2563,78 -5146,45 5749,69 296,48 2589.71 -5164,10 5777,07 296,63 2617.,30 -5182,21 5805,65 296.80 0,89 MWD 0.46 MWD 0.53 MWD 0.36 MWD 1,11 MWD 0.63 MWD 13,87 MWD 8.93 MWD 10,36 MWD 8.35 MWD 9,91 MWD 9,17 MWD 10.88 MWD 9.79 MWD 11,11 MWD 10.66 MWD 10,09 MWD 8,20 MWD 8,90 MWD 8,12 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2000 Anadrill IDEAL ID6 lB 48] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 91 9442.32 80.57 327.86 31.76 92 9459.69 81.69 328.57 17.37 93 9584.90 85.71 330.28 125.21 94 9679.36 87.84 329.51 94.46 95 9773.46 88.36 330.43 94.10 96 9866.52 90.34 331.00 93.06 97 9960.79 90.41 330.88 94.27 98 10054.38 90.58 330.61 93.59 99 10150.33 91.17 330.22 95.95 100 10246.72 91.27 330.47 96.39 101 10339.01 91.61 330.61 92.29 102 10431.00 91.85 330.14 91.99 103 10525.00 91.95 329,96 94.00 104 10617.00 91.16 331.58 92.00 105 10710.00 90.65 332.25 93.00 106 10803.00 90.79 332.15 93.00 107 10894.00 90.72 331.90 91.00 108 10986.00 90.82 331.93 92.00 109 11077.47 90.75 332.01 91.47 110 11170.63 90.99 331.92 93.16 111 11259.42 91.27 331.93 88.79 112 11356.51 90.86 331.91 97.09 113 11450.11 90.41 331.47 93.60 114 11542.27 90.34 331.92 92.16 115 11633.51 90.14 332.62 91.24 116 11726.00 89.93 332.26 92.49 117 11818.17 90.89 332.43 92.17 118 11910.10 91.40 331.82 91.93 119 12001.50 91.41 332.15 91.40 120 12095.97 91.47 331.69 94.47 [ (c)2000 Anadrill IDEAL ID6_lB_48] TVD depth (ft) 7062.25 7064.93 7078.66 7083.98 7087.10 7088.15 7087.54 7086.73 7085.26 7083.21 7080.89 7078.11 7075.00 7072.50 7071.03 7069.86 7068.66 7067.43 7066.18 7064.76 7063.01 7061.21 7060.17 7059.56 7059.18 7059.13 7058.47 7056.63 7054.39 7052.01 29-Sep-2000' 13:02:57 Vertical section (ft) 4780.81 4797.94 4922.25 5016.49 5110.4g D~spl Displ +N/S- +E/W- ('ft) (ft) 2643.'64 -5198.99 2658.23 -5208.03 2765,35 -5271.31 2846.94 -5318.61 2928.36 -5365.68 5203.51 5297-.77 5391.34 5487.24 5583.58 5675.81 5767.73 5861.62 5953.57 6046.56' 6139.55 6230.54 6322.53 6413.99 6507.14 3009.52 -5411.19 3091.92 -5456.98 3173.57 -5502.72 3257.00 -5550.08 3340.74 -5597.76 Page 5 of 6 6595.92 6692.99 6786.58 6878.74 6969.98 Total At displ Azim (ft) (dog) 7062.46 7154.62 7246.53 7337.91 7432.35 5832.52 296.95 5847.20 297.04 5952.64 297.68 6032.64 298.16 6112.76 298.62 6191.79 299.08 6272.05 299.54 -6352.28 299.97 6435.17 300.41 6518.86 300.83 3421.07 -5643.14 6599.15 301.23 3501.00 -5688.59 6679.60 301,61 3582.41 -5735.49 6762.36 301.99 3-662.66 -5780.40 6843.11 302.36 3744.70 -5824.18 6924.15 302.74 . . 3826.96 -5867.55 7005.26 303.11 3907.32 -5910.23 7085.05 303.47 3988.47 -5953.54 7166.07 303.82 4069.21 -5996.52 7246.84 304.16 4151.43 -6040.30 7329.36 304.50 4229.75 -6082.08 4315.40 -6127.77 4397.80 -6172.16 4478.94 -6215.86 4559.70 -6258.31 DLS Srvy Tool (deg/ tool qual 100f) type type 7.12 MWD 6-axis 7.61 MWD 6-axis 3.49 IMP 6-axis 2.40 IMP 6-axis 1.12 IMP 6-axis 4641~69 -6301.10 4723.33 -6343.88 4804.58 -6386.85 4885.24 -6429.77 4968.57 -6474.23 2.21 IMP 6-axis 0.15 IMP 6-axis 0.34 IMP 6-axis 0.74 IMP 6-axis 0.28 IMP 6-axis 0.40 IMP 6-axis 0.57 IMP 6-axis 0.22 IMP 6-axis 1.96 IMP 6-axis 0.91 IMP 6-axis 0.18 IMP 6-axis 0.29 IMP 6-axis 0.11 IMP 6-axis 0.12 IMP 6-axis 0.28 IMP 6-axis 7408.27 304.82 7494.82 305.15 7578.67 305.47 7661.45 305.78 7743.21 306.08 0.32 IMP 6-axis 0.42 IMP 6-axis 0.67 IMP 6-axis 0.49 IMP 6-axis 0.80 IMP 6-axis 7826.19 306.38 7909.15 306.67 7992.24 306.95 8075.12 307.23 8161.02 307.50 0.45 IMP 6-axis 1.06 IMP 6-axis 0.86 IMP 6-axis 0.36 IMP 6-axis 0.49 IMP 6-axis ANADRILL SCHLUMBERGER Survey Report 29-Sepi2000 13:02:57 Page 6 of 6 Seq Measured Incl Azimuth Course TVD Vertical DisPl Displ Total At DLS Srvy Tool ~ depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) I00f) type type 121 12186.36 90.65 332.58 90.39 7050.34 7522.72 5048.46 -6516.47 8243.26 307.77 1.34 IMP 6-axis 122 12278.63 90.58 332.46 92.27 7049.35 7614.98 5130.32 -6559.04 8327.13 308.03 0.15 IMP 6-axis 123 12369.00 91.81 333.59 90.37 7047.47 7705.31 5210.83 -6600.02 8409.11 308.29 1.85 IMP 6-axis 124 12460.00 91.47 334.22 91.00 7044.86 7796.21 5292.52 -6640.03 8491.22 308.56 0.79 IMP 6-axis 125 12553.00 90.17 334.40 93.00 7043.53 7889.12 5376.32 -6680.34 8575.07 308,83 1.41 IMP 6-axis 126 12644.00 89.73 334.29 91.00 7043.61 7980.04 5458.35 -6719.74 8657.28 309.09 0.50 127 12737.00 89.28 334.66 93.00 7044.41 8072.94 5542.27 -6759.81 8741.39 309.35 0.63 128 12798.00 88.94 334.75 61.00 7045.36 8133.86 5597.41 -6785.87 8796.54 309.52 0.58 IMP 6-axis IMP 6-axis IMP 6-axis Survey Projected to total depth: 129 12850.00 88.94 334.75 52.00 7046.32 8185.79 5644.44 -6808.05 8843.60 309.66 0.00 Projection [(c)2000 Anadrill IDEAL ID6 lB 48] ANADRILL SCHLUMBERGER Survey report Client ................... : PHILLIPS Alaska, Inc. Field .................... : Colville River Well ..................... : CD1-30PH API number ............... : 50-103-20348-70 Engineer ................. : Galperin COUNTY: .................. : Doyon 19 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean. Sea Level Depth reference .......... : Driller's Tally GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 55.80 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 295.50 degrees 22-Sep-2000 05:11:31 Page ORIGINAL Spud date ................ : 16-Sep-00 Last survey date ......... : 22-Sep-00 Total accepted surveys...: 80 MD of first survey ....... : 0.00 ft MD of last survey ........ : 9505.00 ft 1 of 4 Geomagnetic data Magnetic model ........... : Magnetic date ............ : Magnetic field strength..: Magnetic dec (+E/W-) ..... : Magnetic dip ............. : BGGM version 2000 14-Sep-2000 1147.16 HCNT 25.64 degrees 80.54 degrees MWD survey Reference Reference G .............. : Reference H .............. : Reference Dip ............ : Tolerance of G ........... : Tolerance of H ........... : Tolerance of Dip ......... : (+/-) Criteria 1002.68 mGal 1147.16 HCNT 80.54 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT 0.45 degrees Corrections - Magnetic dec (+E/W-) ..... : 25.64 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.64 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6 lB 48] RECEIVED OCT O9 000 ~,nchorage ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course '% depth angle angle length - (ft) (deg) (deg) (ft) 1 0,00 0,00 0,00 0,00 2 114,00 0,00 0,00 114,00 3 265,00 3,25 289,00 151,00 4 446,00 7,10 290,00 181,00 5 565,00 8,23 290,14 -119,00 TVD depth (ft) 0,00 114,00 2 64,92 445,15 563,08 6 655,00 8,66 292,62 90,00 7 743,00 8,96 295,17 88,00 8 832,00 10,25 294,91 89,00 9 924-,00 11,44 302,05 92,00 10 1013,00 14,08 300,07 89,00 652,11 739,07 826,82 917,18 1003,97 11 1109,00 17,57 296,00 12 1203,00 20,02 294,37 13 1300,00 22,12-294,84 14 1395,00 25,14 296,61 15 1489,00 28,15 298.30 96.00 1096,32 94,00 ' 1185.30 97,00 '1275',81- 95,00 1362,84 94,00 1446.85 16 1585,00 31,15 298,29 17 1680,00 32,59 297,5.4 18 1775,00 35,65 295,64 19 1870,00 39,67 293,62 20 1965,00 41,85 293,64 96,00 1530,27 95,00 1610,95 95,00 1689,59 95,00 1764,78 95,00 1836,73 21 2060,50 43,48 295,71 22 2155,96 44,49 297,25 23 2251,00 45,29 296,33 24 2346,00 45,18 297,21 25 2442,00 44,77 295,31 95,50. 1906,96 95,46 1975,65 95,04 2042,98 95,00 2109,88 96,00 2177,79 26 2537.00 44.82 295,72 95,00 2245,21 27 2630,00 44,78 295,98 93,00 2311,20 28 2686,00 44,53 295.27 56,00 2351,03 29 2834,00 43,59 292,20 148.00 2457,40 30 2929,00 45,17 294,07 95,00 2525,30 [(c)2000 Anadrill IDEAL ID6 lB 48] 22-Sep-2000 05:11:31 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 0,00 0.00 0,00 0,00 0,00 0,00 4,25 1.39 -4,05 20,49 6.89 -19,42 36,29 12,34 -34,32 49,47 17,16 -46,63 62,94 22,63 -58.94 77,79 28,91 -72,40 95,04 37,20 -87.56 114,61 47,31 -104.41 140.74 59,52 -127,55 171,02 72.,38 -154,96 205,89 86,90 -186.66 243,96 103,46 -220,94 286,08 122,92 -258,33 333,51 145.43 -300,14 383,62 168,90 -344,46 436,8.9 192,72 -392,12 494,91 216,86 -444,88 556,89 241,72 -501,71 621,60 268.75 -560,50 687,88 298,32 -619,83 754,93 328,54 -679,71 822,37 358,92 -739,93 890,21 388,94 -800.77 957,14 417,78 -861,18 1022,.67 446,35 -920,15 1062,03 463,37 -955,64 1164,88 504,81 -1049,82 1231.26 530.92 -1110,91 Page 2 of 4 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 0,00 0,00 0.00 TIP - 0o00 0,00 0,00 MWD - 4,28 289,00 2,15 GYR - 20,60 289,54 2,13 GYR - 36,48 289,77 0,95 MWD 6-axis 49.69 290,21 0,63 MWD 6-axis 63,14 291,00 0.56 MWD 6-axis 77,96 291,77 1,45 MWD 6-axis 95,13 293,02 1,95 MWD 6-axis 114,63 294,38 3,01 MWD 6-axis 140,75 295,02 3,81 MWD 6-axis 171,03 295,04 2,67 MWD 6-axis 205,90 294,97 2,17 MWD 6-axis 243,97 295,09 3,27 MWD 6-axis 286,08 295,45 3,30 MWD 6-axis 333,52 295,85 3,13 MWD 6-axis 383,65 296,12 1,57 MWD 6-axis 436,92 296,17 3,41 MWD 6-axis 494,92 295,99 4,43 MWD 6-axis 556,90 295,72 2,29 MWD 6-axis 621,60 295,62 2,25 MWD 6-axis 687,88 295,70 1,54 MWD 6-axis 754,95 295,80 1,08 MWD 6-axis 822,39 295,88 0,67 MWD 6-axis 890,23 295,91 1,46 MWD 6-axis 957,16 295,88 0,31 MWD 6-axis 1022,69 295,88 0,20 MWD 6-axis 1062,05 295,87 1,00 MWD 6-axis 1164,88 295,68 1,58 MWD 6-axis 1231.26 295,54 2,16 MWD 6-axis RECEiVeD OCT 09 ANADRILL SCHLUMBERGER Survey Report 22-Sep-2000 05:11:31 Page 3 of 4 Seq Measured Incl Azimuth ~ depth angle angle - (ft) (deg) (deg) 31 3023,00 45,45 293,62 32 3120,00 45,35 293,83 33 3214,00 44,76 295,47 34 3308,62 44,96 296,68 35 3405,00 44,62 294.62 Course length (ft) 94,00 97,00 94,00 94,62 96,38 TVD depth (ft) 2591.41 2659.52 2725,92 2792,99 2861,40 Vertical section (ft) 1298,05 1367,09 1433,61 1500,34 1568,24 36 3500,00 44,23 294,21 95,00 2929,24 1634,72 37 3595,00 44,48 295,06 95,00 2997,17 1701,13 38 3686,00 43,89 292,30 91,00 3062,43 1764,51 39 3784,00 43,49 292,96 98,00 3133,29 1832,12 40 3880.00 44,05 295,51 96.00 3202,62 1898,50 95,00 96,00 96,00 96,00 93,00 96,00 95,00 93,00 97,00 95.00 41 3975,00 43,68 295,18 42 4071,00 45,25 296,45 43 4167.00 45.14 297,02 44 4263,00 44,93 296,61 45 4356,00 44,76 295.75 3271,12 3339,63 3407.28 3475,12 3541,06 3609,21 3676,66 3742,73 3811,71 3879,53 46 4452,00 44,78 296,23 47 4547,00 44,75 295,48 48 4640,00 44,71 295,12 49 4737,00 44,64 295,79 50 4832,00 44,26 295,25 1964,33 2031,57 .2099,67 2167,57 2233,15 2300,75 2367,65 2433,10 2501,30 2567,83 51 4927,75 43,86 294,15 95,75 3948,34 2634.40 52 5022,00 43,68 294,36 94,25 4016,40 2699,59 53 5118,66 45,83 295,42 96,66 4085.03 2767,63 54 5207,99 46,09 295,28 89,33 4147,13 2831,85 55 5308,79 45,89 296,51 100,80 4217,17 2904,34 56 5498,97 45,20 295,42 190,18 4350,36 3040,08 57 5689,00 44.56 294,21 190,03 4485,02 3174,16 58 5879,15 44,07 292,82 190,15 4621,07 3306,91 59 6069,93 44,83 295.45 190,78 4757,28 3440,45 60 6260,46 44,69 296,23 190,53 4892,56 3574,60 [(c)2000 Anadrill IDEAL ID6 lB 48] Displ Displ Total +N/S- +E/W- displ (ft) (ft) (ft) 557,94 -1172,03 585,73 -1235,26 613,47 -1295,72 642,81 -1355,67 672,20 -1416,87 699,69 -1477,42 727.37 -1537,79 752,85 -1595,86 778,89 -1658,34 806,15 -1718,89 834,33 -1778,38 863,62 -1838,91 894,27 -1899.74 924,91 -1960,36 953,84 -2019,21 983,47 -2079,98 1012,64 -2140,18 1040.61 -2199,36 1069,93 -2260,93 1098.59 -2320,97 1126,41 -2381,46 1153,20 -2440,90 1181,85 -2502,63 1209,34 -2560,66 1241,00 -2625,88 1300,44 -2747,92 1356,72 -2869,62 i409,73 -2991,41 1464,36 -3113,31 1522,83 -3234,05 At DLS Srvy Tool Azim (deg/ tool qual (deg) 100f) type type 1298,05 1367,09 1433,61 1500,35 1568,24 295,46 0.45 MWD 295,37 0,19 MWD 295,34 1,39 MWD 295,37 0,93 MWD 295,38 1,55 MWD 1634,73 1701,14 1764,53 1832,15 1898.54 295,34 0.51 MWD 295,31 0,68 MWD 295,26 2,21 MWD 295,16 0,62 MWD 295,13 1,93 MWD 1964.37 2031.61 2099.69 2167,59 