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Home My WebLink About200-203MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3F-21 KUPARUK RIV UNIT 3F-21 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2023 3F-21 50-029-22991-00-00 200-203-0 W SPT 5848 2002030 1500 2842 2842 2842 2842 110 120 120 120 4YRTST P Brian Bixby 6/4/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3F-21 Inspection Date: Tubing OA Packer Depth 1240 2015 1990 1985IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230607081406 BBL Pumped:0.3 BBL Returned:0.3 Wednesday, July 26, 2023 Page 1 of 1           MEMORANDUM TO: Jim Regg P.I. Supervisor l / FROM: Guy Cook Petroleum Inspector Well Name KUPARUK RIV UNIT 3F-21 IInsp Num: mitGDC190608160936 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 12, 2019 SUBJECT: Mechanical Integrity Tests CONOCOPFIILLIPS ALASKA, INC. 3F-21 KUPARUK R1V UNIT 3F-21 Sre: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-22991-00-00 Inspector Name: Guy Cook Permit Number: 200-203-0 Inspection Date: 6/6/2019 Wednesday, June 12, 2019 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well? 3F-21 - T - - � YP J I W'TVD �T a In 5848 -Tubing nos - nae 2743 2743 " 'Type Test SPT ',Test psi 1500 IA 970 20301980 1980 - - BBL oe BBL Returned: 0 -' OA sao 650 � eso � osoInti - - 4YRTST P/F P ✓ Notes: Job was completed with a Little Red Services pump truck and calibrated gauges. Wednesday, June 12, 2019 Page I of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAY 0 9 2019 A e%!1 / a. 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ tdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Conductor Extension 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: , ConocoPhilli s AlaskaInc. p Development p ❑ Exploratory ❑ Stratigraphic ❑ Service Q 200-203 3. Address: 6. API Number: P.O.Box 100360, Anchorage, Alaska 99510 50-029-22991-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025632, ADL0025643 KRU 3F-21 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NA Ku aruk River/Ku aruk River Oil 11. Present Well Condition Summary: Total Depth measured 9147 feet Plugs measured 9072 feet true vertical 6272 feet Junk measured feet Effective Depth measured 9072 feet Packer measured feet true vertical 6233 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 47' 16" 78' 78' Surface 3999' 7.625" 4029' 3193' Intermediate 8377' 5.5" 8405' 5848' Production 742' 4.5" 9147' 6272' Liner Perforation depth Measured depth 8848 to 8888 feet 8910 to 8956 True Vertical depth 6112 to 6134 feet 6146 to 6171 Tubing (size, grade, measured and true vertical depth) 3.5", 180, 8424', 5860' Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: NA NA NA NA NA Subsequent to operation: NA NA NA NA NA 14. Attachments (required per 20 AAc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG Q GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-555 Authorized Name: Roger Winter Contact Name: Roger Winter/Roger Mouser Authorized Title: WI Field Supervi r Contact Email: N1927(&conocoohillios.com ( Authorized Si nature: v Date: 5/7/19 Contact Phone: 659-7506 rM 5-12-1 /19 Form 10404 Revised412017 �i /�� iBDMSL-0w MAY 0 9 2019 //�" % Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 7, 2019 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7h Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-404 Sundry from ConocoPhillips Alaska, Inc. well 317-21, PTD# 200-203, Sundry # 318-555 for conductor extension. Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincerely, Roger Winter ConocoPhillips Well Integrity Field Supervisor Summay of work 4/28/2019 Weld 10" of 16" .375 wall pipe to existing conductor. I 3F-2 �� ,copyright 2019. All rights reserve 4V e AOGCC with permission to copy fc1 .other purpose or by other party is i,V'nsent of ConocoPhillips Alaska, f -Y-t6graph-is.provi`dto Aa 'sed PzEying for ar'1W _pre 3F - 9W r "Copyright 2019. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by other party is prohibited without the express consent of ConocoPhillips Alaska, Inc." • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,January 06,2016 TO: Jim Regg P.I.Supervisor I e-f°t 14(/(z' SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F-21 FROM: Bob Noble KUPARUK RIV UNIT 3F-21 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprySE-4.--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F-21 API Well Number 50-029-22991-00-00 Inspector Name: Bob Noble Permit Number: 200-203-0 Inspection Date: 1/2/2016 Insp Num: mitRCN160103161526 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F-21 !Type Inj C' 'TVD 1 5848 ' 1 Tubing l 3690 . 3689 - 1 3686 - 3687 - PTD 2002030 ' Type Test SPT Test psi 1500 - IA 450 1800- 1760 - 1760 - Interval 14 TST P/F P ' OA 20 110 - los 1 105 _I L 1 — -- Notes: Wednesday,January 06,2016 Page 1 of 1 1<R(A 3-P_ 2( P Zvo zc)�v Regg, James B (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, June 22, 2015 2:12 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA);Wallace, Chris D (DOA) Subject: Kuparuk 3F pad SW MIT-IA's Attachments: MIT KRU 3F-PAD WAIVED SI 06-21-15.xls Jim, Attached are recently performed SW MIT-IA's on 3F pad (waived by Chuck Scheve). All wells were shut in at the time of testing. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 2 Pager(907) 659-7000 pgr. 123 SCANNED 111 0jj,f� 411WELLS TEAM ConocoPfJNips STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to pm regoaalaska gov AOGCC Inspectorspalaska gov phoebe brooksi alaska cloy chris wallacenalaska qov OPERATOR: ConocoPhillips Alaska,Inc FIELD/UNIT/PAD: Kuparuk/KRU/3F Pad J DATE: 06/21/15 t l (�2 z1�'� OPERATOR REP: Hight/Riley 1 / ` AOGCC REP: (Chuck Scheve waived) Packer Depth Pretest Initial 15 Min 30 Min 45 Min. 60 Min. Well 3F-03 Type In] N TVD • 5,701' Tubing 975 1,025 1,050 1,050 Interval 4 P T D 1852270 Type test P Test psi 1500 Casing 750 1,710 1,680 1,670 P/F P Notes: OA 40 40 40 40 Well-3F-15 Type Inj N TVD • 5,673' Tubing 1,950 1,950. 1,950 1,950 Interval 4 P T D 1852930 Type test P Test psi 1500 Casing 650 2,650 2,550 2,540 P/F P Notes: OA 280 320 320 320 Well•3F-16A Type In]. N • TVD 4,990' Tubing 1,700. 1,700 1,700 1,700 Interval 4 PTD, 1961510 Type test P Test psi 1500 Casing 210, 2,420 2,360 2,340 P/F P Notes: OA 80 80 80 80 Well,3F-20 • Type Ini• N TVD 5,781' Tubing 1,825 1,825 1,825 1,825 Interval 4 P T D 1990790 Type test P Test psi 1500 Casing 510 2,550 2,500 2,490 P/F P Notes: OA 200 220 220 220 Well 3F-21 Type In' N - TVD - 5,848' Tubing `1,450 -1,450 -1,450 '1,450 Interval 4 P T D 2002030 Type test P Test psi 1500 Casing 100 '2,210 - 2,140 " 2,130 P/F P Notes: OA 10 20 • 20 20 ' Well Type Ini - TVD Tubing Interval P.T D Type test Test psi CasingP/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Dolling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industnal Wastewater R=Internal Radioactive Tracer Survey V=Required by Vanance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU 3F-PAD WAIVED SI O6-21-15 V. Image Project Well History File Cover Page 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. -~-~D ~)~Well History File Identifier Organizing ~:.,~ [] RESCAN [] Color items: ,.q. Grayscale items: D Poor Quality Originals: [] Other: NOTES: TAL DATA Diskettes, No. I [] Other, No/Type B Y: BEVERLY ROBIN VINCENT SHERYOINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~INDY Scanning Preparation ~ x 30 = ~O BY: BEVERLY ROBIN VINCENT St--IERYL A~~WINDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds Other Production Scanning Stage I PAGE COUNT FROM SCANNED F~LE: Stage 2 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) _.