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Home My WebLink About200-118 Imag~oject Well History File Cover ~e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. (:L~- /- /- ~" Well History File Identifier Organizing (~o.~) [] RESC~N ~ms: [] Grayscale items: D Poor Quality Originals: [] Other: NOTES: DIGITAL DATA~ [] Diskettes, No. [] Other, No/Type BY: BEVERLY ROBIN~SHERYL MARIA WINDY Project Proofing BY: BEVERLY ROBI~SHERYL MARIA WINDY Scanning Preparation / x 30 :,~ BY: SEVERLY ROBIN~~SHERYL MARIA WINDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of vadous kinds Other Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: BY: Stage 2 BY: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: /~ YES NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUAUTY. GRAYSCALE OR COLOR IMAGES) IF NO IN STAGE 1, PAGE(S) DISCREPANC~E~W~RE/) ~ FOUND:. YES NO DATE,,~ (~-~ --~//'/~ ~,..~ RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: ISl General Notes or Comments about this file: Quality Checked 12110/02Rev3NOTScanned.wpd • pi- 2C002,co Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Saturday, March 10, 2012 11:54 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; ALP DS Lead and Simops Coord Subject: CD1 -31 (PTD 200 -118) Report of failed MITIA Jim, Guy ✓ i Alpine injector CD1 -31 (PTD 200 -118) failed a diagnostic MITIA. The TIO prior to the test was 1000/960/700. Further diagnostics will be performed utilizing Slickline and E -Line as needed. The well has been SI while awaiting further diagnostics and will be added to the monthly injector report. Pending the outcome of the diagnostics, the appropriate paperwork will be submitted for repair or continued injection. Attached is a 90 day TIO plot and schematic. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. ,- Desk Phone (907) 659 -7224 - r 2 flL Pager (907) 659 -7000 pgr. 909 , CRU CD1 -31 PTD 2001180 3/10/2012 TIO Pressures Plot TRN ANNL ANNULUS PRESSURE TRENDS TRN_RNNI SC WEL1 NAME WLALPCD1 -31 3000 moil. :::: II • . ... 3000. 2100, - - - - -- -- - -- -- - I 1800 1500 ... _ \-- _ - -/ - - -_. 1200 900 AA kAA!icA -A- - AArar -f 4! �• • O. 0. 6 00 . I 0. 300 i - - _.-..- Ji 0, 0. • PLOT START TIME MINOR TIME PLOT DURATI N PLOT END TIME 11- DEC -11 11:55 MAJOR TIME WEEK gRS - MAR -12 11:55 7D 4W 8W1 ® ® ®m rfi PICK TINE: SC TAG NAME DESCRIPTION P -VALUE LATEST DRILLSITE WELL NM WLCD1 -31 -CHOKE FLOW TUBING CHOKE ?TM?? PREV WELL ® SCRATCH 95 FLOW TUBING PRESSURE 777777? cdl 31 ® SCRATCH_95 FLOW TUBING TEMP 77 7777? IIINEXT WELL 7 ?7777? ® 77 77777 ENTRY TYPE OPERATOR MI 7777 ? ?? ® OPERATOR VERIFIED ® SCRATCH_95 INNER ANNULUS PRES 77 77777 III SYSTEM AUTO ENTRY N E SCRATCH_95 OUTER ANNULUS PRES 7777777 Mg BOTH • :, WNS CD1 -31 ConocoPhillips ' ' Well Attributes Max Angle & MD TD „,,,,,,u, . 111L Wellborn a API /UWI Field Name Well Status Inc! (3 MD (ftKB) Act Barn (RKB) t.IXWCOPhlllipa 501032034700 ALPINE INJ 93.47 10,933.01 14,364.0 '''" Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date ••• Well COnbp - C0131, 10130/20/03:39:39 PM SSSV: WRDP Last WO: 42.34 9/14/2000 Schematc - Actual - Annotation Depth MKS) End Date Annotation Last Mod ... End Date Last Tag Rev Reason: RESET INJ VLV Imosbor 10/30/2010 Casing Strings -- ,t Casing Description String 0... SMng ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd .f04 CONDUCTOR 16 15.062 37.0 114.0 114.0 62.58 H-40 WELDED L Insulated Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 32 4111 IF SURFACE 9 5/8 8.697 36.8 2,636.0 2,378.5 36.00 J BTC - MOD Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 34.2 10,387.7 7,099.9 26.00 L - 80 BTCM 1 - r Casing Description String 0... String ID ... Top (BKB) Set Depth (f... Set Depth (TVD) ... String Wt . MI String Top Thrd OPEN HOLE 6 1/8 6.125 10,387.7 14,364.0 7 065 8 irk Tubing Description S trin , Tubin. Strinrs r f r i 9 9 0. String ID . Top (kK8) Set Depth ( / -• Sat Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 4 1/2 3.958 32.3 10 7,020.8 1260 L -80 IBTM Conn • letion Details Top Depth 1 (TVD) Top l oci Nonni... Top (ft1(8) MKS) (^) item Description Comment ID (In) 32.3 32.3 -0.34 HANGER FMC TUBING HANGER 4.500 I 1,742.1 1,709.8 27.06 NIPPLE CAMCO 'DB' NIPPLE 3.812 10,000.5 6,999.4 66.30 PACKER BAKER S -3 PACKER 3.875 10,044.7 7,016.5 68.37 NIPPLE CAMCO 'XN' NIPPLE 3.725 1 '. r 10,055.5 7,020.4 68.90 WLEG WIRELINE ENTRY GUIDE 4.500 Other I n Hole Wireline retrievable r lu e s valves, r um .s fish, etc. , Top Depth CONDUCTOR ;t ( Top I ncl Insulated, ftK8 37-114 '�; Top (RKB) ( ) ( °) Description Comment Run Date ID (in) ° , 1,742.0 1,709.7 27.06 VALVE 3.81" DB LOCK ON A -1 Injection Valve W/ 1.25" orifice 10/29/2010 1.250 (HWS -0005) vALVE,1ae2 Notes; General & Safety NIPPLE, 1,742 , End Date Annotation ir , •. 5/17/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematc9.0 ir a y" SURFACE, 37 -2.638 PACKER, 10,001 ' ,:i , i NIPPLE, 10,045 E. 10,064 1 Ii PRODUCTION, 34. 10,388 ;,!it‘ .i OPEN HOLE. PI +r 10,388. 14,364 T0, 14,364 • ConocoPh Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 01, 2011 RECE1VEC 4 {7��, / y j +,F 1. APR Era" Commissioner Dan Seamount � � � Oil & ts ComiSSion Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Lo� I g' Commissioner Dan Seamount: CI)/ -3/ 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 III 0 ConocoPhillips Alaska Inc. 1 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 -30 50103203480000 2001320 6" n/a 20" n/a 6.4 3/13/2011 c ........), 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 1 C~ MEMORANDUM To: Jim Regg ')C7 ~ P.I. Supervisor I,@~~ 7 22~U~ FROM: Bob Noble Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 22, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CDl-31 COLVII,LE RN iJNIT CDl-31 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~P~- Comm Well Name: COLVILLE RIV CJNIT CD1-31 Insp Num: mitRCN090617155341 Rel Insp Num: API Well Number: 50-103-20347-00-00 Permit Number: 200-118-0 / Inspector Name: Bob Noble Inspection Date: 6/13/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~l CDl-31 Type Inj. G '1'~ 6999 jA 550 3010 4 2970 2960 P.T.D 200ll80 TypeTest SPT Test psi 3010 QA 675 700 700 700 Interval 4YRTST P~ P '~ Tubing 3523 3523 3523 3523 Notes: ~"r !~~ ~~~~~ t,i~ 1 ~ ~1~( ~,~ ,r ~.r: ~ , ~~1,- . ; ~ ~ ~;;~.~ ''. ~_ ~. , w Monday, June 22, 2009 Page 1 of 1 . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 . SCJ\NNED APR 1 0 2007 6).ro-Hß Dear Mr. Maunder: ô\PR ~1 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 Irttegrity 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 2/16/2007 Alpine Field March 31,2007 ~. ". :. "'., . , . . ~'" MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to Drill 2001180 DATA SUBMITTAL COMPLIANCE REPORT Well Name/No. COLVILLE RIV UNIT CD1-31 3~5~2003 MD 14364 j TVD 7066 Operator CONOCOPHILLIPS ALASKA INC APl No. 50-103-20347-00-00 Completion Dat 9/13/2000 Completion Statu WAGIN '~ Current Status WAGIN r UIC Y_~. REQUIRED INFORMATION Mud Log Nc) Sample Nc) Directional Survey ~ ~/.4, DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name Log Log Scale Media (data taken from Logs Portion of Master Well Data Maint) Interval Run OH I Dataset No Start Stop CH Received Number Comments 2588 14364 Open 1/3/2001 09777~.'25~8-14364 R R L L C C L L L L SRVY RPT CBb..-'''~ 5 GPJCDR/Impulse Array Res MD ~ 2/5 Array Res TVD ~ 2/5 0 14364 OH 9/25/2000 SCHLUM 0-14364 FINAL 9800 10226 OH 1/2/2001 9800-10226 Color Print FINAL CH 1/3/2001 9777 FINAL 2585 14319 CH 1/3/2001 2585-14319 BL, Sepia FINAL 2585 14319 CH 1/3/2001 2585-14319 BL, Sepia Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/(~ Chips Received? ~ Analysis ~ R ~.r.~.iv~.d 9 Daily History Received? ~ N Formation Tops t~ N Comments: Compliance Reviewed By: Date: PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 FI. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 January 16, 2002 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Fourth Quarter, 2001 Dear Commissioner: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2001, as well as total volumes disposed into annuli for which' disposal authorization expired during the fourth quarter of 2001. Please call me at 265-6830 should you have any questions. Sincerely, R. Thomas Greater Kuparuk Team Leader RT/skad CC.' Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Annular Dis ~osal durin the fourth quarter of 2001: ' h(l) '~h-(2) ' h(3) ~ Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-42 2193 100 ' ' 0 2293 385 31314 33992 'june ' October CD~-15, CD2-'24, cD2-33 2001 2001 2P-417 5331 100 0 5431 0 627 6058 Sept 2o01 Decembex 2P-420, 2P-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July ~001 October CD2115, CD2-33, CD2-39, 2001 CD2-14 1C-16 12338 100 0 12438 0' 19679 32117 Sept 2001 Oc~°bet'' 1C-131, 1C-125, 1C-102 ~ 2001 "'CD2-39 27400 ' i00" 0 27500 379 0 27879 October November CD2-15, CD2-47 2001 2001 CD2-14 14359 "'1® 0 14459 376 0 14835 November December cD2-45, CD2-47' ' 2001 2001 1C-14" 22389 100 0 22489 ..... (~ 0 22489" Oct 2ool Nov 2OOl 1C-109 2P-438 .... 3..0.331 100 0 .. 30431 212 0 30643 Oct~OOl Dec 2001 2P-420, 2P-415, 2P-429 CD2-15 0 0 0 0 371 0. 371 NA* NA* *Freeze protect, CD2-15 only CD2-47 ' 10315 100 0 10415, 375 0 10790 Dec 2001 Dec 2001 CD2-34 Total Volumes into Annuli ~or which Dis 9osal Authori ation Ex 9ired durin 2001: Froze Protect To~l Volume S~ E~d Source We~ To~ h(1) To~! h(2) To~l h(3) Fiui~ Inject~ Date Date Well Name Volume ,,, Volume Volume Volume S~ of Annuim 2L-313 26290 1~ 0 0 26390 Open, Fr~ ~otec~d M~Ch 1~99 ~ 2~ 2L-317~ 2L-307 1D-36 301~ 1~ ' ' 0 0 302~ O~n, Fr~TM ~ot~ Oct 2~ Nov 2~ 1D42, 1D-34 CD1-31 6698 1~ 0 392 7190 Open, Free~ ~o~ct~ Feb 2~1 M~ch CDI-14 2~1 2N-305 6' '0 0 380 380 Open, Fr~ ~6t~t~ NA** NA** ** ~ze protect .... Volumes only 1D-~ 31915 i ~ 0 218 32~33 Open, Fr~ ~o~c~ Nov 2~ D~ 2~ ID-32, 1D40A 2N.~9A 0 .... 0 0 0 '0 ...... O~n, Free~ ~°~t~ ...... 1D42 32~0 1~ "' 0 265 3240'5 Open, Free~ ~ot~t~ Dec 2~ J~ 2~1 ~D-37, 1D-39 rn Annular Disposal durin the fourth quarter of 2001: ' h(1) h(2) ' h(3) Total fo~ Freeze PreVious New Start End Source WellS Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-42 2193 "'iO0 0 2293 385 31314 33992 Juno 'October CD2-15, CD2-~24, CD2-33 2OOl 2o01 2P-417 5331 100 0 543i ' 0 627 .... 6058 Sept 2001 December 2P-420, 2P-448 2001 CD2~24 ..... 298 i 100 0 3081 375 30543 33999 'July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 1C-16 12338 100 0 12438 0 1967'9 32117 Sept 2001 October 1C-131, 1C-125, 1C-102 2001 CD2-39 27'400 100 0 27500 379 ' 0 27879 October November CD2-15,. CD2-47 2001 2001 CD2-14 14359 100 0 14459 376 0 14835' November'' DeCember CD2-45, CD2-47 2001 2001 "1C-14 ..... 22389 100 0 22489 0 0 22489 'oct2oo! Nov200! 1C-109" ' '~ -~ ....... 2P'438 3033[. 100 0 . 30431 . .212 0 "' 30643 Oct. 2001 Dec 2001 2P-420, 2P-415, 2P-429' CD2'15 0 0 0 0 371 0 371 NA* NA* *Freeze protect CD2-15 only '"CD'L47' 10315 .......100 0 10415 375~' 0 10790 Dec2001 Dec2ool CD2-34 ,t,,ota,t, voturn,es tnto ,annuu ]or, wntcn ~,tsposat ,qurnonzanon v,,xptrea aunng tne,~ourt, n r~,uarter Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus ....... 2L'~3i'3 ............ 26290 ....... 100 0 0 " 26390 Open, Freeze Protected March 1999. Dec2000 2L-317,2L-307 ~1I).-36 30104 100 0 ........ 0 30204 ..... Open, Freeze Protected Oct 2000 Nov 2000 iD-42, 1D-34 CDI-31 6698 100 0 392 7190 Open, Freez~ Protected Feb 2~g)1 March CDI-14 2001 2N~305 ......... 