2233,16 295,13 0.46 MWD 295,16 1,88 MWD 295.21 0,44 MWD 295,26 0.37 MWD 295,29 0,68 MWD 2300,77 2367,66 2433,11 2501,31 2567,84 295,31 0,35 MWD 295,32 0.56 MWD 295,32 0,28 MWD 295,32 0,49 MWD 295,33 0,56 MWD 2634,42 2699,61 2767,65 2831,87 2904,36 295,31 0,90 MWD 295,29 0,25 MWD 295,28 2,35 MWD 295,28 0,31 MWD 295,30 0,90 MWD 3040,10 3174,18 3306,95 3440,50 3574,65 295,33 0,55 MWD 295,30 0,56 MWD 295,23 0.57 MWD 295,19 1,04 MWD 295.21 0,30 MWD RECEIVED 0 C T f,9 : 000 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 61 6449.71 44.33 296.16 189.25 62 6641.11 43.59 294.86 191.40 63 6736.38 44.10 297.14 95.27 64 6925.39 43.86 297.46 189.01 65 7116.86 43.91 297.00 191.47 66 7307.32 43.64 297.07 190.46 67 7402.13 43.25 296.40 94.81 68 7592.91 43.57 295.40 190.78 69 7782.43 43.84 295.88 189.52 70 7973.24 43.45 294.87 190.81 71 8163.61 44.90 296.15 190.37 72 8353.97- 44.12 295.56 190.36 73- 8448.97 43.77 295.04 95.00 74 8639.69 43.09 294.96 190.72 75 8829.66 44.90 296.53 189.97 76 8965.01 44.24 295.76 135.35 77 9211.37 44.2.3 296.06 246.36 78 9400.44 '45.27- 296.22 189.07 79 9430.64 45.09 295.40 30.20 Final Surve~ projeoted to TD: 80 9505.00 45.09 295.40 74.36 TVD depth (ft) 5027.52 5165.30 5234.02 5370.02 5508.02 5645.55 5714.38 5852.98 5989.98 6128.06 6264.59 6400.34 ~64-68.75 6607.25 6743.9-1 6840.33 7016.85 7151.12 7172.41 7224.91 22-Sep-2000 05:11:31 Vertical section (ft) 3707.26 3840.12 3906.10 4037.29 4169.95 Displ Displ +N/S- +E/W- (ft) (ft) 1581.40 -3353.09 1638.63 -3472.99 1667.56 -3532.30 1727.75 -3648.93 1788.48 -3766.95 4301.67 4366.85 4497.95 4628.90 4760.59 1848.38 -3884.32 1877.71 -3942.54 1934.97 -4060.48 1991.63 -4178.53 2048.07 -4297.51 4893.24 5026.69 5092.61 5223.72 5355.66 2105.22 -4417.22 2163.42. -4537.31 2191.59 -4596.91 2247.01 -4715.74 2304.34 -4834.57 5450.63 5622.49 57'55.59 5777.01 2346.20 -4919.83 2421.30 -5074.42 2479.94 -5193.91 2489.27 -5213.20 5829.67 2511.85 -5260.77 Page 4 of 4 Total At DLS Srvy displ Azim (deg/ tool (ft) (deg) 100f) type 3707.30 295.25 0.19 MWD 3840.15 295.26 0.61 MWD 3906.13 295.27 1.74 MWD 4037.30 295.34 0.17 MWD 4169.96 295.40 0.17 MWD 4301.67 295.45 0.14 4366.85 295.47 0.64 4497.95 295.48 0.40 4628.90 295.48 0.23 4760.59 295.48 0.42 4893.24 295.48 0.89 5026.69 295.49 0.46 5092.61 295.49 0.53 5223.72 295.48 0.36 5355.66 295.48 1.11 5450.63 295.50 0.63 5622.49 295.51 0.09 5755.59 295.52 0.55 5777.01 295.52 2.02 5829.67 295.52 0.00 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2000 Anadrill IDEAL ID6 lB 48] RECEIVED OCT Ancflor'alle MWD/LWD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD1-30 .;~ OD · ! "~ ~.. Date Dispatche 3-Oct-00 Installation/Rig Doyon 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 r :.,..,.,. '~'"~'"" !'"' ? i ',. Received By: ~ Please sign and return to: Anadrill LWD Division 3940 Arctic Bird, Suite 300 Anchorage, Alaska SSS03 NRosel @ anchorage.oilfield.slb.com Fax: g07-561-8417 LWD Log Delivery V1.1, Dec '97 · , (" MWD/LWD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD1-30PH ~.OC) · ["~ Date Dispatche 1-Oct-00 Installation/Rig Do¥on 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 RECEIVED. OCT ?000 Al', tnk;n 0it & ~ C~ ~n~'. Commi~i~ Ancho:~aOe Received By: (~~ Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 N Rose1 @ anchorage.oilfield.slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ALASKA OIL A~D GA~ CO~ERVATIO~ CO~IS~IOI~ Chip Alvord Drilling Team Leader Phillips Alasl~a, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501 ~3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Colville River Unit CD1-30 Permit No: 200-132 Sur Loc: 430'FNL, 2370'FWL, Sec. 5, T1 IN, R5E, UM Btmhole Loc. 114'FSL, 331'FWL, Sec. 30, TI2N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt yOU from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10- 403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down' the surface/production easing annulus of a well approved for annular disposal on Drill Site CD 1 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular, space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test 'ofBOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the Noah Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION · DATED this .~ ~ day of August, 2000 dlffEnclosures Department of Fish & Game, Habitat Section w/o'encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill J lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen! Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. DF 56' feet Colville River Field 3. Address 6. Property Designation ~.~S"~,~ ~ Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25558 .,,~u~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25,025) 430' FNL, 2370' FWL, Sec.5, T11 N, RbE, UM Colville River Unit Statewide At target (=7' casing point ) 8. Well number Number 2306' FSL, 1979' FWL, Sec. 31, T12N, RbE, UM CD1-30 #U-630610 At total depth 9. Approximate spud date Amount 114' FSL, 331' FWL, Sec. 30, T12N, RbE, UM 09/16/2000 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD) Property line Alpine CD1- 32 13068 MD Crosses T11N to feet 19.2' @ 425' Feet 2560 7043 TVD feet T12N ..~1 '~,-,,~.2-5's?,,~ 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 91.41° Maximum sudace 2495 psig At total depth (TVD) 3215 at psig 7000' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Len~h MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pm-installed 12.25" 9.825" 36# J-55 BTC 2743' 37' 37' 2780' 2400' 528 Sx Amticset III L & 231 Sx Class G 8.5" 7" 26# L-80 BTC-M 9530' 37' 37' 9567' 7081' 126 sx Class G N/A 4.5" 12.6# L-80 IBT-M 9163' 37' 37' 9200' 6981' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Siz~,,~ ~a.. ,~ __ ,, ~. ~,ertte~ ~d Measured depth True Vertical depth Structural Conductor Surface Litner~rurmc~ic~te AUG ooo 0 RIG.1NAL Perforation depth: measured .