~,~,_ YES NO PAGE COUNT MATCHES NUMBER iN SCANNING PREPARATION: .............. IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ............. YES ................. NO BE'VER~INOENT SHERYL MARIA WINDY DA'TE,;~--/:-~ 'S/~ RESCANNEDB~': BEVERLY ROBIN VINCENT SHERYI_ MARIA WINDY DATE: /si General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 07, 2011 TO: Jim Regg P.I. Supervisor q141f( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F-21 FROM: John Crisp KUPARUK RIV UNIT 3F-21 Petroleum Inspector Src: Inspector Reviewed By: Supry NON-CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3F-21 API Well Number: 50-029-22991-00-00 Inspector Name: John Crisp Insp Num: mi0Cr110605220440 Permit Number: 200-203-0 Inspection Date: 6/5/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. W I 3F-21 T ype 'pi. W TVD 5848 IA 350 2200 - 2160 2150 I p 2002030 ' SPT Test psi 1500 OA 190 400 , 400 400 Interval 4YRTST P/F P ' Tubing 2850 2850 2850 2850 Notes: 1.3 bbls pumped. No problems witnessed. $ tij JUN I 7 MI Tuesday, June 07, 2011 Page 1 of 1 5~,,t~~.e.~- -- Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~(~~ ~~ ~P La ~~~~ Well Job # Log Description N0.4445 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1 O/15/07 2N-343 (REDO) 11745232 MEM INJECTION PROFILE ` 'S C - '"` 08108107 1 1B-14 11837493 PRODUCTION PROFILE - ~ - 08/27/07 1 1A-18 11839651 PRODUCTION PROFILE Q- 08/30/07 1 1Y-18 11837499 PRODUCTION PROFILE 4~ - 08/30/07 1 1G-14 11839652 INJECTION PROFILE ~, ~j- ~ 08/31/07 1 1A-01 NIA USIT 08/31/07 1 1Y-04 11839653 INJECTION PROFILE fU ~ 09/01/07 1 1Y-32 11839655 PRODUCTION PROFILE '~ - 09/02/07 1 2T-TAB-01 11839656 INJECTION PROFILE C - - 09/03107 1 2K-25 11846439 INJECTION PROFILE (,J ~ ( - 09/06107 1 2K-18 11846440 INJECTION PROFILE / -! 09/07/07 1 16-18 11846441 PRODUCTION PROFILE ~ - (p 09/08/07 1 2T-20 11846442 PRODUCTION PROFILE 09/09/07 1 2N-310 11850433 SONIC SCANNER 7b'~-(~ 25 09116/07 1 2N-310 11850433 SONIC SCANNER-FMI ~ ~ - C~`~,1~ 09116107 1 1J-176 11846443 USIT "~ - 09117/07 1 1E-29 N/A UCI ~ - ~ 09/19/07 1 3F-21 11837503 RSTi WFL - 09/20!07 1 2B-10 11839661 INJECTION PROFILE L - 09122107 1 1G-05 11837506 INJECTION PROFILE vsC 09/23/07 1 2H-13 11839662 INJECTION PROFIL ~ - 09/23/07 1 1B-05 11837508 INJECTION PROFILE ~ `-"~ 09/24/07 1 3H-O8 11839663 PRODUCTION PROFILE - b 09/24-07 1 1Y-31 11839664 PRODUCTION PROFILE j ~` - 09125/07 1 1G-06 11839665 INJECTION PROFILE 09/26/07 1 2Z-01A 11837512 USIT - j j 09/27/07 1 2V-08A 11837511 ISOLATION SCANNER '~~ - 09/28/07 1 1G-11 11837513 PRODUCTION PROFILE - 09/29/07 1 1Y-22 11837515 PRODUCTION PROFILE - b 09/30/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • S .on!: rn_ 1. Operations Performed: Abandon D Repair Well D Plug Perforations 0 . Stimulate D Other Ancllii}age Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 200-203 1 " 3. Address: Stratigraphic D Service 0¿ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22991-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 3F-21 / 8. Property Des~gnation: 10. Field/Pool(s): ADL 25632 1 25643, ALK 2565 Kuparuk River Field 1 Kuparuk Oil Pool ~ 11. Present Well Condition Summary: Total Depth measured 9151' ,{ feet true vertical 6275' , feet Plugs (measured) 9072' Effective Depth