0 0 0 380 380 Open, Freeze Protected NA** NA** ** freeze protect _ . ...... volumes only ID-34 31915'" 100 0" 218 32233 "' Open, Freeze Protected Nov 2000 Dec 2000 1D-32, ID-40A ZN-349A 0 "'0 0 0 0 Open, Freez~'Protected ...... ....... ID- 2 ,,, 32040 100 ' 0 265 ,, 32405 Open, Freeze Protected ,, Dec 2000 Jan 2001 1D-37, 1D-39 1. Operations perfOrmed: 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora~le, AK 99510-0360 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation shutdown_ Plugging _ Pull tubing _ Repair well _ 4. Location of well at surface 436' FNL, 2917' FEL, Sec. 5, T11N, R5E, UM At top of productive interval 1237' FSL, 881' FWL, Sec. 31, T12N, R5E, UM At effective depth At total depth 305' FNL, 1096' FEL, Sec. 36, T12N, R4E, UM 12. Present well condition summary Total depth: measured true vertical Stimulate _ Alter casing _ 5. Type of Well: St~atigraphic _ Servk:e_X (asp's 385786, 5975693) (asp's 379449, 5977466) (asp's 377530, 5981234) 14364 feet 7066 feet Plugs (measured) Perforate _ Other_X Conversion to WAG 6. Datum elevation (DF or KB feet) RKB 37 feet 7. Unit or Property name Colville River Unit 8. Well number CD1-31 9. Permit number / approval number 200-118 / 10. APl number 50-103-20347 11. Field / Pool Alpine Oil Pool Effective depth: measured true vertical Casing CONDUCTOR SURF CASING PROD CASING OPEN HOLE OPEN HOLE Length 114' 2636' 10388' Size 16' 9-5/8" 7" 14364 7066 feet Junk (measured) feet Cemented 10 cu yds Portland Type 3 407 sx AS III LW, 228 sx Class G 130 sx Class G Measured Depth 114' 2636' 10388' True vertical Depth 114' 2379' 7099' Perforation depth: measured open hole completion 10388' - 14364' true vertical open hole tubing (size, grade, and measured depth) 4-112'; 12.6~, L.80 Tbg @ 10057' MD. Packers & SSSV (type & measured depth) BAKER S-3 PACKER @ 10000' MD. CAMCO A.1 INJECTION VALVE, ORIFICE = 1.75' @ 1742' MD RECEIVED JAN $ 0 zoO? Alaska Oil & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily AveraRe Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Prior to well operation N/A Subsequent to operation 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _ Oil Gas _ Suspended ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Casing Pressure Tubing Pressure Service_WAG Injector. XX Questions? Call Chris Pierson 26.5-6112 Chr/s P/erson Form 10-404 Rev 06/15188 · Title Alpine Engineer ORiGiNAL Prepared by Sharon AIIsupOrake 263-4612 SUBMIT IN DUPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Pedorate_ Pull tubing _ Alter casing _ Repair well _ Other _X Conversion to WAG 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 436' FNL, 2917' FEL, Sec. 5, T11N, R5E, UM At top of productive interval 1237' FSL, 881' FWL, Sec. 31, T12N, R5E, UM At effective depth At total depth 305' FNL, 1096' FEL, Sec. 36, T12N, R4E, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service_X (asp's 385786, 5975693) (asp's 379449, 5977466) (asp's 377530, 5981234) 6. Datum elevation (DF or KB feet) RKB 37 feet 7. Unit or Property name Colville River Unit 8. Well number CD1-31 9. Permit number / approval number 200-118 / 10. APl number 50-103-20347 11. Field / Pool Alpine Oil Pool 12. Present well condition summary Total depth: measured true vertical 14364 feet Plugs (measured) 7066 feet Effective depth: measured true vertical Casing CONDUCTOR SURF (~ASING PROD CASING OPEN HOLE OPEN HOLE Length 114' 2636' 10388' Size 16" 9-5/8" 7" 14364 feet Junk (measured) 7066 feet Cemented 10 cu yds Portland Type 3 407 sx AS III LW, 228 sx Class G 130 sx Class G Measured Depth 114' 2636' 10388' True veAical Depth 114' 2379' 7099' Perforation depth: measured open hole completion 10388' - 14364' true vertical open hole Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 10057' MD. Packers & SSSV (type & measured depth) BAKER S-3 PACKER @ 10000' MD. CAMCO A-1 INJECTION VALVE, ORIFICE = 1.75" @ 1742' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl N/A Representative Daily Avera.qe Production or Iniection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _ Oil __ Gas _ Suspended __ Service _WAG Injector XX 17. I hereby certify that the_foregoing is true and correct to the best of my knowledge. Signed ~X~' Title Alpine Engineer Chris Pierson Questions? Call Chris Pierson 265-6112 Date Prepared by Sharon AIIsup-Drake 263~4612 JAN 31 2oo Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 April 24, 2001 RECEIVED APR 2 5 7.001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, First Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed' into surface casing by production casing annuli during the first quarter of.2001, as well as total volumes disposed into annuli for which disposal authorization expired during the.first quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul. Mazzolini Drilling Team Leader PM/skad CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon AllsuP-Drake Well Files Annular Disposal durin : the first quarter of 2001: · h(1) h~(2) h(3~ Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date CD1-44 8929 100 0 9029 22899 · 31928 Dec. '00 Jan.'01 c01.33, CD1-NQ1, CDI-10, CD1-28 2N-318 12276 100 0 12376 1619 13995 Dec.'00 Jan.'01 2N-314 CD1-43 30552 100 0 . 30652 385 31037 Jan.'01 Feb.'01 CD1-NQI~ CD1-21 CD1-31 6698 100 0 6798 392 7190 Feb.'01 Mar.'01 CDI-14 1D-42 .17187 100 0 17287 15118 32405 Dec.'00 Jan.'01 1D-37~ 1D-39 ,, 1D-32 23162 100 0 23262 337 23599 Jan.'01 Feb.'01 1D-39 1J-03 13020 100 0 13120 0 13120 Mar.'01 Mar.'01 1J-09~ 1J-14 Total Volumes into Annuli ror which Disposal Authorization Expired during the first quarter 2001: 7...0O" O~ - Total'Vo ume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected. Date Date Well Name Volume Volume Volume . Status of AnnUlus 1L-28 9837 100 0 9937 Open, Freeze Protected March 2000 April 2000 1L-20A, 1L-26A CD1-27 .32714 100 0 32814 Open, Freeze Protected May 2000 June 2000 CD1-44, CDI-19A, CD 1-09, CD 1-06 CD1-38 20220 100 0 20320 Open, Freeze Protected March 2000 May 2000 CD1-44, CD1-41, CD1- 19A CD1-05 286 100. 0 386 Open, Freeze Protected Jan. 2000 Jan. 2000 CD1-05 CD1-03 33890 100 0 33990 Open, Freeze Protected Aug. 2000 Sept. 2000 CD1-43, CD1-31, CD1 30 11/2/00 Scklumberger 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 CD1-31 20405 GRICDR/IMPULSE 000912 1 CD1-31 20405 MD ARRAY RES 000912 I 1 CD1-31 20405 TVD ARRAY RES 000912 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. Scklumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie N0.722 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine 11/22/00 Color Well Job # Log Description Date BL Sepia Prints CD CD1-31 20447 SCMT 001013 1 CD1-17 20457 OR/CDR/IMPULSE 001021 1 CD1-17 20457 MD ARRAY RES ~ 001021 I 1 CD1-17 20457 TVDARRAY RES ; 001021 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. STATE OF ALASKA (~ ..' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r'~ Gas E] Suspended E~] Abandoned E~] service r'~ Injector 2. Name of Operator.~..,_ ,_,._~.~ .... 7. Permit Number Phillips Alaska, Inc. -U'"X~IIMI'~ 200-118 3. Address w~T,~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360~ . 50-103-20347-00 4. Location of well at surface . iii, t'1o ,,,.'7~ ~' .:_.. 9. Unit or Lease Name 437' FNL, 2362' FWL, Sec. 5, T11N, R5E, UM (ASP: 385787, 5975693) ~ Colville River Unit At Top Producing Interval i ' '~ ' 10. Well Number 1237' FSL, 881' FWL, Sec. 31, T12N, R5E, UM ASP: 379449, 5977466)i .... .: CD1-31 At Total Depth i '~, '.:;.: i,;':~ · ;[ 11. Field and Pool 307' FNL, 1099' Fl:k, 8ec.36,112N, R4F, UM ASP: 377530, 5981234 ["~' [ Golville River Field 5. Elevation in feet (indicate KB, DF, etc.) 18. Lease Designation and Serial No. Alpine Oil Pool 37' RKB feetI ADL 380096 & 25558 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions August 30, 2000 September 11, 2000 September 13, 2000I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 12o. Depth where SSSV set 21. Thickness of Permafrost 14364' MD / 7066' TVD 14364' MD / 7066' TVD YES [~ No [~'1 N/A feetMD 1575' 22. Type Electric or Other Logs Run GR/Res 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surface 2636' 12.25" 407 sx AS III LW, 228 sx Class G 7" 26# L-80 Surface 10388' 8.5" 13o sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) 81ZE DEPTH 8ET (MD) PACKER 8ET (MD) 4.5" 10057' 10001' 6.125" open hole completion from 10388'-14364' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Waiting on Facility Start-Up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-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,^ REOEIVED NOV g g ZOO0 ~ 011 & G~ Cons. Commi~ion Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 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. CD1-31 Top Alpine 10193' 7062' TD 14364' 7066' Annulus left open - freeze protected with diese 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 ~ ~- ~ Title Alpine Drillin,qTeamLeader Date G. C. Alvord INSTRUCTIONS Prepared by Sharon AIIsup-Drake 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. RECEIVED Item 28: If no cores taken, indicate "none". Form10-407 NOV Z000 Alaska 011 & Gas Cons. Commission Anchora~ Date: 10/17/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CD1-31 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT SPUD:08/30/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20347-00 08/30/00 (D1) MW: 8.8 VISC: 300 PV/YP: 25/103 APIWL: 20.0 TD/TVD: 984/984 (984) SUPV:DAVE BURLEY / PAT REILLY PJSM. Move rig from CD1-43 to CD1-31. NU diverter. Accepted rig @ 1000 hrs. 8/30/00. Test diverter. Pre spud meeting. Drill from 114' to 260'. Run gyro. Drill w/gyro from 260' to 984' 08/31/00 (D2) MW: 9.6 VISC: 86 PV/YP: 17/24 APIWL: 20.0 TD/TVD: 2645/2384 (1661) CIRCULATING FOR CEMENT JOB. SUPV:DAVE BURLEY / PAT REILLY Drill from 2441" to 2645'. Circ hi vis sweep, recip, rot. Observe well, TOOH to 1078'. No problems. RIH to 2645' circ hi vis sweep rot - recip. Check flow. TOOH to BHA. RU to run 8-5/8" casing. 09/01/00 (D3) MW: 9.6 VISC: 42 PV/YP: 12/15 APIWL: 22.0 TD/TVD: 2645/2384 ( 0) CIRC. AND COND. MUD FOR LOT. SUPV:DAVE BURLEY / PAT REILLY PJSM. RIH w/9-5/8" casing to 2597'. PJSM. Hi vis nutplug wash. Pump cement. Plug bumped. ND diverter. NU BOPE and test to 250/3500 psi. 09/02/00 (D4) MW: 9.6 VISC: 45 PV/YP: 10/20 APIWL: 6.4 TD/TVD: 4497/2384 (1852) DRILLING AHEAD FROM 5312'. SUPV:DAVE BURLEY / PAT REILLY Set back 20 stds 5" DP. RIH w/DP. Tag up ~ 2545'. Circ and cond mud. Test 9-5/8" casing to 2500 psi. Drill float equipment and cement. Circ and cond mud for LOT. Perform LOT, 15.1 ppg. Displace with new mud. Drill from 2665' to 3734'. Circ hi vis sweep. TOOH to shoe 2636'. Check flow, RIH to 3734'. Drill from 3734' to 4497' 09/03/00 (D5) MW: 9.7 VISC: 42 PV/YP: 10/20 APIWL: 5.8 TD/TVD: 7162/5249 (2665) DRILLING 8-1/2" HOLE FROM 7542' SUPV:DAVE BURLEY / PAT REILLY Drill from 4497' to 5734'. Sweep and circ hole clean, check flow. TOOH to 3548'. Check flow. RIH to 5637', circ sweep. Wash to bottom. Drill from 5734' to 7162' RECEIVED NOV 2 2 000 Date: 10/17/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 09/04/00 (D6) MW: 9.7 VISC: 44 PV/YP: 9/29 APIWL: 5.2 TD/TVD: 9256/6493 (2094) POOH FOR LWD AND BIT CHANGE. SUPV:DAVE BURLEY / MOOSE CUNNINGHAM Drill from 162'-7542' Pump sweep, circ hole clean, check for flow, flush flowline, good. POOH for short trip from 7542'-5639'. Screw in @ 7447', break circ. slow, wash & ream from 7447' to 7542'. Drill from 7542' to 9256'. Spill drill. 09/05/00 (D7) MW: 9.7 VISC: 42 PV/YP: 8/23 APIWL: 4.2 TD/TVD: 9800/6906 (544) DRILL AHEAD FROM 10,047' SUPV:DAVE BURLEY / MOOSE CUNNINGHAM Drill from 9256' to 9541'. Pumped high vis sweep around and circ hole clean, monitor well. POOH to 7447' Monitor well, pump dry job. POH. RIH. CBU and cond mud. RIH to 9445' Wash down to 9541', pump high vis sweep, circ & cond mud. Drill from 9541' to 9800' 09/06/00 (D8) MW: 9.7 VISC: 42 PV/YP: 8/24 APIWL: 5.0 TD/TVD:10398/7102 (598) RIG UP TO RUN 7" CASING HOLD PJSM. SUPV:DAVE BURLEY / MOOSE CUNNINGHAM Hold PJSM, drill from 9800' to 10398'. Pump high vis sweep and circ hole clean. Check well for flow, static. POOH, pump out to 9920', check well for flow, wipe hole to 8500'. Check well for flow, good, RIH. Break circ slow from 10302' to 10398', pump sweep & circ, hole clean, monitor well, static. POOH, pump out from 10398' to 9920'. Monitor well, good. POOH to 8969'. Good. Monitor well, pump dry job. POOH. 09/07/00 (D9) MW: 9.6 VISC: 37 PV/YP: 6/16 APIWL: 5.0 TD/TVD:10398/7102 ( 0) TESTING BOPE. SUPV:DAVE BURLEY / MOOSE CUNNINGHAM RU to run 7" casing. PJSM. Run casing. CBU. Continue to run casing to 10388'. Troubleshoot Dowell Cat motor, unable to start primary motor. Circ and reciprocate casing. PJSM. 09/08/00 (D10) MW: 9.6 VISC: 47 PV/YP: 10/23 APIWL: 5.2 TD/TVD:10398/7102 ( 0) DRILL AHEAD FROM 10,444 SUPV:DAVE BURLEY / MOOSE CUNNINGHAM Cement 7" casing. Check floats. Set packoff and test to 5000 psi, good. PJSM. Test BOPE to 250/3500 psi. Tested good. RIH, tag cement @ 10265'. Test 7" casing to 3500 psi, tested good. 09/09/00 (Dll) MW: 9.2 VISC: 48 PV/YP: 11/23 APIWL: 4.4 TD/TVD:l1739/7090 (1341) DRILLING AHEAD FROM 12,165' SUPV:DAVE BURLEY / MOOSE CUNNINGHAM Test 7" casing to 3500 psi. Drill out cement in shoe track and 20' of new hole to 10418'. CBU. Perform FIT to 12.5 ppg. Change well over to 9.2 ppg FloPro mud. Drill from 10418' to 11739' RECEIVED NOV 000 Alaska Oil & Gas Cons. Commission Anchorage Date: 10/17/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 09/10/00 (D12) MW: 9.2 VISC: 48 PV/YP: 10/23 APIWL: 4.0 TD/TVD:12997/7084 (1258) DRILLING AHEAD FROM 13350' SUPV:DAVE BURLEY / MOOSE CUNNINGHAM Drill from 11739' to 12388'. Pump low/high vis sweeps and circ hole clean, monitor well, static. Pump out to shoe, no problems, monitor well. RIH to 12293'. Precautionary wash and ream from 12293' to 12388' Drill from 12388' to 12997' 09/11/00 (D13) MW: 9.2 VISC: 49 PV/YP: 11/23 APIWL: 3.8 TD/TVD:14364/7066 (1367) RIH FROM SHOE, NO PROBLEMS. SUPV:DAVID BURLEY Drill 6.125" hole from 12997' to 14364'. Pump low/high vis sweeps and circ hole clean. 