~askp~ 0[{ & GJ~$ CONS. Commissior~ true vertical Anchorage 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge -- Signed /~' ~,._ ,~:'- ~,~o,~ Title Drilling Team Leader Date ~)~Z.~5"( ~,:~ -"' Commission Use Only Permit Number I APl number - IApprove'date 13D I00Iseec°ver'etterf°r Other requirements Conditions of approval Samples required Yes ~ MudToglrequiredf Yes Hydrogen sulfide measures Yes ~ Directional survey required ~ No Required working pressure for BOPE 2M 3M 5M 10M 15M byorder of .A_l:)p_r_o ~v.ed. b.y~ ...... Commissioner the commission Date Form 10-401 Rev. 7-24-89 ORIGINAL SIGNED BY O Taylor Seamount triplicate Alpine: CD1-30PH (Pilot Hole) & CD1-30 Procedure , . 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Install diverter. Move on Doyon 19. Function test diverter. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8 V2" hole to a point +/- 100' TVD below the base of the Alpine Sand. Set 500 ft cement plug #1 from TD to +/- 8980'. Set 500 ft cement plug #2 from +/- 8980' to +/- 8480'. RIH with drilling assembly. Dress off plug #2. Kick off at +/- 8965' and drill sidetrack to intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement + 500 feet MD above Alpine reservoir. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. BOPE test to 3500 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Drill 6 1/8" horizontal section to well TD. Contingency- set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. Run 4 ~, 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Shear out valve in lowermost gas lift mandrel. Circulate tubing to diesel and install freeze protection in the annulus. Set BPV and secure well. Move rig off. AUG 2.:'f,; Oi~ & G~s Co~s. Co;~mission .A~.chorage Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-32 will be the closest well to CD1-30 (19.2' at 425' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 16.9' at 450' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD1-30 will be injected into the annulus of another permitted well on the CD1 pad.. The CD1-30 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD1-30 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set below the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi CD1-30 & CD1-30 PH DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 ½" Section - 6 1/8" point- 12 ~" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at _+ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with _+ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and DuaI-FIo starch will be used for viscosity and fluid loss control respectively. RKB - GL = 37' , Colville River Field CD1-3OPH Pilot Hole - Prior to Sidetracking Updated 08/24/00 Wellhead 16" Conductor to 114' 9.8 ppg drilling mud in hole I Cement Plug 9-5/8" 36 ppf J-55 BTC Surface Casing 2780 ' MD / 2400' TVD cemented to surface Plu_. #2: 500'. 17 pp~ to cover the HRZ when In place (top at +1- 8480') Top of cement plug dressed off to 8965' MD / 6836' TVD (+/- 44,2 deg inc.) Top Alpine Reservoir at 9250' MD / 7041' TVD Pilot Hole TD at 9480' MD / 7206' TVD (+/- 44.2 deg inc.) Top of Cement Plug #1 at +/- 8980' 500 ft RECEIVED Colville River Field CD1-30 Production Well Completion Plan ii' 16" Conductor to 114' Updated 8/24/00 ~.' '..,..~ ~., .,;~:, .,.,,~..-. ~,~ ~'~:-~.;, ..~. ~ ] 4-112" Camco BAL-O SSSV Nipple (3.812" ID) at 1700',TVD : ~ - Isolation,,Sleeve ~ith DB-6 No-Go Lock (3.812 OD) run in profile :~ - Dual 1/4 x 0.049 s/s control lines :;';~ 9-5/8" 36 ppf J-55 BTC ~ Surface Casing ~ 2780' MD / 2400' TVD WRDP-2 SSSV (2.125"1D) w/DB-6 cemented to surface No-Go Lock (3.812" OB) - to be installed later Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1' BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Packer Fluid mix: 9.6 .~.~g KCl Brine with 2000' TVD diesel cap Tubing Supended with diesel to lowest GLM Completion MD Tubing Hanger 32' Camco KBG-2 GLM (3.909' ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing at 5200' TVD for Camco BAL-O SSSV Nipple 1808' E Dummy with 1" BK-2 Latch 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4174' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 6684' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 9023' 4-1/2" tubing joints (2) ~ ~ HES "X" (3.813" ID) 9092' _~ 4-1/2" tubing joint (1) ~ \ \ \ . Baker S3 Packer 9124' \ \ \ \ Camco KBG-2 GLM (3.909 ID) 4 1/2" tubino Joint (21 , ' - ....... ~ ,~ ..... \ \ \ \ &l Camco DCK-2 Shear Valve HES"XN .... (3 725 ID) 9189' Pinned for casing side shear e +/- 2000 psi ,, , ' . . . ~~~(~ 41/2 10 pupjo,m(+/.60deg) ints above the X landing nipple ~EG 9200' ~ll~r,h.,_ Baker S3 Packer at +/-9124' II TOC @ +/- 8800' MD (500' MD above top Alpine) ~ ~ ~~{,,.~( ~ Top Alpine at 9343' MD / 7040' TVD TVD 32' 1700' 3400' 5200' 6877' 6921' 6940' 6975' 6981' Well TD at 13068' MD I 7043' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 9567' MD / 7081' TVD @ 88 deg i. .. Colville River Field CD1-30 Production Well Completion Plan Formation Isolation Contingency Options Updated 08~24~00 16" Conductor to 114' 4-1/2" Camco B^L-O SSSV Nipple (3.812" ID), WRDP-2 SSSV (2.25" ID) and DB-6 No-Go Lock (3.812" OD) with dual 1/4" x 0.049" sis control line @ 1700' TVD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2780' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1' BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909' ID) at 5200' TVD for E Dummy with 1' BK-2 Latch (A} Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) O_~en Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide (C) Open Hole Brid§e Plu§ Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe Camco KBG-2 GLM (3.909' ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ 2000 psi set 2 joints above the X landing nipple TOC @ +/- 8800' MD (500' MD above top Alpine) Baker S3 Packer set at +1- 9124' ........ ..... Well TD at 13068' MD I 7043' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 9567' MD / 7081' TVD @ 88deg CD1-30 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well' Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 2780 / 2400 14.5 1086 1532 7" 9567 / 7081 16.0 3203 2495 N/A 13068 / 7043 16.0 3186 N/A · NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib./gal 0.052 = Conversion from lb./gal to psi/Tt 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP-(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point . ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1} D = [(10.9 x 0.052) -0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1271 - (0.1 x 2810') = 990 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052)-0.1} D = [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR ASP = FPP - (0.1 x D) = 3203 - (0.1 x 7081 ') = 2495 psi . Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3203 - (0.1 x 7081') = 2495 psi Alpine CD1-30 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 500 -500 -1500 -2500 c~ -3500 -4500 -5500 -6500 -7500 10 11 12 13 14 EQUIVALENT MUD WEIGHT 15 16 17 Alpine, CD1-30PH & CD1-30 Well Cementing Requirements 9 5/8" Surface Casing run to 3400 MD 12810' TVD. Cement from 2780' MD to 1627' with Class G + Adds @ 15.8 PPG, and from 1627' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2280'-1627') X 0.3132 ft3/ft X 1.5 (50% excess) = 306.7 ft3 below permafrost 1627' X 0.3132 ft3/ft X 4 (300% excess) ~ 2038.3 fts above permafrost Total volume = 306.7 + 2038.3 = 2345 ft => 528 Sx @ 4.44 ft3/sk System: Tail slurry: 528 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft~/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant 500' X 0.3132 fta/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 81' X 0.4341 ft~/ft = 35.2 ft~ shoe joint volume Total volume = 234.9 + 35.2 = 270 fta => 231 Sx @ 1.17 ft~/sk System: 231 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 9567' MD / 7081' TVD Cement from 9567' MD to +/- 8843' MD (500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (9567' - 8843')oX 0.1268 ft~/ft X 1.4 (40% excess) = 128.5 fts annular volume 81' X 0.2148 ft°/ft = 17.4 ft~ shoe joint volume Total volume = 128.5 + 17.4 = 145.9 ft~ => 126 Sx @ 1.16 ft3/sk System: 126 Sx Class G + 0.2% D046 antifoamer, 0.27% D065 dispersant, 0.20% D800 retarder, 0.20% D046 anti-foam and 0.25% D156 fluid loss additive @ 15.8 PPG yielding 1.16 fts/sk CD1-30PH Cement Plug #1: 9480' MD to 8980' MD = 500'. Cement with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. Slurry: 500' X 0.3941 ft~/ft X 1.15 (15% excess) = 226.6 fts => 196 Sx @ 1.16 ftS/sk CD1-30PH Cement Plug #2: 8980' MD to 8480' MD = 500'. Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. Slurry: 500' X 0.3941 ft~/ft X 1.15 (15% excess) = 226.6 ft3 => 226.6 sx @ 1.00 ftS/sk 1 By Weight Of mix Water, all other additives are BWOCement <- NorTh (re('". 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 I I I I I Phillips Alaska, Inc. Structure: CD#I Well: 50 Field: Alpine Field Location: North Slope, Alaska <- West (feet) Interm Pt/Beg Drp TD - Csg Pt I TD LOCATION: I 114' FSL, 331' FWL SEC. 50, T12N. R5E 331.90 AZIMUTH 8190' (TO TD) ***Plane of Proposal*** TARGET LOCATION: 2506' FSI_, 1979' F'WL SEC. 51, T12N, R5E Target - Csg Pt D Miluveach A Base Alpine LCU - Sidetrack Pt 60aa 560O 5600 54OO 5200 5000 41100 46O0 4400 A I z 4200 0 4000 ~-~ 5~00 ~.~ 5600 54OO 5200 5000 2800 2600 2400 2200 2075' FSL, 2012' FWL SEC. 51, T12N, RSE PILOT HOLE TD LOCATION: EOC 7400 7200 7000 6800 6600 6400 6200 5000 5800 5600 5400 5200 5000 4800 4600 4400 4200 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 I I I I I c~ ~ ~ For: S Reynolds] ! Cc~'d"mM' ~'~ rn ~'Mt retem'v~ ~da~ Ir30- 0 ~ RKB El~atlon: 56' KOP 400 800 Build 3/100 Wes[ Sek 1200 Permafrost 1600 EOC 2000 C-40 C-30 TANGENT ANGLE ~4.17 D~G 2400 2800 5200 5600 4000 44O0 ~oo 52OO 5600 6O00 640O 6800 7200 7600 Phillips Alaska, Inc. Sfruciure: CD#I Well: :~0 Field : Alpine Field Looofion : North Slope, Alaska 295.55 AZIMUTH 5809' (TO PH rD) ***Plane of Proposal*** 9 5/8 Casing Pt: C-20 1<-5 K-2 Albion 97 Albion 96 HRZ K Miluve( Alpl Base i i i i i i i i i i i i i i i i [ i i ii i i i i I i l 400 0 400 800 1200 1600 2000 2&O0 2800 5200 5600 4000 4400 4800 Verficol Section (feet) -> Azimuth 551.90 with reference 180~99 N, 102.51 W from slot #50 Creoted by bmlchoe; ~'or; Ig Re~olde I Dote plotted: 24-~g-~ Plot ~le~ce ri CD1 ~or~t~ ore ;n f~ ~er~ce Vert~l ~t~ ore refe~ Phillips Alaska, Inc. Structure: CO#I Field: Alpine Field Well: 30 Looofion: North Slope, Alosko 331.90 AZIMUTH a~O' (~0 T~) ***Plane o~ Proposal*** 6400 6600~ ~oo 7000 7200 7400 ~.~ TARGET ANGLE TANGENT ANGLE 88 DEG 91.41 DEG e · FINAL ANGLE 90.18 DEG Vertical Section (feet) -> i i i i 8000 6200 8400 Azimufh ;5.~1.90 wifh reference 180.99 N, 102.51 W from slof #50 Created by bmichoel For: H Reynolds Oote plottod: 24--Aug-2000 Plot RofererIg8 Is CD1--30 PHI Ccwrdrnates ore In feet re~'efam:e slat rrue Vertical Dlpth2&enco__ RKB (Do,yon Phillips Alaska, Inc. Struature: CDj~! Field: Alpine Field Well: :50PH1 Looafion: North Slopo, Alaska Point KOP Build 5/1 O0 West Sak Permafrost EOC C-40 'C-50 9 5/8 Casing Pt C-20 K-5 K-2 Albian 97 Albian 96 HRZ K-1 LCU Miluveach A Alpine D Alp;ne ~Base Alpine TD PROFILE COMMENT DATA MD 500.00 800.00 1056.1 6 1626.90 1958.95 2474.91 2774.65 2780.22 5285.50 4751.51 5061.01 7458.90 8086.25 8574.20 8968.7`3 9101.17 9187.61 9225.86 9250.