09/12/00 (D14) TD/TVD:14364/7066 ( SUPV:DAVID BURLEY MW: 9.2 VISC: 27 PV/YP: 0/ 0 0) RIH WITH 4-1/2" COMPLETION STRING. APIWL: 0.0 Circ hole clean. Pump out to shoe, no problems. CBU. RIH to 14228', no problems. Precautionary wash and ream to 14364', pump low/high sweeps and circ hole clean. Pumped Flo-vis sweep and change well over with brine. Monitor well, POH to 12388'. Pumped Flo-vis pill and displaced into open hole. POH to 10340', no problems. POH to BHA. 09/13/00 (D15) MW: 9.6 VISC: 27 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:14364/7066 ( 0) SPOT RIG OVER CD1-30 SUPV:DONALD LUTRICK RU to run 4.5" tubing. PJSM. RIH w/4.5" completion equipment. ND BOPE. NU tree and test to 5000 psi, OK. PJSM. Set packer and test tubing to 3500 psi. Test casing to 3500 psi. OK. Set BPV. RECEIVED NOV Oil & Gas Cons. Commission · . I SURVEY CALCULATION. AND'FIELD'WORKSHEET' Job No. '045 00045 Sidetrack No. Page 1 of 6 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/31 Survey Section Name CD1-31 MWD BHI Rep. NEWLON / GEHRES l~lll~r~i~ WELL DATA Target 'I'VD (FT) Target Coord. N/S Slot Coord. N/S -436.54 Grid Correction 0.000 Depths Measured From: RKB ~ USE ~ SS~ Target Description Target Coord. E/VV Slot Coord. F. AN 2363.88 Magn. Declination 26.540 Calculation Method MINIMUM CURVATURE Target Direction (DD) Bujld\Walk\DL per: 100ff[~ 30m[~ 10m~ Vert. Sec. Azim. 285.98 Magn. to Map Corr. ~ 26.540 Map North to: OTHER SURVEY DATA , , Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FI') (FT) (Per 100 FT) Drop (-) Left (-) 0.00 0.00 0.00 · 0.00 0.00 0.00 0.00 TIE IN POINT 30-AUG-00 MWD 114.00 0.00 0.00 114.00 114.00 0.00 0.00 0.00 0.00 0.00 8' M1C 1.4 DEG AKO 30-AUG-00 MWD 174.00 0.25 198.00 60.00 174.00 0.00 -O.12 -0.04 0.42 0.42 GYRO SINGLE SHOT 30-AUG-O0 MWD 351.00 1.35 110.00 177.00 350.98 -2.06 -1.20 1.80 0.77 0.62 GYRO SINGLE SHOT 30-AUG-00 MWD 473.47 2.86 100.42 122.47 ° 473.37 -6.54 -2.25 6.16 1.26 1.23 30-AUG-O0 MWD 564.84 3.26 95.23 91.37 564.61 -11.36 -2.90 10.99 0.53 0.44 30-AUG-00 MWD 654.99 2.89 100.25 90.15 654.63 -16.14 -3.54 15.78 0.51 -0.41 30-AUG-O0 I MWD 745.00 1.37 93~49 90.01 744~57 -19.45 -4.01 19.09 1.71 -1.69 30-AUG-00 MWD 834.00 0.55 95.25 89.00 833.56 -20.91 -4.11 20.57 0.92 -0.92 , 30-AUG-00 MWD 924.00 0.64 291.57 90.00 923.56 -20.83 -3.97 20.54 1.31 0.10 31-AUG-00 MWD 1013.00 3.41. 281.18 89.00 1012.49 -17.70 -3.27 17.48 3.13 3.11 31 -AUG-00 MWD 1109.00 7.09 279.19 96.00 1108.07 -8.97 -1.77 8.82 3.84 3.83 -2.07 31 -AUG-00 MWD 1204.00 10.71 278.34 95.00 1201.91 5.61 0.45- -5.70 3.81 3.81 -0.89 · 31 -AUG-00 MWD 1300.00 12.81 280.34 96.00 1295.89 25.04 3.65 -25.00 2.23 2.19 2.08 · __ __ 31 -AUG-00 MWD 1490.00 19.44 284.80 95.00 1478.43 77.27 15.01' -76.08 3.85 3.75 2.91 = ~'-- ~'~ :31-AUG-O0 MWD 1585.00 22.49 285.62 95.00 1567.13 111.26 23.94 -108.87 3.23 3.21 0.86 NNV~. ~. ?NNN 31 -AUG-00 MWD 1680.00 24.83 284.05 95.00 1654.14 149.37 33.68 -145.73 2.55 2.46 -1.65 31 -AUG-O0 MWD 1775.00 28.24 283.83 95.00 1739.12 191.77 43.89 -186.91 3.59 3.59 -0,23 ~ OH & Gas Corls. Co~ ...... ~ ........ A ...................... 31 -AUG-00 MWD 1870.00 31.72 282.80 95.00 1821.40 239.18 54.80 -233.11 3.70 3.66 -1.08 31 -AUG-00 MWD 1966.00 35.43 283.70 96.00 1901.37 292.21 66.99 -284.77 3.90 3.86 0.94 -~---~-' -~I~/D- ;' ;"~601°0- ';~t~- ........ ~3~ ........... ~-- --~-9~-6-~ ........ -;~.~-.-~- 80.70 -339.57 3.25 3,22 0.72 ~-~U-~O~-i-'-M~O "2i-56100 ..... 4'07l~ .......... ~-~8-8- i ....... ~)'(~-~'-~-0-~0~--''| ......... ~4(~- .... 96,20 -398.91 2.63 0.52 31-AUG-oo.i MW9 2251.00 44,07 286,08 I 9500 212035I .474.16 113,35 -460.76 3.38 3.27 1.26 - , .I , I, , / ,. Target TVD SURVEY CALCU TION AND FIELD WORKSHEET Job.o. 0450 0045 Company PHILLIPS ALASKA, INC. Rig Csntractor & No. Doyon Drilling Co. - Rig: #19 Survey Section Name CD1-31 MWD Sidetrack No. Page 2 of 6 Field ALPINE FIELD BHI Rep. NEWLON / GEHRES Target Coord. N/S WELL DATA Slot Coord. N/S -436.54 Grid Correction. 0.000 2363.88 Magn. Declination 26.540 285.98 Magn. to Map Corr. 26.540 .. Depths Measured From: RKB ~ MSL0 ssr-] Target Description Target Direction Date 31 -AUG-00 31 -AUG-00 31 ~AUG-00 31 -AUG-O0 02-SEP-00 02-SEP-00 02-SEP-00 02-SEP-00 02-SEP-O0 02-SEP-00 02-SEP-00 02-SEP-00 02-SEP-00 03-SEP-00 03-SEP-00 03-SEP-00 03-SEP-O0 03-SEP-00 03-SEP-O0i 03-SEP-00 03-SEP-O0 03_SEP-OO' Survey Depth 2346.00 2442.00 2536.00 2580.00 2719.00 2909.00 3099.00 3290.00 3481.00 3669.57 3862.00 4053.00 4241.00 4435.00 4624.00 4812.00 5005.00 5196.00 (OD) 5386.44 5577.00 5767.00 5957.00 6147.00 Target Coord. E/W Slot Coord. F_./W Build\Walk\DL per: 100ft[~ 30m~] 10m~ Vert. Sec. Azim. sURVEY DATA Hole Course Direction Length TVD (DO) (FT) . 287.02 95.00 2187.35 50.42 285.28 96.00 2252.73 284.33 94,00 284.51 44.00 283.93 139.00 283.20 190.00 282.81 190.00 284.98 191.00 284.87 191.00 284.09 ~188.57 283.16 192.43 282.40 191.00 281.72 188.00 . 283.20 194.00 282.87 189.00 282.71 188.00· Vertical Section 541.51 611.79 2314.41 682.70 2342.57 716.49 2431.87 8~P-96 2554.04 968.35 2675.82 1113.99 2797.03 1261.49 2917.18 1409.94 3036.86 1555.62 3158.04 1704.97 3277.76 1853.55 3397.23 1998.37 3520.01 2148.28 3638.34 2295.46 3755.26 2442.46 3875.10 2593.51 282.92 193.00 282.37 191.00 3994.77 2742.12 284.82 190.44 4113.89 2890.57 284.23 190.56 4233.19 3039.11 284.16 190.00 4354.13 3185.57 284.42 190.00 4475.38 3331.79 284.20 190.00 4596.94 3477.75 284.48 192.00 4720.06 3625.02 · Total Coordinate Build Rate Build (+) N(+) / S(-) E(+) / W(-) Drop (-) 132.55 -525.32 2.27 152.08 .592.83 1.75 170.20 -661.40 178.61 -694.14 204.78 -797.40 238.91 -938.85 271.73 -1080.96 307.20 -1224.23 345.44 -1367.70 381.88 -1508.79 417.08 -1654.06 450.00 ' -1799.19 480.34 -1941.14 512.75 -2087.80 545.99 -2231.38 578.58 -2374.94 612.14 -25~P-46 644.73 -2667.71 679.66 -2812.12 716.94 -2955.96 752.87 -3098.02 788.98 -3239.77 825.07 -3381.27 861.56 -3524.00 Calculation Method MINIMUM CURVATURE Map North to: OTHER Walk Rate Right (+) Left (-) 0.99 -1.81 2.30 -1.01. 0.61 0.41 -0.45 -0.42 Comment 0.29 -0.38 -0.13 -0.21 0.62 1.14 · 0.19 -0.08 -0.25 -0.41 6 3/4' M1XL 1.2 DEG AKO 0.62 -0.48 -0.40 -0.40 -0.27 -0.36 0.46 0.76 0.06 -0.17 0.26 -0.09 -0.18 0.11 -0.25 .0.29 0.33 1.2g -0.38 -0.31 -0.44 -0.04 0.31 o. 14 -0.12 0.32 0.15 Gas Cons. Commission AhGhGi'~ SURVEY CALCULATION AND FILLD WoRKSHE Job No. 0450-00045 Sidetrack No. Page 3 of 6 I ! Company PHILLIPS ALASKA. INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD ~ Well Name & No. PAD CD#1/31 Survey Section Name CD1-31 MWD BHI Rep. NEWLON / GEHRES ..... J~lr~"~~ WELL DATA ,.. Target TVD (F~) Target Coord. N/S Slot Coord. N/S -436.54 Grid Correction 0.000 Depths Measured From: RKB ~ MSLE] SSI'] Target Description Target Coord. E/W Slot'Coord. E/W 2363.88 Magn. Declination 26.540 Calculation Method MINIMUM CURVATURE Target Direction (DEl) Build\Walk\DL per: 100ft~ 30mE] 10m0 Vert. Sec. Azim. 285.98 Magn. to Map Corr. ' 26.540 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool DePth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) (FT) (Fl') (FT) (F~ (Per loo F'q Drop (-) Left (-) 03-SEP-O0 MWD 6528.00 50.21 283.71 189.00 4840.75 3770.39 896.98 -3665.07 0.33 -0.11 -0.41 03-SEP-00 MWD 6719.00 50.04 283.22 191.00 4963.20 3916.83 931.12 -3807.62 0.22 -0.09 -0.26 ~ 03-SEP-00 MWD 6909.00 49.63 282.76 190.00 5085.75 4061.82 963.75 -3949.10 0.28 -0.22 -0.24 - 03-SEP-00 MWD 7099.00 50.21 283.18 190.00 5208.08 4207.00 996.39 -4090.77 0.35 0.31 0.22 04-SEP-00 MWD 7290.00 50.28 283.72 191.00 5330.23 4353.69 1030.54 -4233.58 0.22 0.04 0.28 , , 04-SEP-00 MWD 7480.00 50.43 283.04 190.00 5451.45 4499.84 1064.39 -4375.91 0.29 0.08 -0.36 04-SEP-00 MWD 7670.00 49.45 282.87 190.00 5573.73 4645.06 1097.00 -4517.63 0.52 -0.52 -0.09 04-SEP-00 MWD 7860.00 50.43 284.27 190.00 5696.02 4790.34 1131.13 -4658.98 0.76 0.52 0.74 04-SEP-00 MWD 8050.00 51.39 284.92 190.00 5815.82 4937.77 1168.29 -4801.68 0.57 0.51 0.34 . 04-SEP-O0 MWD 8241.00 51.56 283.88 .191.00 5934.79 5087.13 1205.45 -4946.41 0.44 0.09 -0.54 04-SEP-00 MWD 8432.00 51.31 283.77 191.00 6053.86 5236.37 1241.14 -5091.43 0.14 -0.13 -0.06 51.06 282.84 190.00 6172.95 5384.25 1275.21 o.,o ,o.,, D i:: F'. i::: I\/l::: i'} 04-$EP-00 MWD 8622.00 04-SEP-O0 MWD 8812.00 51.41 284.34 190.00 6291.92 5532.26 1310.02 -5379.48 0.64 0.18 0.79 04-SEP-O0 M.WD 9000.00 51.10 284.04 188.00 6409.58 5678.82 1345.97 -5521.64 0.21 -0.16 -0.16 NOV ~. ~. ?Nfl_fl *-~-"~ 04-SEP-OO MWD 9191.00 50.80 283.20 191 .o0 6529.91 5827.02 1380.90 -5665.79 0.38 -0.16 .0.44 05-SEP-O0 MWD 9384.00 50.42 282.70 193.00 6652.39 5975.97 1414.32 -5811.16 0.28 -0.20 .0.26 il~aska 0}{ & Ga~ Coils. ~ ................ .__ ................................................. , ...... ~-~-,c,,-a,~ 05-SEP-O0 MWD 9476.00 49:83 202.51 92.00 6711.37 6046.45 1429.73 -5800.06 0.66 -0.64 -0.21 05-SEP-00 MWD 9537.79 50.02 282.68 61.79 6751.15 i 6093.65 1440.04 -5926.20 0.37 0.31 0.28 6 3/4' MlX 1.5 DEG AKO 05-SEP-00 MWD 9569.00 52.15 285.61 31.21 6770.76 6117.91 1445.98 -5949.74 10.00 6.82 9.39 .... 05-SEP-O0 MWD 9602.00 53.44 288.80 33.00 6790.72 6144.19 1453.76 -5974.84 8.63 3.91 9.67 05'-~-~--0~- MWD 9633.87 53.81 289.44 31.87 6809.62 6169.81 1462.17 -5999.09 1.99 1.16 2.01 05-SEP-O0 MWD 9664.00 53.82 289.79 30.13 68Z7.41 6194.08 1470.33 -602i .99 0.94 0.03 1.16 , ................ r .................... 7 ................................... r ................................. _z_ ................................... 05-SEP-O0i MWD 9698.00 54.26 [ 290.00 34.00 6847.37 6221.53 1479.70 -6047.87 1.39 1.29i 05-SEP-O0 'Ii MWD 9731.O0,, 54.35 II 290.02 33.00 6866.63 6248.27 148e.87 -6073.05 0.2811 0.27 0.06 SURVEY CALCULATION AND FIELD WORKSHEET - o no. 'o, 0-0oo s no. __ Company PHILLIPS ALASKA. INC. Rig Cbntractor & N°. D°yon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/31 Survey Section Name CD1-31 MWD BHI Rep. NEWLON / GEHRES WELL ata Target TVD (F-r) Target Coord. N/S Slot Coord. N/S -436.54 Grid Correction 0.000 Depths Measured From: RKB ~] MSL E] ssE~ Target Description Target Coord. E/W Slot Coord. E/W 2363.88 Magn. Declination 26.540 Calculation Method MINIMUM CURVATURE Target Direction (DD) Bui!cAWalk\DL per: 100ft[~ 30mE] 10m[~ Vert. Sec. Azim. 285.98 Uagn. to Map Corr. ' 26.540 Map North to: OTHER i SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / $(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (OD) (DD) (F'r) (F'r) (FT) (FT) (Per ~00 FT) Drop (-) Left (-) 05-SEP-O0 MWD 9758.00 54.52 291.48 27.00 6882.33 6270.15 1496.65 -6093.59 4.44 0.63 5.41 05-SEP-00 MWD 9791.00 55.64 293.15 33.00 6901.22 6297.04 1506.92 -6118.62 5.36 3.39 5.06 -- 06-SEP-O0 MWD 9823.00 57.62 295.94 32.00 6918.82 6323.46 1518.03 -6142.92 9.55 6.19 8.72 06-SEP-00 MWD 9855.00 59.65 298.79 32.00 6935.48 6350.24 1530,59 -6167.18 9.90 6.34 8.91 06-SEP-00 MWD 9887.00 62:63 301.69 32.00 6950.93 6377.39 1544.71 -6191.38 12.23 9.31 9.06 .__ 06-$EP-O0 MWD 9919.00 64.36 304.25 32.00 6965.21 6404.78 1560.30 -6215.40 8.97 5.41 8.00 06-SEP-O0 MWD 9950.00 64.86 304.45 31,00 6978.50 6431.35 1576.10 -6238.52 1.72 1.61 0.65 .... 06-SEP-00 i MWD 9982.00 65.64 305.33 32.00 6991.90 6458.85 1592.72 -6262.36 3.49 2.44 2.75 06-SEP-00 MWD 10014.00 66.78 307.17 32.00 7004.81 6486.31 1610.04 -6285.97 6.35 ' 3.56 5.75 06-SEP-O0 MWD 10042.00 68.24 308.68 28.00 7015.52 6510.30 1625.94 -6306.37 7.21 5.21 5.39 06-SEP-00 MWD 10078.00 70.00 311.03 36.00 7028.35 6541.06 1647.50 -6332.19 7.82 4.89 6.53 -- 06-SEP-00 MWD 10109.00 71 ~21 313.79 31.00 7038.65 6567.24 1667.22 · -6353.77 9.26 3.90 8.90 -" RECEIVED 06-SEP-00 MWD 10137.00 72.72 315.99 28.00 7047.32 6590.54 1686.01 -6372.63 9.21 5.39 7.86 06-SEP-O0 MWD 10180.00 73.68 318.07 43.00 7059.75 6625.80 1716.13 -6400.69 5.14 2.23 4.84 ' ... 06-SEP-O0' m~vvD 10204.00 74.47 319.02 24.00 7066.33 6645.15 1733.54 -6415.03 0.11 3.29 7.71 NOV 06-SEP-OO MWD 1'0269.43 77.85 327.72 65.43 7082.00 6695.25 1784.79 -6453.27 12.67 5.17 11.92 06-SEP-O0 MWD 10301.00 79.55 330.68 31.57 7088.19 6717.81 1811.38 -6469.12 10.65 5.38 9.38 AlasKa t,m ~ ~,,~ 06-SEP-00 MWD 10328.41 80.42 331.70 27.41 7092.96 6736.83 1835.03 -6482.12 4.85 3.17 3.72 -- 09-SEP-00 MWD 10464.00 87.05 334.56 135.59 7107.75 6828.41 1955.19 -6542.98 5.32 4.89 2.11 4 3/4' M1X 1.2 DEG AKO 09-SEP-O0 MWD 10558.00 89.52 333.51 94.00 7110.56 6891.21 2039.65 -6584.11 2.85 2.63 -1.12 · 09-SEP-00, MWD 10652.00 90.31 333.98 94.00 7110'70 6954.39 2123.95 -6625.70 0.98 0.84 0.50 09-SEP-OO MWD 10746.00 90.48 334.11 94.OO 7110.05 7017.21 2208.47 -6666.84 0.23 O. 18 O. 14 09-SEP-O0 MWD 10836.00 92~57- '~'; i~6- .... ~) 7107.66 7078.73 2280.50 -6707.90 3.66 ..... '~)~.8-3' "' · -O~s~':'(~O-: ..... ~'i~ ...... ~*0~)'3'310~3 ........ ~)~31'4'7 ........... ~*~(~'~- ....... -~7~)~ .... 7102.55 7146.21 2073.08 -6753.65 1.07 0.93 0.53 SURVEY CALCULATION AND FIELD WORKSHEET Job No. '0450-00045 Sidetrack No. Page 5 of 6 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/31 Survey Section Name CD1-31 MWD .......... BHI Rep. NEWLON / GEHRES I~r~ WELL DATA Target TVD (FT) Target Coord. N/$ Slot Coord. N/S -436.54 Grid Correction 0.000 Depths Measured From: RKB ~] MSL ~ SS~ Target Description Target Coord. E/W Slot Coord. E/W 2363.88 Magn. Declination 26.540 Calculation Method MINIMUM CURVATURE Target Direction (DD) Bui!d\Walk\DL per: 100ff[~ 30m[-] 10m~ Vert. Sec..Azim. 285.98 Magn. to Map Corr. ' 26.540 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) _(_DO) (DO) (FT) · (FT) (FT) (FT) '(Per m0 FT) Drop (-) Left (-) 09-SEP-00 MWD 11027.00 92.10 333.50 94.00 7097.98 7210.47 2457.37 -6796.59 2.11 -1.46 1.52 09-SEP-00 MWD 11121.00 92.47 333.91 94.00 7094.23 7273.66 2541.58 -6838.20 0.59 0.39 0.44 09-SEP-00 MWD 11212.00 89.59 332.11 91.00 7092.60 7335.67 2622.64 -6879.49 3.73 -3.16 -1.9~, 09-SEP-O0 MWD 11307.00 90.00 332.28 95.00 7092.94 7401.40 2706.67 -6923.80 0.47 0.43 0.18 09-SEP-00 MWD 11398.00 90.31 332.09 91.00 ?092.69 7464.38 2787.16 -6966.26 0.40 0.34 -0.21 , , 09-SEP-00 MWD 11495.00 90.69 332.94 97.00 7091.84 7531.10 2873.21 -7011.03 0.96 0.39 0.88 09-SEP-00 MWD 11591.00 91.13 332.17 96.00 7090.32 7597.08 2958.39 -7055.27 0.92 0.46 -0.80 _ -- 09-SEP-00 MWD 11688.00 89.35 332.79 97.00 7089.91 7663.85 3044.41 -7100.08 1.94 -1.84 0.64 10-SEP-00 MWD 11781.00 89.83 333.43 93.00 7090.58 7727.12 3127.35 -7142.14 0.86 0.52 0.69 10-SEP-00 MWD 11876.00 90,00 332.21 95.00 7090.72 7792.10 3211.86 -7185.54 1.30 0.18 -1.28 10-SEP-O0 MWD 11969.00 90.62 332.98 93.00 7090.22 7855.98 3294.42 -7228.34 1.06 0.67 0.83 10-SEP-O0 MWD 12060.00 90.14 331.07 91.00 7089.61 7919.14 3374.78 · -7271.03 2.16 -0.53 -2.10 10-SEP-00 MWD 12153,00 90.58 331.94 93.00 7089.03 7984.29 3456.51 -7315.39 1.05 0.47 0,94 -- 10-SEP-00 MWD 12246.00 91.34 333.22 93.00 7087.47 8048.18 3539.05 -7358.21 1.60 0.82 1,38' -- 10-$EP-00 i MW~) 12338.00 89.25 330.38 92.00 7087.00 8112.29 3620.12 -7401.68 3.83 -2.27 -3.09 10-SEP-00 MWD 12429.00 89.59 330.91 91.00 7087.92 8177.01 3699.43 -7446.29 0.69 0.37 0.58 IO-SEP-00 MWD 12521.00 89.55 331.01 92.00 7088.61 8242,08 3779.86 -7490.95 0.12 -0.04 0.11 10-SEP-00 MWD 12613.00 89.73 333.03 92.00 7089.19 8305.94 3861.10 -7534.11 2.20 0.20 2.20 ,o.s .oo ,,.oo o.oo REC IVr:::n 10-SEP-O0 MWD 12799.00 90.65 332.29 95.00 7087.74 8433.11 4026.58 -7619.00 0.78 -0.04 -0.78 IO-SEP-O0 MWD 12892.00 90,93 332.33 93.00 7086.46 8497.32 4108.92 -7662.22 0.30 0.30 0.04 N V P. ?n nn ............................................................................................... ~.vvv 10-SEP-O0 MWD 129§5.00 91.41 333.34 93.00 7084.56 8560.91 4191.65 -7704.67 1.20 0.52 1.09 11 -SEP-OO MWD 13076.00 92.91 334.28 91.00 7081.13 8621.95 4273.24 -7744.80 1.94 1.03 Alaska 0{t & Gas C0[~$. Cofftlll~SS~OR .....11 -SEP-O0: ......... tl ......... MWD:"'I ............... 13167.00 9 i'1'37-', ...... 33~]~5- ...... ~i"."~'~ ....... :/-~)~:~'~- .......................................................... .8683.40 . 4354.60 -7785.42 2.46 -1.69 -1.79 SURVEY CALCULATION AND FIELD WORKSHEET Job.o. 0450-00045 Sidetrack No. Page 6 of 6 i Company PHILLIPS ALASKA, INC. Rig Cbntractor & NO. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/31 Survey Section Name CD1-31 MWD BHI Rep. NEWLON / GEHRES i~ WELL DATA · Target 'I'VD (FT) Target Coord. N/S Slot Coord. N/S -436.54 Grid Correction 0.000 Depths Measured From: RKB ~ MSL r-] ssU Target Description Target Coord. E/VV Slot Coord. E/W 2363.88 Magn. Declination 26.540 Calculation Method MINIMUM CURVATURE Target Direction (Do) Builcl~Walk\DL per: 100ft[~ 30m0 10m0 Vert. Sec. Azim. 285.98 Magn. to Map Corr. ' 26.540 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I'VD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F'r) (DO) (DD) (F'r) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) ., 11-SEP-00 MWD 13260.11 91.64 332.25 93.11 7075.29 8747.51 4437.12 -7828.47 0.52 0.29 -0.43 11 -SEP-00 MWD 13354.00 90.75 331.16 93.89 7073.33 8813.04 4519.77 -7872.97 1.50 -0.95 -1.16 11-SEP-00 MWD 13445.00 90.99 331.54 91 ~00 7071.95 8876.96 4599.62 -7916.59 0.49 0.26 0.42, i 1-SEP-00 MWD 13535.00 89.73 331.31 90.00 7071.38 8940.10 4678.65 -7959.64 1.42 -1.40 -0.26 -- 11-SEP-00 MWD 13629.00 89.93 332.58 94.00 7071.66 9005.44 4761.61 -8003.85 1.37 0.21 1.35 11-SEP-00 MWD 13718.00 90.21 331.92 89.00 7071.55 9066.96 4840.37 -8045.29 0.81 0.31 -0.74 11 -SEP-00 MWD 13812.00 90.07 331.75 94.00 7071.32 9132.43 4923.24 -8089.66 0.23 -0.15 -0.18 11-SEP-00 MWD 13904.00 90.07 331.58 92.00 7071.21 9196.70 5004.22 -8133.32 0.18 0.00 -0.18 -- 11-SEP-O0 MWD 13994.00 90.10 332.76 90.00 7071.08 9259.00 5083.80 -8175.34 1.31 0.03 1.31 11-SEP-O0 MWD 14089.00 89.83 332.62 95.00 7071.14 9324.14 5168.22 -8218.92 0.32 -0.28 -0.15 11 -SEP-00 MWD 14182.00 89.90 334.27 93.00 7071.36 9387.01 5251.40 -8260.50 1.78 0.08 1.77 __ 11-SEP-00 MWD 14275.00 92.19 333.70 93.00 7069.66 9449;22 5334.96 ' -8301.28 2.54 2.46 -0.61 11-SEP-00 MWD 14312.00 92.44 334.35 37.00 7068.17 9473.94 5368.19 -8317.47 1.88 0.68 1.76 11-SEP-00 MWD 14364.00 92.44 334.35 52.00 7065.95 9508.45 5415.03 -8339.96 0.00 0.00 0.00 Projected Data - NO SURVEY -- r-l:l\lP_. I~lUV ~ ~ .......... / / . I Type of request: STATE OF ALASKA (~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ 2. Name of Operator Alter casing _ Repair well _ Plugging _ Time extension _ Change approved program _ Pull tubing _ Variance _ .phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 437' FNL, 2362' FWL, Sec.5, T11N, R5E, UM At target (7" casing point in Alpine)) 1423' FSL, 750' FWL, Sec 31, T12N, R5E, UM At effective depth At total depth 1211' FNL, 663' FEL, Sec.36, T12N, RSE, UM ...... 5. Type of Well: Development __X Exploratory _ Stratigraphic _ Service _ per APD per APD Stimulate _ Perforate _ Other _ Annular Injection - X 6. Datum elevation (DF or KB feet) RKB 56' feet 7. Unit or Property name Colville River Unit 8. Well number CD1-31 9. Permitnumber/approval number 200-118 lO. APInumber 50-103-20347-00 11. Field / Pool Colville River Field/Alpine Oil Pool 12. Present well condition summary Total depth: measured 14364 feet true vertical 7062 feet Effective depth: measured 14364 feet true vertical 7062 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 77' 16" 10 cu.yds, Portland Type 3 114 114 Surface 2,600 9.625" 407 sx ASL3, 228 sx Class G 2636 2,384 Production 10054' 7" 130 sx Class G 10388' 7102' CD1-31 is as an open hole injection well. Itwas suspended after being completed with 4-1/2" tubing. It is intended that the 9-5/8" x 7" annulus be used for injection of associated drilling waste as per the previously applied for annular waste disposal permit application. 13. A~chments ~e~ription summa~ of proposal _ Detailed opera, on,program _~ BOP sketch 14. Estimated ~te for commencing operation ~15. Status of well classification as: I December 20, 2000 16. If proposal was verbal~ approved ~Oil ~ Gas __ Suspended __ Name of approver Date approv~ lSewice ~ [17. I hereby ~A~ that the foregoing is true and coffe~ to the be~ of my ~owledge. Signed ~~ ~~ Title: Drilling Te~ Leader Date 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-~ Approved by order of the Commission Commissioner Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 16, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Enable Annular Disposal of Drilling Waste on well: CD1-31 Dear Sirs: Phillips Alaska, Inc. hereby requests that CD1-31 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Please find attached form 10-403 and other pertinent information as follows: . 2. 3. 4. 5. 6. 7. Form 10-403 Surface Casing Description Surface Casing Cementing Report Copy of the Daily Drilling Report covering surface casing cementing. Casing and Formation Test Integrity Report (LOT at surface casing shoe). Formation LOT on 9-5/8" x 7" casing annulus. CD1-31 Well Completion Schematic. If you have any questions or require further information, please contact Scott Reynolds at 265-6253 or Chip Alvord at 265-6120. Scott D. Reynolds Drilling Engineer CC. CD1-31 Well File Alpine Files Chip Alvord Gracie Stefanescu ANO-382 Anadarko RECEIVED OCT Ancho?age Casing Detail Well: CD1-31 9 5/8" Surface Casinq Date: 8/31100 PHILLIPO Alaska, Inc. )LEUM COMPAHY ~ A ~uus~a~u7 or PI'llLLIP~ PP-I HULP-UM ~PAH¥ DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.80 FMC Gen V Hanger 2.71 36.80 Jts 3 to 69 67 Jts 9-5/8" 36# J-55 BTC Csg 2511.74 39.51 Davis Lynch Float Collar 1.53 2551.25 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 81.47 2552.78 Davis Lynch Float Shoe 1.76 2634.25 2636.01 TD 12 1/4" Surface Hole 2645.00 RUN TOTAL 40 BOWSPRING CENTRALIZERS - I per jt 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_ Use Best-o-Life 2000 pipe dope OCT Remarks: Up Wt - 155k Dn Wt - 140k Block Wt - 75k Supe~isor: D.P. Bu~ey / P. Re#ly Phillips Alaska Drilling Cementing Details Well Name: CD1-31 Report Date: 09/01/2000 Report Number:. 3 Ri~I Name: Do¥on 19 AFC No.: 998C12 Field: Alpine I I Casing Size Hole Diameter:. Angle thru KRU: Shoe Depth: ~ LC Depth: ~ % washout: 9 5/8 12.25 na 2636I 2551I 77 Centralizers State type used, intervals covered and spacing Comments: (40) 12.2S x 9.625 Bowsprings 1 per it. on #'s 1-13, every other joint to surface. Mud Weight: Pr(prior cond): PV(after cond): I YP(prior cond): YP(after cond): .~omments: 9.8 16 15I 31 7 Gels before: Gels after: Total Volume Circulated: 37/42/100 2/19/22 1200 Wash 0 Type: Volume: Weight: comments: Water 40 BBLS 8.4 High vis'Bio:mn w/7.5 Ib/bbl SPa~er 0 : Type: Volume: Weight: ~hlbnts: i · ARCO S45 50 BBLS 10.5 Lead C~hient: ;0: : ; Type: Mix wtr temp: No. of Sacks: Weight: Yield: c~n~eiit~!:: · AS III LW 70 407 10.7 4.4 i!:: .i .::': i~ ii ~: i .... i .i 'i :' : ' i 30% D063, 0.6% D046,1.S% D079, 1.5% S001, 50% D124 and 9% D044 ~i!i:e~n~; :: 0;:~ ~ ::i · :,. Type: Mix wtr temp: No. of Sacks: Weight: Yield: D!~i~n~ :i 0;!~ ;::; ;;~ ;.~= ;.:; ;;! Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: : :. ....... .:. .... :: ~ Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:09/01/00 Yes Yes Time:0946 Remarks:Reciprocated pipe while conditiong mud and first 280 bbls of lead cement, had +/- 100 bbls of 10.7 ppg cement returns to surface, full returns throughout. Cement Company: IRig Contractor: DOYON IApproved By: D. Burley / P. Reilly Dowell Phillips Alaska Drilling Daily Drilling Report AFC No. I Date Rpt No I Rig Accept - hrs Days Since Accept/Est: 2.6 / 3.5 998C12 109/01/2000 3 108/30/2000 10:00:00 Rig Relase - hrs: lAM Well: CD1-31 Depth (MD/'rVD) 2645/2384 Prev Depth MD: 2645 Progress: 0 Contractor: DOYON Daily Cost $ 207161 Cum Cost $ 439343 Est Cost To Date $ 525000 Ri~l Name: Do~/on 19 Last Cs~l: 9 5/8' O 2636'. Next Cs~l: 7' O 10364'. Shoe Test: Operation At 0600: CIRC. AND COND. MUD FOR LOT. Upcoming Operations: PERFORM LOT - DRILL 8 1/2' HOLE TO 9127'. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA, MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL SPUD 2645 N TST 08/27/2000 09/01/2000 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.6ppg 08/09/2000 08/20/2000 VISCOSITY PU WT' MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 42sqc 155 N SPACE 08/20/2000 06/21/2000 PV/YP SO WT TYPE TYPE TYPE 12/15 140 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 1605 5/7/9 APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 670 22.0 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 99 NAml/30 min ::IN~ECTI~N: : USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL 7.5% C D 1-03 ~ ~:~T~ HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F 41 204bbl III / / CD1-31 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 8 25.0 I 121 I 4.0 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 180° 5.s s.slsI I 1200 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F 32.50 5.5% III Water Base Muds 1294 PIT VOL GPM 2 JETS JETS Diesel PHILLIPS 2 0o III IIIII IIIII 40 PERSONNEL Other 546 DALLY MUD SPS 1 BIT COST BIT COST Cement CONTRACTOR 25 $10253 III 420 PERSONNEL Brine 390 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $21411 III III III 269o COMPANY MUD wm GRADE GRADE TOT FOR WELL (bbl) SERVICE 14 MI 9.61 I I III III 15465 PERSONNEL TOTAL 46 12:00 AM 04:30 AM 4.50 CASG SURF Casing and PJSM - MU FLOAT EQUIP - RIH w/g 5/8"" CASING T/2597' Cementing 04:30 AM 08:00 AM 3.50 CASG SURF Casing and PU LANDING JT AND HGR, - EST ClRC - ClRC AND COND. Cementing MUD - RU CMT HEAD - PJSM. 08:00 AM 10:00 AM 2.00 CEMENT SURF Casing and 40 BBL HI VIS NUTPLUG WASH - 50 BBL SPACER - 5 BBL Cementing H20 - TEST LINES - 407 SX AS III - 228 SX G. PUMPED 8.8 BPM BEFORE TAIL AT SHOE - 10 BPM TAIL AROUND SHOE - PLUG BUMPED - ClP @ 0945 HRS - 100 BBLS OF 10.7 PPG CEMENT TO SURFACE. 10:00 AM 10:30 AM 0.50 OTHER SURF Casing and LD CMT HEAD AND LANDING JT. Cementing 10:30 AM 11:30 AM 1.00 OTHER SURF Casing and CLEAR RIG FLOOR - RD CSG EQUIP. - RU STACK WASHER Cementing - FLUSH STACK - LD WASHER - BLOW DOWN TD. 11:30 AM 01:30 PM 2.00 NU_ND SURF Other ND DIVERTER - RISER - ANNULUS. 01:30 PM 02:30 PM 1.00 NU_ND SURF Other NU CSG HEAD AND TEST METAL TO METAL SEAL TO 1000 PSI. 02:30 PM 03:30 PM 1.00 NU_ND SURF Other NU BOPE. 03:30 PM 09:30 PM 6.00 BOPE SURF Other RU AND TEST BOPE RAMS AND VALVES 250/3500 - ANNULUS 250/2500. JEFF JONES AOGCC WAIVED WITNESSING THE TEST. 09:30 PM 10:00 PM 0.50 OTHER SURF Other SET WEAR RING. Daily Drilling Report: CD1-31 09/01/2000 Page I 10:00 PM 12:00 AM 2.00 24.00 PREP SURF Other PU MULE SHOE AND 60 JTS DP. Supervisor. DAVE BURLEY / PAT REILLY Daily Drilling Report: CD1-31 09/01/2000 Page 2 CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-31 Date: 9/2/00 Supervisor: Burley / Reilly Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG Casing Setting Depth: 2,636' TMD 2,377' TVD Hole Depth: 2,665' TMD 2,396' TVD Mud Weight: 9.6 ppg Length of Open Hole: 29' 2418 EMW = Press 685 psi 0.052 xTVD + Mud Weight - + 9.6 ppg 0.052 x 2,377' EMW = 15.14 ppg Pump output = .101 BPS Fluid Pumped = 1.1 bbls BLED BACK = 1.0 bbls 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 1,900 psi 1,800 psi 1,700 psi 1,600 psi 1,500 psi ],400 psi ],300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 700 600 500 400 300 200 100 0 psi psi psi psi psi psi psi psi psi 0stk 2stk 4stk 6stk 8stk 10 12 14 stk stk stk LEAK_OFF TEST i~iCASING TEST LOT SHUT IN TIME TEST SHUT IN TIME TIME LINE 16 18 20 22 24 26 28 30 32 34 36 38 40 stk stk stk stk stk stk stk stk stk stk stk stk stk STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE .................. [ ................................. .................. [ I I I~1 [i[~l ........ ]1[~1 ....I .................. ....... ~ 6stks ~ 220 psi .................. .................. .................. ,~ .............. t ................. -I [ 9stks , 490 psi , .................. : ''i~'~][]lit .... .................. .................. I. .............. ~ ................. -t ~ 12stks i 710psi .................. .................. f .............. ! ................. .................. ?.~141 --.s.t..klSl--.t.....7.9--.O--..P.s.L.J 1 I I I I I I I I 1 I I 1 .................. [ .............. ~ ................. 4 ! , , ! , ! .................. t .............. ; ................. I SHUT IN TIME I SHUT IN PRESSURE .... _l.:..O.._m.i.._n....[ .............. i .... .7.].O_.p.s..i._.] .... .3.-..O...m. il.n...,i .............. ] .....6..7.0_.Rs. i....i .... ~ :gllm [].... [ .............. i .....6.5.2.P.S--i.__.4 .... .6....o...m.i..n....[ .............. i .... -6--39--Es--i----~ .... ] :9l .m t~.. I l [ .............. i .... ~--]]-- PJt.. I 9.0min [ [ 600 psi ZZ.E ]EZEZZZZED.'SZ .'.ET,: CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE | Ostks ! Opsi 20 stks 2,000 psi , SHUT IN TIMEl I 10.0 mJn 2,460 psi i...L5.-.o_.m..i.r:. ..................... .2.~.4.5..5..~.sj... l_..2.5.:.o...mj..n. ..................... .2., .4.4_5_~.s.[ .... l I I i I I I NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-31 Reason(s) for test: Casing Size and Description: 9 5/8" 36# J-55 BTC CSG X Casing Setting Depth: 2,636' TMD 2,377' TVD Date: 9/8/00 Supervisor: D.P. Burley [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight 7" 26# L-80 BTCM CSG TOC Hole Depth: 9,693' TMD 6,844' TVD 9.6 ppg Length of Open Hole Section: 7,057' Mud Weight: EMW = Leak-off Press. + Mud Weight = 600 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,377' EMW for open hole section = 14'5 ppg Used cement unit YES Pump output = bbls pumped Fluid Pumped = 9.0 bbls Rig pump used # 2 Fluid Bled Back = 0.5 bbls ..................................................................................................... l ............. l ................... l ............................. 1 ................... 1.. 1 600 psi ~ ~ psi ~ / ~ psi ~ psi ~ LEAK-OFF TEST ~CASINg TEST ~ psi ...... '~? LOT SHUT IN TIME ~ CASINg TEST SHUT IN TIME 1~ psi ~TIME LINE 0 psi 0 2 4 6 8 10 12 14 16 18 ~ BARRELS NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above PHILLIPS Alaska, Inc. A Subsidiary ot PHILLIPS PETROLEUM COMPANY LEAK-OFF DATA MINUTES FOR LOT BBLS PRESSURE ................ 1 ....... ~' ...... 1 ..... iF~'~i' .... I ................ ~ ............... -I- ........ ' ........ ~ 1.0 I 242 psi i ................ 1 ..... '~ ..... t'"~"~'~i'"l ................ 1 ..... ':~i~ ..... ................ 1 ..... ',i76 ..... l'-"~/~"/,'~i'"l ................ ! ....... = ...... ! ................. , 5.0 , 600 psi i ................ ~ ............... -I ................. J 6.0 I 589 psi ~ ................ l ..... '~:~ ..... t'"~"~'a"'l ................ ! ..... '~:~ ..... t'"~"~'a'"! ................ 1 ..... - :ii ..... ................ 1 ............... 1 ................. ! , ,, , , ,, ................ '! ............... ~ ................. ................ ~ ............... ~ ................. I , I ................ ~ ............... ~ ................. i , ................ ~, ............... I' ................ ! ................ ~ ............... ~ ................. i i i i , i i ! , ! ! , ! ................ ~ ............... ~ ................. ' I I I J SHUT IN TIME J SHUT IN PRESSURE min 0.0 , , 580 psi 2.0min i ! 499 psi '-§7~"BB'"I ............... I'"'~ii~'1~'~i .... ................ ! ............... I 4.0 min , , 494 psi "'~D' ........ min ! ...............t-"~"l~'~i'" ................~.o m~ 1 ............... t'"~i~"~'a'" "'~:D' ........ min l ............... t'"~"~'a'" "-~:~' ........ min ! ...............t'"~'i~'~i'" ..!.o....o...m. Ln..i ............... j....4.!~..~!... CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ................ [ ............... I ................ I I ! ................ i ................................ 1 ................ ~ ................................ I ' 1 ................ ! ................................ ! ' 4 ................ i ................................ ................ 1 ................................ ................ ! ............... ~ ................ ................ I ............... ,~ ................ ................ ~ ................................ i ' SHUT IN TIME J SHUT IN PRESSURE "'5;~-r~B'"! ..................... 5'~'~ ..... ..... ~ .......... ~ ............................... 1.0 min ; ........... = .... ~ ................................ 2.0 m~n ~ 3.0 min ' .--x:b--~ra---i ................................. ................ ~ ............... , ................ .--~:9--~[~-..I ............... I ................ 4 ~ 0 rain ' ' ..... : .......... l ................................ 4 7.0 rain ~ 8.0 rain ~,' "'~:b"~ra"1 ................................ .-~-~6--~[3--~ ............................... ...... ......... ............... i ................ 15.0 rain ~ ~ ................................ "~:~"~[a'! ................................ ..~..~..~..~ ................................ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Modified by Scoff Reynolds CD1-31 Colville River Field Injection Well Completion Plan Updated 10/16/00 t[ll~ 4-1'2 Camco DB Nipple (3.812 ID) iItltl~ at 1700' TVD: 1742' MD il~i~tl 9-5/8"~ 36 ppf J-55 BTC ~ Surface Casing @ 2636' MD / 2400' TVD cemented to surface Completion TOC @ +/- 9693' MI; (+500' MD above top Alpine) Top Alpine at 10,193' MD / 7063' TVD A1 Injection Valve (2.125"1D) - to be installed later 4-1/2" 12.6 ppf L-80 IBT Mod. R._~.3 tubing run with Jet lube pipe dope Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB Nipple 4-1/2", 12.6#/ft, IBT-Mod Tubing S3 Packer (c/w handling pups) 4-1/2" tubing joint (1) R2 HES "XN" (3.725" ID) - 65 deg 4-1/2" 10' pup joint Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap Baker S3 Packer at +/- 10,000' (<200' MD above to top Alpine) Tubing Supended with diesel MD TVD 32' 32' 1742' 1700' 10000' 6999' 10045' 7017' 10057' 7020' 7" 26 ppf L-80 BTC Mod Production Casing @ 10,388' MD / 7102' TVD @ 87 deg Well TD at 14364' MD / 7062' TVD MWDILWD Log Product Delivery Customer Phillips Alaska Inc. Well No CD1-31 Installation/Rig Doyon 19 Dispatched To: AOGCC Date Dispatche 22-Sep-00 Dispatched By: Nathan Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 ;EP 25 ' 0)0 ~'~ I il.& G~' Cons. C }mm~ss~0n AnCh0mg0 Received By: Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 rose~anchorage.anadrill.slb.com Fax: 907-561-8417 LWD Log Delivery VI. 1, Dec '97 ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska Inc. Field .................... : Colville River Well ..................... : CD1-31 API number ............... : 50-103-20347-00 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 .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 55.63 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft O. O0 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 331.94 degrees ll-Sep-2000 22:52:26 Page 1 of 6 ORIGINAL Spud date ................ : 29-Aug-00 Last survey date ......... : ll-Sep-00 Total accepted surveys...: 134 MD of first survey ....... : 0.00 ft MD of last survey ........ : 14364.00 ft Geomagnetic data ............. Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 29-Aug-2000 Magnetic field strength..: 1147.16 HCNT Magnetic dec (+E/W-) ..... : 25.65 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-) ..... : 25.65 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.65 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6_lB_48] RECEIVED SEP 2000 Alaska Oil & Gas Cons. Commissio~ Anchoraoe ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth $ depth angle angle - (ft) (deg) (deg) 1 0.00 0.00 0.00 2 114.00 0.00 0.00 3 174.00 0.25 198.00 4 351.00 .1.35 110.00 5 473.47 2.86 100.42 6 564.84 3.26 95.23 7 654.99 2.89 100.25 8 745.00 1.37 93.49 9 834.00 0.55 95.25 10 924.00 0.64 291.57 11 1013.00 3.41 281.18 12 1109.00 7.09 279.19 13 1204.00 10.71 278.34 14 1300.00 12.81 280.34 15 1395.00 15.88 282.04 16 1490.00 19.44 284.80 17 1585.00 22.49 285.62 18 1680.00 24.83 284.05 19 1775.00 28.24 283.84 20 1870.00 31.72 282.80 21 1966.00 35.43 283.70 22 2060.00 38.46 284.38 23 2156.00 40.96 284.88 24 2251.00 44.07 286.08 25 2346.00 46.23 287.02 26 2442.00 47.91 285.28 27 2536.00 50.07 284.33 ~28 2580.00 50.34 284.51 29 2719.00 49.71 283.93 30 2909.00 50.26 283.20 C our s e length (ft) 0.00 114.00 60.00 177.00 122.47 91.37 90.15 90.01 89.00 90.00 89.00 96.00 95.00 96.00 95.0O 95.00 95.00 95.00 95.00 95.00 96.00 94.00 96.00 95.00 95.00 96.00 94.00 44.00 139.00 190.00 [(c)2000 Anadrill IDEAL ID6_lB_48] TVD depth (ft) 0.00 114.00 174.00 350.98 473.37 564.61 654.63 744.57 833.56 923.56 1012.49 1108.07 1201.91 1295.89 1387.92 1478.43 1567.13 1654.14 1739.12 1821.40 1901.37 1976.49 2050.33 2120.35 2187.35 2252.73 2314.41 2342.57 2431.87 2554.04 ll-Sep-2000 22:52:26 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 0.00 0.00 0.00 0.00 0.00 0.00 -0.09 -0.12 -0.04 -1.91 -1.20 1.80 -4.88 -2.25 6.16 -7.73 -2.90 10.99 -10.54 -3.54 15.78 -12.51 -4.01 19.09 -13.31 -4.11 20.57 -13.16 -3.97 20.54 -11.11 -3.27 17.48 -5.71 -1.77 8.82 