`34 95.35.99 9480.57 Inc Dir TVD North 0.00 0.00 500.00 0.00 10.00 295.55 797.47 18.77 17.68 295.55 1046.00 45.18 34.81 295.55 1556.00 153.62 44.17 295.55 1796.56 2.39.10 44.17 295.55 2181.00 400.14 44.17 295.55 2596.00 490.21 44.17 295.55 2400.00 491.88 44.17 295.55 2761.00 64.3.11 44.17 295.55 5814.00 1084.22 44.17 295.55 4056.00 1177.21 44.17 295.55 5756.00 1897.7`3 44.17 295.55 6206.00 2086.24 44.17 295.55 6556.00 22`32.86 44.17 295.55 6859.00 2351.41 44.17 295.55 6954.00 2391.20 44.17 295.55 6996.00 2417.18 44.17 295.55 7022.00 2428.07 44.17 295.55 7041.00 24.36.0.3 44.17 295.55 7101.00 2461.1 6 44.17 295.55 7206.00 2505.15 East 0.00 -59.27 -94.52 -`321.59 -500.25 -837.16 -1025.59 - 1029.09 - 1,345.48 -2268.54 -2462.90 -5970.52 -4564.71 -4671.45 - 4919.48 -5002.74 -5057.07 -5079.86 -5096.51 -5149.10 -5241.12 V. Sect 0.00 45.52 104.76 556.22 554.44 927.87 1156.72 1140.60 1491.27 2514.15 2729.78 4400.55 4857.67 5177.66 5452.56 5544.84 5605.06 5650.32 5648.78 5707.06 5809.05 Deg/lO0 0.00 2.00 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Creotod by bml-hae~ For: Date plotted: 24-Aug-2000 C~dbot. ore rn feet ~emn. ~ J~. I Phillips Alaska, Inc. S~ruature: CD#I Field: Alpine Field Well: 30 Looation: North Slope, Alaska Point KOP - Sidetrack Pt K-1 LCU Miluveach A Alpine D Alpine Target - Csg Pt EOC Interm Pt/Beg Drp EOC TD - Csg Pt PROFILE MD Inc. 8964.65 44.17 8968,80 44.43 9114.17 54.04 9232.09 62.52 9295.14 67,06 9343.25 70.84 9566.68 88.00 9908.20 91.41 11256.74 91,41 1136O.70 90.18 13067.48 90.18 COMMENT DATA Dir TVD North East V. Sect Deg/1 O0 295,55 6856,05 2350.22 -4916,95 295.94 6839.00 2351.48 -4919.56 307,70 6934,00 2409.97 -5012.27 315.22 6996.00 2476.47 -5087.10 318.64 7022,00 251 6,82 -5124,78 321,29 7040.00 2552.63 -5154,84 332.00 7081,00 2735.42 -5274.49 331.99 7082.76 3036,91 -5434.82 351.99 7050,00 4209,52 -6058,45 331.90 7048.28 4318.91 -6116.74 331.90 7043.00 5824.45 -6920.73 4181.19 0.00 4183,53 9,00 4278,79 9.00 4372.71 9.00 4426,05 9,O0 4471.80 9,00 4689,40 9,00 5030.86 1.00 6358.99 0.00 6482.94 1,00 8189,71 0,00 Base Alpine 13067.50 90.18 331.90 7043.00 5824.47 -6920.74 8189.73 0.00 Phillips Alaska, Inc. C~1 30PH1 slot #30 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref: CD1-30 PH1 Versior~ Our ref : prop3016 License : Date printed: 23-Aug-2000 Date created: 27-Jun-1998 Last revised : 23-Aug-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on nTO 20 37.100,w150 56 46.041 Slot location is n70 20 32.877,w150 55 36.772 Slot Grid coordinates are N 5975700.122, E 385794.756 Slot local coordinates are 429.01S 2371.14 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-9236'>,,22,CD~1 PMSS <0-11492'>,,27,CD~1 PMSS <562 - 12134'>,,37,CD~1 PMSS <O-9357'>,,16PH1,CD~l PMSS <8393 - 12600'>,,16,CD~1 PMSS <9499 - 14515'>,,5,CD~1 PMSS <O-10504'>,,5PH1,CD~l PMSS <O-10224'>,,39PH1,CD~l PMSS <9146 - 13289'>,,39,CD~1 PMSS <472 - 1545'>,,36PH1,CD~l PMSS <763 - 7440'>,,36PH2,CD~l PMSS <6600 - 10654'>,,36,CD~1 PMSS <832 - 12147'>,,25,CD~1 PMSS <384 - 14477'>,,23,CD~1 PMSS <0-11300'>,,13,CD~1 PMSS <9081 - 12811'>,,44,CD~1 PMSS <297 - 9882'>,,44PH1,CD~l PMSS <476 - 11190'>,,34,CD~1 PMSS <0-10897'>,,3,CD~1 PMSS <0-10548'>,,19,CD~1 PMSS <2827 - 11956'>,,19A,CD~l PMSS <O-8350'>,,26PH1,CD~l PMSS <7755-11134'>,,26,CD~1 PGMS <O-10255'>,,WD2,CD~l PMSS <O-7331'>,,1PH1,CD~1 PMSS <5946 - 10289'>,,1,CD~1 PMSS <O-8844'>,,45PH1,CD~l Closest approach with 3-D Last revised Distance 11-Jul-2000 16-Mar-2000 26-Aug-1999 4-Jan-2000 25-0ct-1999 23-~an-2000 23-Jan-2000 4-Jan-2000 22-Sep-1999 4-Jan-2000 4-Jan-2000 22-Dec-1999 15-Mar-2000 3-May-2000 15-~u1-1999 23-May-2000 23-May-2000 11-May-2000 4-Jan-2000 6-Apr-2000 30-Apr-2000 6-Mar-2000 1-Nov-1999 28-Jun-1999 29-Feb-2000 27-~un-1999 4-Oan-2000 79.4 26 3 70 0 140 1 140 1 248 9 248 9 88 7 88 7 60 1 60.1 60.1 50.0 69.9 169.8 140.1 140.1 39.9 269.8 109.3 109.3 38.6 38.6 1221.3 289.6 289.6 149.9 Minimum Distance method M.D. Diverging from M.D. 312.5 312.5 437.5 437.5 0.0 0.0 100.0 100.0 100.0 100.0 3OO.O 3OO.O 300.0 300.0 600.0 600.0 600.0 600.0 100.0 100.0 100.0 100.0 100.0 8340.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 9480.4 100.0 100.0 200.0 9420.0 260.0 260.0 325.0 325.0 325.0 325.0 375.0 375.0 375.0 375.0 387.5 387.5 220.0 220.0 220.0 220.0 200.0 200.0 PMSS <7950-11950'>, .45.~ . PMSS <654 - 10956'>.,38PBl,gD~l PMSS <9876 - 12240'>,,38,CD~1 PMSS <10803-13706' >,. 24, CD~I PMSS <0-11067' >.. 32PH1, CD~I PMSS <10013' - 14353'>,,32.CD~1 PMSS <8464-11500' >., 22, CD~i PMSS <475 - 8166'>,.41PH1.CD/~1 PMSS <7182 - 11170'>,,41,CD~1 PMSS <0-11934'>,, 9PH, CDt}i PMSS <10894 - 15350'>..g.CD~l PMSS <12550 - 16023'>,.6,CD~1 PMSS <0-13308' >,, 6PH,CD~I PMSS <0-12055'>,, 40, CD~i PMSS <0-13450' >.. 35, CD~i PMSS <0-11608' >,, 42. CD~i PMSS <0 - ???>,,43,CD~1 16-Nov-1999 13-Feb-2000 14-Feb-2000 7-Aug-2000 4-Jan-2000 12-Dec-1999 11-Aug-2000 26-Mar-2000 3-Apr-2000 14-Jul-2000 20-gun-2000 21-Aug-2000 21-Aug-2000 17-~ul-2000 24-~ul-2000 23-Dec-1999 22-Aug-2000 149.9 79.6 79.6 59.3 19.2 19.2 79.4 109.7 109.7 210.0 210.0 240.3 240.3 100.0 49.8 120.0 130.3 200.0 180.0 180.0 325.0 425.0 425.0 312.5 100.0 100.0 100.0 100.0 300.0 300.0 100.0 100.0 100.0 100.0 200.0 180.0 180.0 325.0 425.0 425.0 312.5 933.3 9000.0 350.0 350.0 300.0 300.0 100.0 7460.0 9480.4 100.0 Phillips Alaska, Inc. CDJl 30 slot #30 Alpine Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : CD1-30 Vets#6 Our ref : prop3530 License : Date printed : 23-Aug-2000 Date created : 11-Aug-1999 Last revised : 22-Aug-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is nT0 20 32.877,w150 55 36.772 Slot Grid coordinates are N 5975700.122, E 385794.756 Slot local coordinates are 429.01 S 2371.14 E Projection tlr~e: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Proximities will incorporate ellipses - when survey tools are defined ~or both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS <0-9236'>,,22,CD%1 CD1-21 Version %3,,21,CD#1 CD1-15 Version %2,,15,CDJl CD1-10 Version 93,,10,CD%1 PMSS <0-11492~>,,27,CD~1 PMSS <562 - 12134t>,,37,CD#1 PMSS <0-9357'>,,16PH1,CDJ1 PMSS <8393 - 12600'>,,16,CD%1 PMSS <9499 - 14515'>,,5,CD~1 PMSS <0-10504'>,,SPH1,CD%1 PMSS <0-10224'>,,39PH1,CD%1 PMSS <9146 - 13289'>,,39,CDJl PMSS <472 - 1545'>,,36PHl,CD#l PMSS <763 - 7440'>,,36PH2,CD#1 PMSS <6600 - 10654'>,,36,CD%1 ~ISS <832 - 12147'>,,25,CD%1 ~MSS <384 - 14477'>,,23,CDJl PMSS <0-11300'>,,13,CD~1 PMSS <9081 - 12811'>,,44,CD%1 PMSS <297 - 9882'>,,44PH1,CD#1 PMSS <476 - 11190'>,,34,CD~1 PMSS <0-10897'>,,3,CD%1 ~SS <0-10548'>,,19,CD#1 PNSS <2827 - 11956'>,,194, CD#1 CD1-33 Version #4,,33,CD#1 CD1-28 Version #5,,28,CD~1 CD1-20 Version #3,,20,CD#1 PMSS <0-8350'>,,26PH1,CD#1 PMSS <7755-11134'>,,26,CD~1 P(~IS <0-10255'>,,WD2,CD91 WMSS <0-7331'>,,1PH1,CDJ1 PMSS <5946 - 10289'>,,1,CD#1 PMSS <0-8844'>,,45PH1,CD%l PMSS <7950-11950'>,,45,CD%1 PMSS <654 - 10956'>,,38PB1,CD%1 Closest a~roach with 3-D Last revised Distance 11-Jul-2000 )77.7( 10-Aug-1999 )86.5( 5-Apr-2000 )148.3( 10-Aug-1999 )198.3( 16-Mar-2000 )23.9( 26-Aug-1999 )68.1( 4-Jan-2000 )139.2( 25-0ct-1999 )139.2( 23-Jan-2000 )247.3( 23-Jan-2000 }247.3( 4-Jan-2000 )85.2( 22-Sep-1999 )85.2( 4-Jan-2000 )59.1( 4-Jan-2000 )59.1( 22-Dec-1999 )59.1( 15-Mar-2000 )48.1( 3-May-2000 )68.3( 15-Ju1-1999 )168.7( 23-May-2000 }139.2( 23-May-2000 )139.2( 11-May-2000 )37.9( 4-Jan-2000 }268.3( 6-Apr-2000 }107.5( 30-Apr-2000 )107.5( 11-Aug-1999 )27.4( 13-Jan-2000 )17.1( 10-Aug-1999 )0.0( 6-Mar-2000 )36.6( 1-Nov-1999 )36.6( 28-Jun-1999 )1218.4( 29-Feb-2000 )288.3( 27-Jun-1999 )288.3( 4-Jan-2000 )148.7( 16-Nov-1999 )148.7( 13-Feb-2000 )78.0( Minimum Distance method M.D. Diverging from M.D. 350 0 662 5 350 0 312 5 450 0 387 5 220 0 220 0 325 0 325 0 637 5 637 5 140 0 140 0 140 0 325 0 260 0 312 5 160 0 160 0 260 0 312 5 362 5 362 5 437 5 412 5 13067 5 387 5 387 5 437 5 260.0 260.0 240.0 240.0 220.0 8780.0 12360.0 350.0 312.5 450.0 387.5 220.0 220.0 11440.0 11440.0 637.5 637.5 140.0 140.0 8600.0 325.0 260.0 9060.0 9500.0 160.0 9160.0 312.5 362.5 362.5 437.5 412.5 13067.5 387.5 387.5 437.5 260.0 7520.0 240.0 240.0 220.0 PMSS <9876 - 12240'>,,38,CD#1 CD1-24 Version %5,,24,CD%1 PMSS <10803-13706'>,,24,CD#1 CD1-17 Version %8,,17,CD#1 4 Version%11,,4,CD%1 CD1-2 Version #7,,2,CD#1 PMSS <0-11067'>,,32PH1,CD#l PMSS <10013' - 14353'>,,320CD#1 PMSS ¢8464-11500'>,,22,CD91 PMSS <475 - 8166'>,,41PH1,CD#1 PMSS <7182 - 11170'>,,41,CD#1 PMSS <0-11934'>,,~PHoCD91 PMSS <10894 - 15350'>,,9,CDtl PMSS <12550 - 16023'>,,6,CD91 PMSS <0-13308'>,,6PH,CD#1 PMSS <0-12055'>,,40,CD%1 35 Version#6,,35,CD#1 PMSS <0-13450'>,,35,CDtl CD1-29 Version #2,°29,CD%1 PMSS <0-11608'>,,42,CD#1 CD1-43 Version %11,,43,CD%1 PMSS <0 - ???>,,43,CD#1 CD1-31 Version#4,,31,CD#1 CD1-30 PH1 Version%6,,30PH1,CD#1 14-Feb-2000 29-Jun-2000 7-Aug-2000 19-ADr-2000 17-Jul-2000 9-Aug-2000 4-Jan-2000 12-Dec-1999 11-Aug-2000 26-Mar-2000 3-Apr-2000 14-Jul-2000 20-Jun-2000 21-Aug-2000 21-Aug-2000 17-Jul-2000 6-Jun-2000 24-Jul-2000 13-Jan-2000 23-Dec-1999 10-Aug-2000 22-Aug-2000 10-Aug-2000 23-Aug-2000 )78.0( )9338.8( )56.8( )127.4( )258.4( )278.4( )16.9( }16.9( )77.7( )104.1( )104.1( )208.3( )208.3( )238.6( )238.6( )99.2( )2192.0( )48.8( )7.9( )119.0( )128.9( )129.6( }7.4( )0.0( 220.0 1666.7 387.5 387.5 312.5 312.5 450.0 450.0 350.0 966.7 966.7 412.5 412.5 337.5 337.5 200.0 7860.0 200.0 462.5 200.0 260.0 160.0 425.0 9460.0 220.0 1666.7 387.5 387.5 312.5 10760.0 450.0 13067.5 9850.0 966.7 8988.2 9526.7 9526.7 337.5 337.5 8580.0 10480.0 11680.0 13067.5 9293.3 7760.0 7720.0 13067.5 9460.0 Phillips Alaska, Inc. CD#i 30PH1 slot ~30 Alpine Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : CD1-30 PH1 Version%6 Our ref : prop3016 License : Date printed : 23-Aug-2000 Date created : 27-Jun-1998 Last revised : 23-Aug-2000 Field is centred on n?0 20 37.100,w150 51 37.53 Structure is centred on nT0 20 37.100,w150 56 46.041 Slot location is nT0 20 32.877,w150 55 36.772 Slot Grid coordinates are N 5975700.122, E 385794.?56 Slot local coordinates are 429.01 S 2371.14 E Projection ty~e: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 £eet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse seDaration in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated Object wellpath PMSS <0-9236'>,,22,CD#1 CD1-21 Version #3,,21,CD%1 CD1-15 Version #2,,15,CD$1 CD1-10 Version #3,,10,CD91 PMSS <0-11492'>,,27,CD91 PMSS <562 - 12134'>,,37,CD#1 ~MSS <0-9357'>,,16PHl,CD#l PMSS <8393 - 12600'>,,16,CD%1 PMSS <9499 - 14515'>,,5,CD%1 PMSS <0-10504'>,,5PH1,CD#1 PMSS <0-10224'>,,39PH1,CD%1 PMSS <9146 - 13289'>,,39,CD%1 PMSS <472 - 1545'>,,36PH1,CD#1 PMSS <763 - 7440'>,,36PH2,CD#1 PMSS <6600 - 10654'>,,36,CD91 PMSS <832 - 12147'>,,25,CD%1 PNSS <384 - 14477'>,,23,CD91 PMSS <0-11300'>,,13,CD#1 PMSS <9081 - 12811'>,,44,CD%1 PMSS <297 - 9882'>,,44PH1,CD#1 PMSS <476 - 11190'>,,34,CD%1 PNSS <0-10897'>,,3,CD#1 PMSS <0-10548'>,,19,CD#1 PMSS <2827 - 11956'>,,19A, CD%1 CD1-33 Version #4,,33,CD~1 CD1-28 Version #5,,28,CD#1 CD1-20 Version #3,,20,CD91 PMSS <0-8350'>,,26PHi,CD91 PMSS <7755-11134'>,,26,CD$1 PGMS <0-10255'>,,WD2,CD#1 PMSS <0-7331'>,,1PH1,CD#1 PMSS <5946 - 10289'>,,1,CD#1 PMSS <0-8844'>,,45PH1,CD#1 PMSS <7950-11950'>,,45,CD%1 PMSS <654 - 10956~>,,38PB1,CD%1 Closest a~proach with 3-D Last revised Distance 11-Jul-2000)77.7( 10-Aug-1999)86.5( 5-ADr-2000 )148.3( 10-Aug-1999)198.3( 16-Mar-2000}23.9( 26-Aug-1999)68.1( 4-Jan-2000 )139.2 25-0ct-1999)139.2 23-Jan-2000)247.3 23-Jan-2000)247.3 4-Jan-2000 )85.2 22-Se~-1999)85.2 4-Jan-2000 )59.1( 4-Jan-2000 )59.1( 22-Dec-1999)59.1( 15-Mar-2000)48.1( 3-May-2000 )68.3 15-Ju1-1999)168.7 23-May-2000)139.2 23-May-2000)139.2 11-May-2000)37.9 4-Jan-2000 )268.3 6-A~r-2000 )107.5 30-Apr-2000)107.5 11-Aug-1999)27.4 13-Jan-2000)17.1( 10-Aug-1999)98.0 6-Mar-2000 )36.6 1-Nov-1999 )36.6 28-Jun-1999)1218.4 29-Feb-2000)288.3 27-Jun-1999)288.3 4-Jan-2000 )148.7 16-Nov-1999)148.7 13-Feb-2000)78.0 by an asterisk, e.g. 487.4* Minimum Distance method M.D. Diverging from M.D. 350.0 662.5 350.0 312.5 450.0 387.5 220.0 220.0 325.0 325.0 637.5 637.5 140.0 140.0 140.0 325.0 260.0 312.5 160.0 160.0 260.0 312.5 362.5 362.5 437.5 412.5 400.0 387.5 387.5 437.5 260.0 260.0 240.0 240.0 220.0 8780.0 8580.0 350.0 312.5 450.0 387.5 220.0 220.0 325.0 325.0 637.5 637.5 140.0 140.0 8600.0 325.0 260.0 312.5 9480.4 160.0 9420.0 312 5 362 5 362 5 437 5 412 5 400 0 387 5 387 5 437 5 260.0 7520.0 240.0 240.0 220.0 PI(SS <9876 - 12240',,,38,CD~1 CD1-24 Version 95,,24,CD~1 PMSS ~10803-13706',,,24,CD#1 CD1-17 Version %8,,17,CD%1 4 Version911,,4,CD%1 CD1-2 Version %7,02,CD#1 PMSS ~0-11067'~,,32PH1,CD#1 PMSS ~10013' - 14353'~,,32oCD91 PMSS ~8464-11500',,,22,CD#1 PMSS 4475 - 8166',,,41PH1,CD#1 PMSS 47182 - 11170'k,,41,CD%1 PMSS ~0-11934'>°,gPH,CD#1 PMSS 410894 - 15350'>,,9,CD~1 PMSS ~12550 - 16023'~,,6,CD%1 PMSS 40-13308'>,°6PH,CD91 PMSS ~0-12055'~,,40,CD#1 35 Version%6,,35,CD#1 PMSS 40-13450',,,35,CD#1 CD1-29 Version #2,,29,CD91 PMSS ~0-11608'-,,42,CD#1 CD1-43 Version #11,,43,CD#1 PMSS ~0 - ???~,,43,CD#1 CD1-31 Version#4,,31,CD#1 14-Feb-2000 29-Jun-2000 7-Aug-2000 19-Apr-2000 17-Jul-2000 9-Aug-2000 4-Jan-2000 12-Dec-1999 11-Aug-2000 26-Mar-2000 3-Apr-2000 14-Jul-2000 20-Jun-2000 21-Aug-2000 21-Aug-2000 17-Jul-2000 6-Jun-2000 24-Jul-2000 13-Jan-2000 23-Dec-1999 10-Aug-2000 22-Aug-2000 10-Aug-2000 )78.0( )9338.8( )56.8( )127.4( )258.4( )278.4( )16.9( )16.9( )77.7( )104.1( )104.1( )208.3( )208.3( }238.6( )238.6( )99.2( )2192.0( )48.8( )7.9( )119.0( )128.9( )129.6( )7.4( 220.0 1666.7 387.5 387.5 312.5 312.5 450.0 450.0 350.0 966.7 966.7 412.5 412.5 337.5 337.5 200.0 7860.0 200.0 462.5 200.0 260.0 160.0 425.0 220.0 1666.7 387.5 387.5 312.5 8500.0 450.0 450.0 8840.0 966.7 9000.0 412.5 412.5 337.5 337.5 8574.2 7860.0 8500.0 462.5 9480.4 7760.0 7720.0 4060.0 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 August 24, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-30 (& CD1-30 PH) Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD1 drilling pad. The intended spud date for this well is September 16, 2000. It is intended that Doyon Rig 19 be used to drill the well. CD1-30 PH will be drilled through to the base of the Alpine Sand at an inclination of approximately 44.17°, This will allow evaluation of the reservoir interval. It will then be plugged back and sidetracked to enable a horizontal penetration of the Alpine reservoir. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as an open hole producer. At the end of the work program, the well will be closed in awaiting field start up. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: . ! 5. 6. 7. 8. 9. 10. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). A proposed drilling program, including a request for approval of annular pumping operations. A drilling fluids program summary. Proposed pilot hole schematic. Proposed completion diagram. Proposed completion diagram with open hole isolation options. Pressure information as required by 20 ACC 25.035 (d)(2). Proposed cementing program and calculations. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. ? ~i~ ii": '''~' ~?'~. [~"~:~" i! ',"- .......... ~"~ :";"~';i:' ~:~ ...... ~ ~; ~ ....... ~ {~ J~;' ~ .... ~'..;~ ~,.~ ........ ;:~...~;, ~', ......... .:., ~.. lc ...... ~ ~. ~'~' ~::~.:,:: ;:~..:x.4' If you have any questions or require further information, please contact Scott Reynolds at 265-6253 or Chip Alvord at 265-6120. Sincerely, Scott D. Reynolds Drilling Engineer Attachments CC: CD1-30 Well File / Sharon AIIsup Drake Chip Alvord Mike Erwin Gracie Stefanescu Lanston Chin ATO 1054 ANO 382 ANO 384 Anadarko - Houston Kuukpik Corporation e-mail: Tommy_Thompson @ anadarko.com Il Il ,~m Il i CASH ADVANCL i ][ 121 ORDER OF.. PERIOD END[NC; ,.. +,:. i~o ~':l, oo't,.OO,: :~ s ,,,o i, ? sooo.'t, ;,a,,.a ],..~ i I I I I I I I l[ Ill I I I I I DOLLARS VAUD r-OK AMOUNT OVER $1000 ' BROWN I Il Il I I I I WELL PERMIT CHECKLIST FIELD & POOL /~//~ IN;T CLAS[~{/ ~:::::~ V ~'{~//-- . 5. 6. 7. 8. 9. 10. 11. DATE 12. -~-2~ '~::::)13. COMPANY /~"/~:~-~ WELL NAME ~.~/'-,..~C3 PROGRAM: exp. dev v/ redrll ~ serv ~ wellbore seg ~ann. disposal para req ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 2'I. 28. 2~. Permit fee attached .... ~ .............. Lease number appropriat~. Unique well name and.numb~ .............. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... ' Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet'.regulation ................ BOPE press rating appropriate; test to ~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. GEOL AREA ~~ UNIT# {~~._~ ~ ON/OFF SHORE ~ ~ ~ - . ~,~.~, . N GEOLOGY 30. Permit can be issued wlo hydrogen sulfide measures ..... '"'"'"---'-- 31. Data presented on potential overpressure zones ....... /,~N ' '32. Seismic analysis of shallow gas zones .......... ~,, ~J' ~ Y'" N AP_PR DATE 33. Seabed condition survey (if.off-shore) ......... /~.. ~. - Y N ~ ~.Z.~'.C~ 34. Contact name/phone for weekly progress reports/,.e~oratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan '" .. (A) will contain waste in a suitable receiving zone; ....... (~) N APPR DATE (a) will not contaminate freshwater; or cause drilling waste., .. to surface; ' wK~ glZ~ (C) will not impair mechanical integrity of the well used for disposal; (~N'~~f' ~'~4:~PILOV~ ~"-~'- ~"~7't/~.(:~ ~-)~ o~-'7'/~2~ LX.)~U_.. (D) will not damage producing formation or impair recovery from a ~ N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. ~) N GEOLO. GY: ENGINEERING: UICIAnnular COMMISSION: Comments/Instructions: Cl c:~nsoffice\wordian~iana~checklist (rev. 02/17100) ..