3.08 0.45 -5.70 14.98 3.65 -25.00 29.90 8.25 -48.08 49.03 15.01 -76.08 72.34 23.94 -108.87 98.27 33.68 -145.73 126.66 43.90 -186.91 158.02 54.81 -233.10 193.07 67.00 -284.77 230.96 80.71 -339.57 272.54 96.21 -398.91 316.78 113.36 -460.76 364.08 132.55 -525.31 413.08 152.09 -592.83 461.32 170.20 -661.40 484.15 178.62 -694.14 555.81 204.79 -797.40 652.47 238.92 -938.85 Page 2 of 6 Total displ (ft) 0.00 0.00 0.13 2.17 6.56 At DLS Srvy Azim (deg/ tool (deg) 100f) type 0.00 0.00 TIP 0.00 0.00 MWD 198.00 0.42 GYR 123.80 0.77 GYR 110.07 1.26 MWD 11.37 '16.17 19.50 20.98 20.92 104.78 0.53 MWD 102.64 0.51 MWD 101.86 1.71 MWD 101.30 0.92 MWD 100.93 1.31 MWD 17.78 9.00 5.72 25.27 48.78 100.60 3.13 MWD 101.34 3.84 MWD 274.49 3.81 MWD 278.31 2.23 MWD 279.74 3.26 MWD 77.55 111.47 149.57 192.00 239.46 281.16 3.85 MWD 282.40 3.23 MWD 283.01 2.55 MWD 283.22 3.59 MWD 283.23 3.70 MWD 292.54 349.03 410.34 474.50 541.78 283.24 3.90 MWD 283.37 3.25 MWD 283.56 2.63 MWD 283.82 3.38 MWD 284.16 2.38 MWD 612.02 682.95 716.76 823.27 968.77 284.39 2.20 MWD 284.43 2.42 MWD 284.43 0.69 MWD 284.40 0.55 MWD 284.28 0.41 MWD RECEIVED SEP 25 2000 Alaska Oil& 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 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 31 3099.00 50.02 282.81 32 3290.00 51.20 284.98 33 3481.00 50.84 284.87 34 3669.57 50.37 284.09 35 3862.00 51.57 283.16 36 4053.00 50.80 282.40 1 37 4241.00 50.29 281.72 1 38 4435.00 51.18 283.20 1 39 4624.00 51.30 282.87 1 40 4812.00 51.79 282.71 1 41 5005.00 51.44 282.92 42 5196.00 50.97 282.37- 43 5386.44 51.60 284.82 44 5577.00 50.88 284.23 45 5767.00 50.05 284.16 46 5957.00 50.64 284.42 1 47 6147.00 49.81 284.20 1 48 6339.00 50.42 284.48 1 49 6528.00 50.21 283.71 1 50 6719.00 50.04 283.22 1 51 6909.00 49.63 282.76 1 52 7099.00 50.21 283.18 1 53 7290.00 50.28 283.72 1 54 7480.00 50.43 283.04 1 55 7670.00 49.45 282.87 1 56 7860.00 50.43 284.27 t 57 8050.00 51.39 284.92 1 58 8241.00 51.56 283.88 1 59 8432.00 51.31 283.77 1 60 8622.00 51.06 282.84 1 Course length (ft) 190.00 191.00 191.00 188.57 192.43 91.00 88.00 94.00 89.00 88.00 93.00 91.00 90.44 90.56 90.00 90.00 90.00 92.00 89.00 91.00 90.00 90.00 91.00 90.00 90.00 90.00 90.00 91.00 91.00 90.00 [(c)2000 Anadrill IDEAL ID6_lB_48] TVD depth (ft) 2675.82 2797.03 2917.18 3036.86 3158.04 3277.76 3397.23 3520.01 3638.34 3755.26 3875.10 3994.77 4113.89 4233.19 4354.13 4475.38 4596.94 4720.06 4840.75 4963.20 5085.75 5208.08 5330.23 5451.45 5573.73 5696.02 5815.82 5934.79 6053.86 6172.95 ll-Sep-2000 22:52:26 Vertical section (ft) 748.27 846.97 948.20 1046.73 1146.13 1243.45 1336.99 1434.58 1531.45 1627.75 1726.75 1823.83 1922.59 2023.14 2121.68 2220.22 2318.63 2417.98 2515.59 2612.77 2708.12 2803.56 2900.87 2997.70 3093.13 3189.74 3289.67 3390.54 3490.25 3588.08 Displ Displ +N/S- +E/W- (ft) (ft) 271.74 -1080.96 307.21 -1224.23 345.45 -1367.69 381.89 -1508.79 417.09 -1654.06 450.01 -1799.19 480.34 -1941.14 512.76 -2087.79 546.00 -2231.37 578.59 -2374.94 612.15 -2522.46 644.74 -2667.71 679.67 -2812.12 716.95 -2955.96 752.88 -3098.02 788.99 -3239.77 825.08 -3381.27 861.57 -3524.00 896.99 -3665.07 931.13 -3807.62 963.77 -3949.10 996.40 -4090.77 1030.55 -4233.58 1064.40 -4375.91 1097.01 -4517.62 1131.14 -4658.97 1168.30 -4801.68 1205.46 -4946.41 1241.15 -5091.42 1275.22 -5235.49 Page 3 of 6 Total At DLS Srvy displ Azim (deg/ tool (ft) (deg) 100f) type 1114.59 284.11 0.20 MWD 1262.18 284.09 1.07 MWD 1410.64 284.18 0.19 MWD 1556.37 284.20 0.41 MWD 1705.84 284.15 0.73 MWD 1854.62 1999.69 2149.84 2297.20 2444.41 284.04 0.51 MWD 283.90 0.39 MWD 283.80 0.75 MWD 283.75 0.15 MWD 283.69 0.27 MWD 2595.67 2744.51 2893.09 3041.66 3188.19 283.64 0.20 MWD 283.59 0.33 MWD 283.59 1.06 MWD 283.63 0.45 MWD 283.66 0.44 MWD 3334.46 3480.48 3627.79 3773.24 3919.82 283.69 0.33 MWD 283.71 0.45 MWD 283.74 0.34 MWD 283.75 0.33 MWD 283.74 0.22 MWD 4065.00 4210.37 4357.20 4503.50 4648.91 283.71 0.28 MWD 283.69 0.35 MWD 283.68 0.22 MWD 283.67 0.29 MWD 283.65 0.52 MWD 4794.32 4941.77 5091.18 5240.52 5388.56 283.65 0.76 MWD 283.68 0.57 MWD 283.70 0.44 MWD 283.70 0.14 MWD 283.69 0.40 MWD RECEIVED SEP 25 .?..000 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 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 ~ depth angle angle - (ft) (deg) (deg) 61 8812.00 51.41 284.34 62 9000.00 51.10 284.04 63 9191.00 50.80 283.20 64 9384.00 50.42 282.70 65 9476.00 49.83 282.51 Course length (ft) 190.00 188.00 191.00 193.00 92.00 66 9537.79 50.02 282.68 67 9569.00 52.15 285.61 68 9602.00 53.44 288.80 69 9633.87 53.81 289.44 70 9664.00 53.82 289.79 61.79 31.21 33.00 31.87 30.13 TVD depth (ft) 6291.92 6409.58 6529.91 6652.39 6711.37 6751.15 6770.76 6790.71 6809.62 6827.40 ll-Sep-2000 22:52:26 Vertical section (ft) 3686.53 3785.12 3883.76 3981.63 4027.64 Displ Displ +N/S- +E/W- (ft) (ft) 1310.03 -5379.48 1345.98 -5521.63 1380.91 -5665.79 1414.34 -5811.15 1429.74 -5880.06 4058.45 4074.76 4093.44 4112.26 4130.24 1440.05 -5926.20 1446.00 -5949.74 1453.77 -5974.84 1462.18 -5999.08 1470.34 -6021.99 71 9698.00 54.26 290.00 34.00 6847.37 4150.67 1479.71 -6047.87 72 9731.00 54.35 290.02 33.00 6866.62 4170.61 1488.88 -6073.05 73 975-8.00 54.52 291.48 27.00 6882.33 4187.14 1496.66'-6093.59 74 9791.00 55.64 293.15 33.00 6901.22 4207.98 1506.94 -6118.62 75 9823.00 57.62 295.94 32.00 6918 82 4229.21 1518.04 -6142.92 76 9855.00 59.65 298.79 32.00 6935.48 4251.71 1530.61 -6167.18 77 9887.00 62.63 301.69 32.00 6950.93 4275.55 1544.73 -6191.38 78 9919.00 64.36 304.25 32.00 6965.21 4300.61 1560,31 -6215.40 79 9950.00 64.86 304.45 31.00 6978.50 4325.43 1576.11 -6238.52 80 9982.00 65.64 305.33 32.00 6991.90 4351.31 1592.74 -6262.35 7004.81 7015.52 7028.35 7038.65 7047.32 81 10014.00 66.78 307.17 82 10042.00 68.24 308.68 83 10078.00 70.00 311.03 84 10109.00 71.21 313.79 85 10137.00 72.72 315.99 32.00 28.00 36.00 31.00 28.00 86 10180.00 73.68 318.07 87 10204.00 74.47 319.92 88 10269.43 77.85 327.72 89 10301.00 79.55 330.68 90 10328.41 80.42 331.70 [(c)2000 Anadrill IDEAL ID6 lB 48] 43.00 24.00 65.43 31.57 27.41 7059.75 7066.33 7082.00 7088.19 7092.96 4377.69 4401.32 4432.49 4460.05 4485.50 1610.05 -6285.96 1625.95 -6306.37 1647.51 -6332.19 1667.23 -6353.77 1686.02 -6372.63 4525.27 4547.77 4610.60 4641.52 4668.51 1716.14 -6400.68 1733.55 -6415.83 1784.80 -6453.27 1811.39 -6469.11 1835.04 -6482.12 Page 4 of 6 Total displ (ft) 5536.70 5683.32 5831.65 5980.79 6051.38 At DLS Srvy Azim (deg/ tool (deg) 100f) type 283.69 0.64 MWD 283.70 0.21 NfWD 283.70 0.38 MWD 283.68 0.28 mD 283.67 0.66 5fWD 6098.66 6122.93 6149.16 6174.71 6198.89 6226.26 6252.90 6274.70 6301.46 6327.71 283.66 0.37 ~fWD 283.66 10.00 5fWD 283.68 8.63 M~D 283.70 1.99 mD 283.72 0.94 ~fWD 283.75 1.39 M~D 283.78 0.28 NrWD 283.80 4.44 ~fWD 283.84 5.36 M~D 283.88 9.55 NFWD 6354.28 6381.17 6408.25 6434.54 6461.73 283.94 9.90 M~D 284.01 12.23 MWD 284.09 8.97 MWD 284.18 1.71 FfWD 284.27 3.49 P~gD 6488.88 6512.60 6543.00 6568.87 6591.89 284.37 6.35 NfWD 284.46 7.21 NN~D 284.58 7.82 ~fWD 284.70 9.26 NfWD 284.82 9.21 NFWD 6626.75 6645.90 6695.53 6717.93 6736.86 285.01 5.14 PrWD 285.12 8.11 NfWD 285.46 12.67 P~WD 285.64 10.65 NfWD 285 . 81 4 . 85 NfWD _M 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 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis RECEIVED 25 .000 N;s~ 0il & Gas Cons. commission Anrhnr~fll~ ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD % depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 91 10464.00 87.05 334.56 135.59 7107.75 92 10558.00 89.52 333.51 94.00 7110.56 93 10652.00 90.31 333.98 94.00 7110.70 94 10746.00 90.48 334.11 94.00 7110.05 95 10836.00 92.57 331.56 90.00 7107.66 96 10933.00 93.47 332.07 97 11027.00 92.10 333.50 98 11121.00 92.47 333.91 99 11212.00 89.59 332.11 100 11307.00 90.00 332.28 101 11398.00 90.31 332.09 102 11495.00 90.69 332.94 103 11591.00 91.13 332.17 104 11688.00 89.35 332.79 105 11781.00 89.83 333.43 106 11876.00 90.00 332.21 107 11969.00 90.62 332.98 108 12060.00 90.14 331.07 109 12153.00 90.58 331.95 1!0 12246.00 91.34 333.22 111 12338.00 89.25 330.38 112 12429.00 89.59 330.91 113 12521.00 89.55 331.01 114 12613.00 89.73 333.03 115 12704.00 90.69 333.03 116 12799.00 90.65 332.29 117 12892.00 90.93 332.33 118 12985.00 91.41 333.34 119 13076.00 92.91 334.28 120 13167.00 91.37 332.65 97.00 94.00 94.00 91.00 95.00 91.00 97.00 96.00 97.00 93.00 95.00 93.00 91.00 93.00 93.00 92.00 91.00 92.00 92.00 91.00 95.00 93.00 93.00 91.00 91.00 [(c)2000 Anadrill IDEAL ID6_tB_48] 7102.55 7097.98 7094.23 7092.60 7092.94 7092.69 7091.84 7090.32 7089.91 7090.58 7090.72 7090,21 7089.61 7089.03 7087.47 7087.00 7087.92 7088.61 7089.19 7088.85 7087.74 7086.46 7084.56 7081.13 7077.73 ll-Sep-2000 22:52:26 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 4803.17 1955.20 -6542.98 4897.06 2039.66 -6584.11 4991.01 2123.96 -6625.69 5084.94 2208.48 -6666.83 5174.89 2288.52 -6707.90 5271.75 5365.62 5459.51 5550.46 5645.46 2373.89 -6753.65 2457.38 -6796.59 2541.59 -6838.20 2622.65 -6879.48 2706.68 -6923.80 5736.46 5833.45 5929.43 6026.42 6119.40 2787.17 -6966.26 2873.22 -7011.02 2958.40 -7055.26 3044.42 -7100.08 3127.36 -7142.14 6214.38 6307.38 6398.37 6491.36 6584.34 3211.87 -7185.54 3294.43 -7228.34 3374.79 -7271.02 3456.52 -7315.39 3539.06 -7358.21 6676.33 3620.13 -7401.68 6767.30 3699.44 -7446.29 6859.28 3779.87 -7490.94 6951.27 3861.11 -7534.10 7042.26 3942.21 -7575.37 7137.24 7230.23 7323.20 7414.08 7504.98 4026.59 -7619.00 4108.94 -7662.21 4191.66 -7704.66 4273.26 -7744.80 4354.61 -7785.42 Page 5 of 6 Total displ (ft) 6828.86 6892.80 6957.80 7023.11 7087.54 At DLS Srvy Azim (deg/ tool (deg) 100f) type 286.64 5.32 IMP 287.21 2.85 IMP 287.77 0.98 IMP 288.33 0.23 IMP 288.84 3.66 IMP 7158.71 7227.20 7295.25 7362.45 7434.05 289.37 1.07 IMP 289.88 2.11 IMP 290.39 0.59 IMP 290.87 3.73 IMP 291.35 0.47 IMP 7503.14 7576.93 7650.42 7725.26 7796.83 291.81 0.40 MWD 292.28 0.96 IMP 292.75 0.92 IMP 293.21 1.94 IMP 293.65 0.86 IMP 7870.71 7943.69 8016.05 8090.89 8165.06 294.08 1.30 IMP 294.50 1.06 IMP 294.90 2.16 IMP 295.29 1.05 IMP 295.69 1.60 IMP 8239.55 8314.63 8390.57 8465.87 8539.75 296.06 3.83 IMP 296.42 0.69 IMP 296.78 0.12 IMP 297.13 2.20 IMP 297.49 1.05 IMP 8617.58 8694.42 8771.08 8845.48 8920.50 297 . 86 0.78 IMP 298.20 0.30 IMP 298.55 1.20 IMP 298 . 89 1.94 IMP 299.22 2.46 IMP RECEIVED 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 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 ll-Sep-2000 22:52:26 Page 6 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 121 13260.11 91.64 332.25 93.11 7075.29 7598.05 4437.13 -7828.47 8998.50 299.54 0.52 122 13354.00 90.75 331.16 93.89 7073.33 7691.92 4519.78 -7872.96 9078.11 299.86 1.50 123 13445.00 90.99 331.54 91.00 7071.95 7782.91 4599.63 -7916.59 9155.82 300.16 0.49 124 13535.00 89.73 331.31 90.00 7071.38 7872.90 4678.67 -7959.64 9232.86 300.45 1.42 125 13629.00 89.93 332.58 94.00 7071.66 7966.90 4761.62 -8003.84 9313.14 300.75 1.37 126 13718.00 90.21 331.92 89.00 7071.55 8055.89 4840.38 -8045.28 9389.14 301.03 0.81 127 13812.00 90.07 331.75 94.00 7071.32 8149.89 4923.25 -8089.65 9470.00 301.32 0.23 128 13904.00 90.07 331.58 92.00 7071.21 8241.89 5004.23 -8133.32 9549.51 301.60 0.18 129 13994.00 90.10 332.76 90.00 7071.08 8331.89 5083.82 -8175.33 9627.11 301.88 1.31 130 14089.00 89.83 332.62 95.00 7071.13 8426.88 5168.23 -8218.92 9708.82 302.16 0.32 131 14182.00 89.90 334.27 93.00 7071.35 8519.85 5251.41 -8260.50 9788.42 302.45 1.78 132 14275.00 92.19 333.70 93.00 7069.'.66 8612.76 5334.97 -8301.28 9867.78 302.73 2.54 133 14312.00 92.44 334.35 37.00 7068.16 8649.71 5368.21 -8317.47 9899.39 302.84 1.88 TVD Vertical Dispt Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis ~ IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis Last survey is a projection to Total Depth of CD1-31 134 14364.00 92.44 334.35 52.00 7065.95 8701.62 5415.04 -8339.96 9943.72 303.00 0.00 Projected [(c)2000 Anadrill IDEAL ID6_lB_48] . . RECEIVED SEP - 000 Naska Oil& Gas Cons. Commission Anchorage CD 1-31 Packer Setting Depth Subject: CD1-31 Packer Setting Depth Date: Mon, 11 Sep 2000 16:41:35 -0900 From: "Scott D Reynolds" <SREYNOL2~ppco.com> To: blair_wondzell~admin.state.ak.us CC: "Chip Alvord" <CALVORD~ppco.com>, "Michael D Erwin" <MERWIN~ppco.com> Mr. Wondzell, Phillips Alaska Inc., is approximately 1.5 days from running the completion on the Alpine grassroots injector well CD1-31. After working up the tubing detail for the completion, it has been determined that the Wireline Entry Guide (WEG) will be placed at 68 to 69 degrees inclination if the packer is set 196' from the top of the Alpine. Because this inclination makes it extremely difficult to work with wireline tools, Phillips Alaska Inc would like to ask for an exception to the requirement that the packer be set within 200' of the top of the Alpine Formation. We would like to move the packer up hole another 110' to 120' for a total distance of 303' to 313' above the Alpine. This would allow us to set our WEG at an inclination of 65 degrees; consequently, the difficulties working with wireline tools would be mitigated. Pertinent information: Calculated Top of Cement 9600' MD Top of the Alpine 10,193' MD 7" Casing Set @ 10,388' MD Planned packer setting depth (with 200' requirement) from top of Alpine) Planned packer setting depth (with exception) top of Alpine & 290' below the top of cement.) 10,000' MD (193' 9890' MD (303' from Regards, Scott D Reynolds Alpine Drilling Engineer 265-6253 1 of 1 9/1.2/00 3:06 PM ALASILA OIL AND GAS CONSERVATION COPlPllSSION Chip Alvord Drilling Team Leader Phillips Alaska, 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 CD 1-31 Permit No: 200-118 Sur Loc: 437'FNL, 2362'FWL, Sec. 5, T1 IN, R5E, UM Btmhole Loc. 1211'FNL, 663'FEL, Sec. 36, T12N, R4E, 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 casing annulus of a well approved for am~ular 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. The blowout prevention equipment (BOPE) nmst be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice maybe given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Semnount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~__ ~ff./v~ day of August, 2000 dlf/Enclosures cc: 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 Reddll ~ lb Type of Well Exploratory Stratigraphic Test Development Oil Re-Entry Deepen! Service X 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 Desig~qation ~ Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25558/~' ~O ~'~, 4. Location of well at surface 7. Unit or propd'rty Name 11. Type Bond (see 20 AAC 25.025) 437' FNL, 2362' FWL, Sec.5, T11 N, R5E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 1423' FSL, 750' FWL, Sec. 31, T12N, R5E, UM CD1-31 #U-630610 At total depth 9. Approximate spud date Amount 1211' FNL, 663' FEL, Sec. 36, T12N, R4E, UM 08/27/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line Alpine CD1- 32 13,365' MD Crosses T11 N, feet 9.2' @ 314' Feet 2560 7,081' TVD feet R5E to T12N, R4E 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 833' feet Maximum hole angle 92° Maximum surface 2507 psig At total depth (TVD) 3215 at psig 7000' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Wei~lht Grade Couplin~l Len~lth MD TVD MD TVD (include sta~le data/ 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 2627' 37' 37' 2664' 2400' 507 Sx Arcticset III L & 230 Sx Class G 8~5" 7" -26# L-80 BTC-M 10327' 37' 37' 10364' 7111' 133 sx Class G N/A 4.5" 12.6# L-80 IBT-M 9918' 32' 32' 9950' 7003' Tubing (packer depth) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: trSeeaSv~qcda, ;::tt Plugs (measured) 0 RIG IN A L Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size CemetJl~ ._~[i~_. ~ ~. ~ ~ ~ ~_.. I~ured depth True Vertical depth Structural.~i[ ~% ~r ~ %~ .~..-_ ~LJ~ ~,~,,,~ ~,,,, ~, ~ ~ Conductor Surface Intermediate ProductionJUL ;!5 2000 Liner Perforation depth: measuredA aSk & GaS Commission true verticalAnchorage 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 ~ ~ ~_~,~ Title Drilling Team Leader Date 7f~.,~{ GO Commission Use Only Permit Number I APInumber I Approvaldate .?/~/i~IOD I See cover letter for ~, ~ -- ~.~ 50- //'~l~-..~.,~:3 ~/~;~ Other requirements Conditions of approval Samples required Yes ~ Mud log required ~ Yes fl~TM] Hydrogen sulfide measures Yes //~"~)~rectional survey required (,'~'~) No Required working pressure for BOPE 2M 3M 5M 10M 15M by order of ~/~/00 Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 :n triplicate ORIGINAL SIGNED BY D Taylor Seamount Alpine: CD1-31 Procedure . 3. 4. 5. 6. 7. 8. . 11. 12. 13. 14. 15. 16. 17. 18. 19. 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 8-1/2" hole to the intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement 500 feet above Alpine reservoir, as per Rule 20 AC 25.030. 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 Y2, 12.6 Cf, L-80 tubing with 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. Circulate tubing to diesel and install freeze protection in the annulus. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Set BPV and secure well. Move rig off. ~\~,, ~-c~ RECEIVED JUL 25 2000 Alaska Oi-~ & Gas Co~so Oommimsio~ Anchomge 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 CD1-31 (9.2' at 314' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 7.5' at 343' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: There is some potential for lost circulation in the Alpine sand. If losses are encountered, conventional LCM treatments will be used. 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 CD1-31 will be injected into the annulus of a permitted well on the CD1 pad. The CD1-31 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 CD1-31 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 at 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 27992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 47599 psi 7,240 psi 6,154 psi RECEIVED JUL 25 2000 Alaska 0:~ ~ Gas Co~s. k;orn~s~on CD1-31 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 W' Section - 6 1/8" point- 12 N" 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 FIo-Trol starch will be used for viscosity and fluid loss control respectively. RECEIVED JUL 25 2000 A~chorage Colville River Field CD1-31 Injection Well Completion Plan ',i~i/I 1" n ' Updated 07/20/00 ~l/~ 6 Co ductor to 114 ~/m/] 4-1/2 Camco DB N~pple (3.812 ID) A1 Injection Valve (2.125"1D) - to i~////lt at 1700' TVD = 1733' MD be installed later ! ~ Surface Casing @ 2664' MD / 2400' TVD cemented to surface Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap Tubing Supended with 4-1/2" 12.6 ppf L-80 IBT Mod. R.~.3 diesel tubing run with Jet lube pipe dope Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB Nipple 1733' 1700' 4-1/2", 12.6#/ft, IBT-Mod Tubing S3 Packer (c/w handling pups) 9950' 7003' 4-1/2" tubing joint (1) HES "XN" (3.725" ID) - 65 deg 10000' 7025' 4-1/2" 10' pup joint ~ WEG, 10010' 7029' +/- 9950' (<200 MD above to top Alpine) .... ,,~,~ili!tiilii~fll~ll~i~li~ti~lti~tltli~lili~l~,- ............................. TOC @ +/- 9600' MD (+500' MD above top Well TD at Alpine) 13365' MD ! 7081' TVD Top Alpine at 10120' MD / 7069' TVD 7" 26 ppf L-80 BTC Mod ~'~ C~*"~. j'[~,[P~. Production Casing @ 10364' MD / 7111' TVD @ 88 deg ;ii"% ( Colville River Field CD1-31 Injection Well Completion Plan Formation Isolation Contingency Options Updated 07/20/00 16" Conductor to 114' 4-1/2" Camco DB Nipple (3.812" ID) @ 1700' TVD = 1733' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2664' MD / 2400' TVD cemented to surface 4-1/2" 12,6 ppf L-80 IBT Mod, R._~.3 tubing run with Jet Lube Run'n'Seal pipe dope (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Uod - 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) Open 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) - Uuleshoe / Entry Guide (C) Open Hole Bridge Plug Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe TOC @ +/- 9600' MD (+500' MD above top Alpine) RECEIVED JUL 25 2OOO Ai~ska OJ'; & Gas (;m~s.',.,omm~smon, ' ' Baker S3 Packer set at +/-9950' ~0~8 7" 26 ppf L-80 BTC Mod Production Casing ~ 10364' MD / 7111' TVD ~ 88 deg Well TD at 13365' MD ! 7081' TVD CD1-31 f 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 2664 / 2400 14.2 1086 1532 7" 10364 / 7111 16.0 3218 2507 N/A 13365 / 7081 16.0 3203 N/A · NOTE: 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 lb./gal 0.052 = Conversion from Ib,/gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP= FPP- (0.1x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. 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) = 1086 - (0.1 x 2400') = 846 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) = 3218 - (0.1 x 7111 ') = 2507 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3218 - (0.1 x 7111') = 2507 psi Alpine CD1-31 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 500 -500 -1500 -2500 -3500 P( PR -4500 -5500 -6500 -7500 [SStR~l M0[ ¢~EIG~tT i I I I '~ I I 8 9 10 11 12 13 14 15 16 17 EQUIVALENT MUD WEIGHT A. nchorage Alpifi=, CD1-31 Well Cementinq Requirements 9 5/8" Surface Casing run to 2664 MD / 2400' TVD. Cement from 2664' MD to 2164' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2164' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2164'-1575') X 0.3132 ft3/ft X 1.5 (50% excess) = 276.7 ft3 below permafrost 1575' X 0.3132 ft3/ft X 4 (300% excess) = 1973.2 ft3 above permafrost Total volume = 276.7 + 1973.2 = 2249.9 ft3 --> 507 Sx @ 4.44 ft3/sk System: Tail slurry: 507 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/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 ft3/ft X 1.5 (5~0% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft° shoe joint volume Total volume - 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 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 10364 MD/7111'TVD Cement from 10364' MD to +/- 9600' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (10364' - 9600~') X 0.1268 ft3/ft X 1.4 (40% excess) = 135.6 ft3 annular volume 80' X 0.2148 ft°/ft = 17.2 ft3 shoe joint volume Total volume = 135.6 + 17.2 = 152.8 ft3 => 133 Sx @ 1.15 ft3/sk System: 133 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft3/sk I By Weight Of mix Water, all other additives are BWOCement ICreated by bm;choel For: B Robertaon I Dote plotted: 18-Jul-200Q I Plot Reference is Co~dinot~ ore in f.~ refer~ Tr~e Vert~;I Depths =~ce RK~D~on 19)1 ~ I PHILLIPS Alaska, Inc. Structure: CD#I Well: 51 Field: Alpine Field Looafion: North Slope, Alaska <- West (feet) 8400 8000 7600 7200 6BO0 6400 6000 5600 5200 4800 4400 4000 5600 5200 2800 2400 2000 1600 1200 800 400 0 400 I I I I I I I I I I I I I I I I I I I I I I I t I I I I I I I I I I I I I I I I I I I I 4800 CD1-51 TD PT LOCATION: 1211' FNL, 665' FEL SEC. 56, T12N, R4E EOC Begin Fnl Drop EOC rD - Csg Pt. CD1-31 INTERM PT LOCATION: 2306' FSL, 280' FWL SEC. 51, T12N, RSE CD1-51 TGT LOCATION: 1425' FSL, 750' FWL SEC. 31, T12N, RSE 285.98 AZIMUTH 6758' (TO TARGET) ***Plane of Proposal*** TRUE K5 c~O 4400 4000 5600 32OO 2soo A I 1200 800 400 400 Z 2400 0 2000 ~.~ .-I- 1600 ~ PHILLIPS Alaska, Inc. Strucfure: CD#1 Well: ;51 0 ~ RKB ELEVATION: 56' Field: Alpine Field Looufion: North Slope, Alosko Nudge 1.5/100 1 Drop 1.5/100 500 3.50 Cr~t~ ~te ~ott~: 18-Jul-2~ 0.50~.00 End Drp/KOP ~ot R~erence le 31 Vw~3. 1000 9.00 West Sok ~dl~ ore In f~ refwe~ 1500 ~ 21.00 Permofrost ~ ~.oo ~ 45.00 c40 ~ EOC C5~~ 5/8 Cosing PL '~ 285.98 AZIMUTH ~c~o 6758' (TO TARGET) ~ ***Plone of Proposol*** TANGENT ANGLE 5500 ~ " ~ · Nbion-97 ooo RECEIVED Nblon-96 . ~oo JUL 2 5 ~000 x ,,z _~ ? ¢~ ,,,°~ ~,. ~aska 0~ & Gas bo~s. ~o~]i~88{0~ "~ 9. ~.~ '~ ,ooo ~chomge 71.00 . . ~500 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 500 0 500 1000 1500 2000 2500 ~000 3500 4000 4500 5000 5500 6000 6500 70~ Vertical Section (feet) -> Azimuth 285.98 with reference 0.00 S, 0.00 E from slot ~1 2000 2500 Q. 5000 3500 4000 4500 I v 5000 ICreated by bmloheel ];'0]': ]) Eobert~on I D~te plotted: 19-Jul-2000 Plot Reference ;,, 31 Coordingte~ are in feet reference slot ~31. I True Vertical Depths ore reference RKB(Doyon 19).I PHILLIPS Alaska, Inc. Structure: CD#I Well: 51 Fleld: Alpine Field Looafion: North Slope, Alaska 331.92 AZIMUTH 7700' (TO TD) ***Plane of Pmpoeal*** RECEIVED ~ 6600 r- 6800 '5 7000 ._ > 7200 7400 I V TARGET ANGLE 88 DEG FINAL ANGLE 90.29 DEG JUL 25 £000 Alaska Oi-~ & ~as Cons. Co~'nmission ,~chorage ! ! ! i ! ! ! ! i ! ! ! ! ! i i i ! ! ! !! ! !! ! ! ! ! ! i ! ! ! J ! ! !! ! 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 7800 8000 Vertical Section (feet) -> Azimuth 551.92 with reference 0.00 N, 0.00 E from sial #;~1 I Creoted by bm;choel For: ~te plotted: 19-Jul-2~ Coordi~te~ ore in f~ r~erenc~ 8~ ~31. I True Vert[~l D~thl o~e ~y~ lg).~ ~ I PHILLIPS Alaska, Inc. Structure: CD#1 Field: Alpine Field Well: ~51 Looafion: North Slope, Alaska RECEIVED jUL 26 2000 0:;'~ & Gas Oens. Commission ~orage Point Nudge 1.5/100 Drop 1.5/100 End Drp/KOP West Sak Permafrost C40 EOC C50 9 5/8 Casing Pt. C20 K5 K2 Albion-97 Alblan-96 HRZ K1 Begin Build LCU Miluveach A Alpine D Alpine Target - Csg Pt. EOC Begin Fnl Drop EOC TD - Csg Pt. Base Alpine MD 500.00 566.67 8,35.33 1046.88 1574.9,3 2,329.98 2521.54 2657.65 2665.96 5235.27 4895.87 5245.97 7912.29 8666.11 91 86.55 9708.52 9724.72 9868.85 9997.16 0062.96 0119.78 0565.75 0786.42 1170.12 1564.29 3564.54 5564.56 PROFILE COMMENT DATA Inc Dir TVD North 0.00 104.00 $00.00 0.00 4.00 104.00 566.45 -2.25 0.00 283.77 8,32.90 -4.50 6.41 28,3.77 1046.00 -1.66 22.25 28,3.77 1556.00 29.55 44.90 285.77 2181.00 128.15 50.65 283.77 2,509.69 1 61.89 50.65 285.77 2596.00 186.95 50.65 285.77 2400.00 188.11 50.65 285.77 2761.00 292.95 50.65 285.77 5814.00 598.67 50.65 285.77 4056.00 665.15 50.65 285.77 5728.00 1154.40 50.65 285.77 6206.00 1295.19 50.65 285.77 6556.00 1589.01 50.65 285.77 6867.00 1485.11 50.65 285.77 6877.28 1488.10 57.55 297.57 6962.00 1529.49 64.75 507.69 7024.00 1590.06 68.71 512.48 7050.00 1628.98 72.25 51 6.42 7069.00 1 666.49 88.00 551.99 7111.00 1860.64 92.25 551.99 7110.1 6 2255.71 92.25 551.99 7095.26 2572.20 90.29 5,51.92 7091.00 2745.52 90.29 ,551.92 7081.00 4508.23 90.29 551.92 7081.00 4508.25 East V. Sect 0.00 0.00 9.05 -9.50 18.06 -18.60 6.47 -6.68 -120.03 123.48 -522.94 558.00 -660.65 679.69 -762.87 784.86 -767.61 789.75 -1195.16 1229.62 -2442.29 2512.72 -2705.21 2785.25 -4709.14 4844.97 -5275.26 5427.42 -5666.10 5829.54 - 6058.12 62,52.87 -6070.29 6245.59 -6178.88 6561.17 -6275.20 6468.52 -6519.39 6525.65 -6557.59 6570.70 -6496.64 6757.84 -6695.12 7051.56 - 6875.19 7517.67 -6966.47 7452.58 -7908.10 8845.71 -7908.11 8845.72 Deg/lO0 0.00 1.50 1.50 3.00 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 9.00 9.00 9.00 9.00 9.00 1.00 0.00 1.00 0.00 0.00 PHILLIPS Alaska, Inc. CD#I 31 slot #31 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 31 Version#3 Our ref : prop3532 License : Date printed : 19-Jul-2000 Date created : il-Aug-1999 Last revised : 19-Jul-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 n70 20 32.803,w150 55 36.984 Slot Grid coordinates are N 5975692.709, E 385787.385 Slot local coordinates are 436.54 S 2363.88 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-10548'>,,19,CD$1 PMSS <2827 - l1956'>,,19A, CD#l PMSS <0-10897'>,,3,CD#1 PMSS <0-8350'>,,26PH1,CD#l PMSS <7755-11134'>,,26,CD~1 PGMS <0-10255'>,,WD2,CD#l PMSS <476 - 11190'>,,34,CD#1 PMSS <297 - 9882'>,,44PHl,CD#l PMSS <9081 - 12811'>,,44,CD#1 PMSS <0-11300'>,,13,CD~1 PMSS <384 - 14477'>,,23,CD#1 PMSS <832 - 12147'>,,25,CD#1 PMSS <763 - 7440'>,,36PH2,CD$l PMSS <6600 - 10654'>,,36,CD$1 PMSS <472 - 1545'>,,36PH1,CD#l PMSS <0-10224'>,,39PH1,CD#l PMSS <9146 - 13289'>,,39,CD#1 PMSS <7182 - 11170'>,,41,CD#1 PMSS <475 - 8166'>,,41PH1,CD$1 PMSS <0-10504'>,,5PH1,CD#i PMSS <9499 - 14515'>,,5,CD$1 PMSS <0-9357'>,,16PH1,CD#l PMSS <8393 - 12600'>,,16,CD#1 PMSS <0-7331'>,,1PH1,CD#l PMSS <5946 - 10289'>,,1,CD#1 PMSS <0-11608'>,,42,CD$1 PMSS <654 - 10956'>,,38PBl,CD#l PMSS <9876 - 12240'>,,38,CD#1 PMSS <9810 - 10796'>,,24,CD$1 PMSS <0-8844'>,,45PHl,CD#l PMSS <7950-11950'>,,45,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <0-11492'>,,27,CD#1 PM$S <0-9236'>,,22,CD#1 22 PMSS(0 - 9239'>DepthShifted,,22,CD#l PMSS <0-13308'>,,6PH,CD$1 PMSS <12550 - 16023'>,,6,CD#1 PMSS <10894 - 15350'>,,9,CD#1 PMSS <0-11934'>,,9PH,CD$1 PMSS <0-11067'>,,32PH1,CD#l PMSS <10016 - 11136'>,,32,CD#1 PMSS <0-8168'>,,35,CD#1 PMSS <0-12055'>,,40,CD#1 Closest approach with 3-D Last revised Distance 6-Apr-2000 117.4 30-Apr-2000 4-Jan-2000 6-Mar-2000 1-Nov-1999 28-Jun-1999 il-May-2000 23-May-2000 23-May-2000 15-Ju1-1999 3-May-2000 15-Mar-2000 4-Jan-2000 22-Dec-1999 4-Jan-2000 4-Jan-2000 22-Sep-1999 3-Apr-2000 26-Mar-2000 23-Jan-2000 23-Jan-2000 4-Jan-2000 25-0ct-1999 29-Feb-2000 27-Jun-1999 23-Dec-1999 13-Feb-2000 14-Feb-2000 14-Jun-2000 4-Jan-2000 16-Nov-1999 26-Aug-1999 16-Mar-2000 il-Jul-2000 il-Jul-2000 30-Jun-2000 il-Jul-2000 20-Jun-2000 14-Jul-2000 4-Jan-2000 7-Jun-2000 19-Jul-2000 17-Jul-2000 117.4 280.3 41.9 41.9 1221.8 29 4 129 7 129 7 170 2 80 4 53 1 49 6 49 6 49 6 79 5 79 5 99 2 99 2 259 4 259 4 150 5 150 5 300 1 300 1 109 5 69 1 69 1 67 1 139 4 139 4 59 6 18 3 80 6 80 6 244 2 244 2 208 2 208 2 .9 2 9 2 39 4 89 6 Minimum Distance method M.D. Diver~in~ from M.D. 566.7 566.7 300.0 657 1 657 1 757 1 200 0 100 0 100 0 833 3 100 0 671.4 100 0 100 0 100 0 100 0 100 0 100 0 100 0 314 3 314 3 100 0 100 0 200 0 200 0 100 0 200 0 200 0 577 8 200 0 200 0 0 0 642 9 844 4 844 4 742 9 742 9 742 9 742 9 314 3 314 3 100 0 100 0 566.7 566.7 300.0 657.1 657.1 757.1 8920.0 100.0 10093.8 833.3 500.0 671.4 2144.4 7660.0 1604.1 100.0 t00.0 8880.0 1388.9 314.3 314.3 100.0 100.0 200.0 200.0 9762.4 200.0 200.0 577.8 200.0 200.0 0.0 642.9 844.4 844.4 742.9 742.9 742.9 742.9 314.3 314.3 6580.0 100.0 25 2000 Anchora.qe PHILLIPS Alaska, Inc. CD#1 31 slot #31 Alpine Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : 31 Version#3 Our ref : prop3532 License : Date printed : 19-Jul-2000 Date created : il-Aug-1999 Last revised : 19-Jul-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 n70 20 32.803,w150 55 36.984 Slot Grid coordinates are N 5975692.709, E 385787.385 Slot local coordinates are 436.54 S 2363.88 E Projection type: 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 for 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 <0-10548'>,,19,CD#1 PMSS <2827 - l1956'>,,19A, CD~l PMSS <0-10897'>,,3,CD~1 PMSS <0-8350'>,,26PH1,CDgl PMSS <7755-11134'>,,26,CD#1 PGMS <0-10255'>,,WD2,CD#1 CD1-29 Version #2,,29,CD91 CD1-33 Version #4,,33,CD#1 CD1-28 Version #5,,28,CD~1 PMSS <476 - 11190'>,,34,CD#1 PMSS <297 - 9882'>,,44PH1,CD#l PMSS <9081 - 12811~>,,44,CD~1 PMSS <0-11300'>,,13,CD91 PMSS <384 - 14477'>,,23,CD#1 PMSS <832 - 12147'>,,25,CD91 PMSS <763 - 7440'>,,36PH2,CD#l PMSS <6600 - 10654'>,,36,CD#1 PMSS <472 - 1545'>,,36PHi,CD#1 PMSS <0-10224'>,,39PH1,CD#l PMSS <9146 - 13289'>,,39,CD91 PMSS <7182 - 11170'>,,41,CD#1 PMSS <475 - 8166'>,,41PH1,CD#l PMSS <0-10504'>,,5PH1,CD#l PMSS <9499 - 14515'>,,5,CD91 PMSS <0-9357'>,,16PHl,CD#l PMSS <8393 - 12600'>,,16,CD91 PMSS <0-7331'>,,1PH1,CD#l PMSS <5946 - 10289'>,,1,CD#1 PMSS <0-11608'>,,42,CD#1 PMSS <654 - 10956'>,,38PB1,CD#l PMSS <9876 - 12240'>,,38,CD#1 CD1-24 Version #5,,24,CD#1 PMSS <9810 - 10796'>,,24,CD91 PMSS <0-8844'>,,45PH1,CD#l PMSS <7950-11950'>,,45,CD#1 Closest approach with 3-D Last revised Distance 6-Apr-2000 30-Apr-2000 4-Jan-2000 6-Mar-2000 1-Nov-1999 28-Jun-1999 13-Jan-2000 il-Aug-1999 13-Jan-2000 il-May-2000 23-May-2000 23-May-2000 15-Ju1-1999 3-May-2000 15-Mar-2000 4-Jan-2000 22-Dec-1999 4-Jan-2000 4-Jan-2000 22-Sep-1999 3-Apr-2000 26-Mar-2000 23-Jan-2000 23-Jan-2000 4-Jan-2000 25-Oct-1999 29-Feb-2000 27-Jun-1999 23-Dec-1999 13-Feb-2000 14-Feb-2000 29-Jun-2000 14-Jun-2000 4-Jan-2000 t6-Nov-1999 )114.1( )114.1( )278.5( )38.0( )38.0( ) 1216.3 ( )17.2( )17.9( )26.2( )27.5( )128.9( )128.9( )165.7( 78.6( 48.6( 48.9( 48.9( 48.9( 78.2( 78.2( 97.7( 97.7( )257.6( )257.6( )149.6( )149.6( )299.0( )299.0( )99.6( )67.5( )67.5( )9117.8( )63.0( )138.4( )138.4( Minimum Distance method M.D. Diverging from M.D. 577.8 577.8 414.3 671.4 671.4 800.0 442.9 342.9 442.9 300 0 200 0 200 0 855 6 513 3 700 0 100 0 100 0 100 0 328 6 328 6 200 0 200 0 371.4 371.4 577.8 577.8 300.0 300.0 9793.7 200.0 200.0 1966.7 600.0 200.0 200.0 577.8 577.8 414.3 671.4 671.4 800.0 13364.6 342.9 1166.7 300.0 2500.0 10400.0 10960.0 11364.3 700.0 2222.2 8900.0 1604.1 328.6 328.6 9160.0 1444.4 10600.0 10600.0 13364.6 13364.6 300.0 8060.0 9793.7 200.0 200.0 1966.7 600.0 200.0 200.0 ,.JUL 2 $ 200'3 ,Anchorage PMSS <562 - 12134'>,,37,CD~1 PMSS <0-11492'>,,27,CD~1 PMSS <0-9236'>,,22,CD#1 22 Version~l,,22,CD~l 22 PMSS(0 - 9239'>DepthShifted,,22,CD~l CD1-2 Version ~6,,2,CD#1 CDi-10 Version ~3,,10,CD#1 CDi-15 Version ~2,,15,CD~1 CDi-17 Version #8,,17,CD~1 CD1-20 Version #3,,20,CD#1 CD1-21 Version #3,,21,CD#1 CD1-43 Version #11,,43,CD#1 PMSS <0-13308'>,,6PH,CD#l PMSS <12550 - 16023'>,,6,CD~1 PMSS <10894 - 15350'>,,9,CD#1 PMSS <0-11934'>,,9PH, CD#l CD1-30 Version #4,,30,CD~1 CD1-32 Version #6,,32,CD~1 PMSS <0-11067'>,,32PHl,CD~l PMSS <10016 - 11136'>,,32,CD#1 4 Version#ll,,4,CD#l 35 Ver$ion#6,,35,CD#1 PMSS <0-8168'>,,35,CD#1 PMSS <0-12055'>,,40,CD#1 26-Aug-1999 16-Mar-2000 11-Jul-2000 11-Jul-2000 11-Jul-2000 8-Aug-1999 10-Aug-1999 5-Apr-2000 19-Apr-2000 10-Aug-1999 10-Aug-1999 6-Jul-2000 30-Jun-2000 11-Jul-2000 20-Jun-2000 14-Jul-2000 11-Au~-1999 8-Jun-2000 4-Jan-2000 7-Jun-2000 17-Jul-2000 6-Jun-2000 19-Jul-2000 17-Jul-2000 )57.8( )14.3( )76.1( )5275.5( )76.1( )288.9( )208.5( )147.7 )123.2 )105.5 )90.9 )118.7 )240.2 )240.2 )203.2 )203.2 )7.5 )866.4 )7.5 )7.5 )268.8 )3017.8 )38.4( )88.8( 300.0 642.9 866.7 5100.0 866.7 314.3 414.3 822.2 877.8 526.7 628.6 300.0 757.1 757.1 757.1 757.1 414.3 13364.6 342.9 342.9 342.9 6920.0 200.0 200.0 300.0 642.9 10786.4 10450.0 10786.4 10344.6 414.3 822.2 877.8 13364.6 13364.6 7340.0 10260.0 10260.0 757.1 757.1 13364.6 13364.6 10387.9 11266.7 342.9 11500.0 6960.0 6200.0 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 20, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-31 Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well from the Alpine CD1 drilling pad. The intended spud date for this well is August 27, 2000. It is intended that Doyen Rig 19 be used to drill the well. CD1-31 will be drilled to penetrate the Alpine sand horizontally. 7" casing will then be run and cemented in place. A horizontal section will then be drilled and the well completed as an open hole injector. 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: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Proposed cementing program and calculations. 9. 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. Anchorage If you have any ques ~ons or require further information, please contact Chip Alvord at 265-6120. Sincerely, ~ Brian Robertson Senior Drilling Engineer Attachments cc: CD1-31 Well File / Sharon AIIsup Drake Chip Alvord Mike Erwin Gracie Stefanescu Lanston Chin ATO 1054 ATO 1030 ANO 384 Anadarko - Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com RECEIVED JUL 2 5 Alaska 0['; & Gas Cons. '~' Ancho~ge WELL PERMIT CHECKLIST COMPANY_~_~_,?/~.~,5" WELL NAMe/- ,:~j PROGRAM: exp dev redfll serv =~ wellbore sag ann. disposal para req FIELD & POOL /.~..(:3 ]<~q INIT~LA~S /'- ~-,..~',~,'7" GEOLAREA ~:>~,,--) UNIT# .~'O ,~'~,'~ ON/OFF SHORE ADMINISTRATION 1. Permit fee attached. I/ N 2. Lease number appropriate ................... N 3. Unique well name and.number .................. Y: N 4. Well located in a defined pool .................. Y' N 5. Well located proper distance from drilling unit boundary .... Y N 6. Well located proper distance from other wells .........., Y. N 7. Sufficient acreage available in drilling unit ............ t Y N 8. If deviated, is wellbore plat included ...............~ Y N 9. Operator only affected party ................... Y N 10. Operator has appropriate bond in force ............. Y~ N 11. Permit can be issued without conservation order ........ Y N ~R ~::~/L 12. Permit can be issued without administrative approval ...... Y. N ,:~~ 13. Can permit be approved before 15-day wait ........... ~/N ENGINEERING 14, CondUctor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg .....~NN~(~i~N 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... ¥ 22. Adequate wellbore separation proposed ............. N 23. If diverter required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... N ..... 25. BOPEs, do they meet regulation ................ N ~.cu~.~--~'~.~..~ &t~l~ DATE 26. BOPE press rating appropriate; test to ~%---'~--~ psig. N ~..~~ ~/c~,- 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. Y GEOLOGY 30. Permit can be issued wlo hydrogen sulfide measures ..... (~)N 31. Data presented on potential overpressure zones ....... Y N /~"~ ,,..3 32. Seismic analysis of shallow gas zones .......... . ".. Y R D E Seabed cOndition survey (if.off-shore) ...... , ...... ~"N - · · _ ~ ~/ _ 34. Contact name/phone for weekly progress reports [exploratory~ Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; ....... (~) N APPR DATE r (B) will not contaminate freshwater; or cause drilling waste .~ .. ~N ~.V~ $1E) [oo (C) will not impair mechanical integrity of the well used for disposal; ~ N (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. ~,,Y~ N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: c:~nsoffice\wordian\diana\checklist (rev. 02/17100) . .