measured 8984' feet Junk (measured) true vertical 6186' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 78' 16" 110' 110' SURF CASING 4000' 7-5/8" 4028' 3193' PROD CASING 8367' 5-1/2" 8389' 5838' PROD CASING 758' 4-1/2" 9147' 6273' Perforation depth: Measured depth: 8860' - 8888', 8910'-8956' MD true vertical depth: 6118'-6134', 6146'-6171' 5:;¡;V~NED SEP 1 9 ZOO7 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8421' MD. Packers & SSSV (type & measured depth) no packer Cameo 'OS' nipple @ 507' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 8848'-8868' Treatment descriptions including volumes used and final pressure: 50 bbls 15.8 Class G 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinn Pressure Tubino Pressure Prior to well operation na na 3828 ¿ -- Subsequent to operation na na 2900 ,/ -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory D Development D Service 0 Daily Report of Well Operations _X 16. Well Status after work: OilD GasD WAGD GINJD WINJ0 WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Group Engineer <=1-13-01 Signature ~,klfa__ Phone: 265-6471 Date - Prenarprl b" Sharon AII"un-Drake 263-4612 ,10. -ç¿'~ RBDM..f) BFt SEP 1 9 20 ~" /:fÞ 'f./(-D7 Form 1 1404 Revised 4/2006 Sub ri ina Only . . RECEIVED STATE OF ALASKA ,., ALASKA OIL AND GAS CONSERVATION COMMISSION )EP 142007 REPORT OF SUNDRY WELL OPERA TIONSaska Oil & Ga C ORIGINAL ~ \~ 7~¡~ DATE 6/29/07 7/2/07 7/3/07 7/8/07 7/10/07 7/11/07 7/12/07 7/13/07 7/14/07 7/17/07 7/20/07 7/21/07 8/5/07 8/6/07 8/6/07 8/11/07 . . 3F-21 Well Events Summary Summary GAUGED TBG T02.79". TAGGED @ 8962' RKB, EST. 6' RATHOLE. Pumped 4.90 bbl sand slurry (900 Ibs) with 2bbls of gel ahead follow by 3 bbls of gel behind and chasing slurry with 39 bbls of freshwater and 30 bbls slick diesel freeze protect.Attempt target TOS depth = 8868' RKB ( + / - 10' ).Left well shut in for slickline tag. TAG BOTTOM W/ 2.7" CENT & SAMPLE BAILER @ 8851'RKB. RAN 2.78" GAUGE RING FOR CORRECTION @ D NIPPLE @ 8343' SLM = 23' CORRECTION. RAN 2.33" GAUGE RING & TAGGED@ 8857' RKB. PUMPED 10 BBLS DIESEL DOWN TBG @ 11/4 BPM, 2100 PSI & TAGGED TOS @8871' RKB. TAG "D" NIPPLE AT 8366' RKB FOR +20' CORRECTION. TAG TOP OF SAND AT 8891' RKB. DUMP BAIL SAND TO 8880' RKB. RAN 2.8" GAUGE RING. TAG D NIPPLE @ 8345' SLM = 21' CORRECTION. TAGGED TOS @ 8885' RKB. JOB IN PROGRESS. DUMP BAILED SAND FROM 8887' RKB TO 8873' RKB. IN PROGRESS. TAGGED TOS W/ 2.7" CENT @ 8873' RKB. DUMPED CALCIUM CARBONATE FROM 8873' RKB TO 8869' RKB. JOB COMPLETE OPERATIONS FREEZE PROTECTED WELL IN A.M.; TAG AGAIN TO VERIFY TOS HASN'T DROPPED BELOW WINDOW. TAG TOS @ 8874' RKB. JOB COMPLETE. Performed 2 - 25 bbl cement squeezes. RIH circulated well over to sea-water, soft tagged sand plug @ 8895 CTMD flagged pipe. Picked up and started first cement stage as per procedure. Could not get Squeeze pressure to hold over 2100psi, start mixing second cement batch. RIH soft tag @ 8893' CTMD, P/U 20 ft and pump second stage of cement. Squeeze pressure would build to 2500 psi, with quick leak off time. Over 1 hour of pressuring up at slow rates max pressure able to sustain was 2600 psi, with 600 psi leak off over 20 min. Drop ball and pump BIO to contaminate cement, soft tag on sand plug @ 8895' CTMD, POOH with diesel chasing BIO to surface. TAGGED APPARENT CEMENT BRIDGE @ 5579' RKB. MILLED TBG FROM SURFACE TO 8500' CTMD (2.735" MILL) USING SLICK SEAWATER AND BIO SWEEPS, SLIGHT MOTOR WORK AT 5500' CTMD & 5740' CTMD. ATTEMPT TO PRESSURE TEST SQUEEZED PERFS WAS UNSUCCESSFUL. FOUND SAND TOP AT 8867' CTMD. WELL LEFT SHUT IN AND FREEZE PROTECTED. TAGGED SAND PLUG @ 8877' RKB (WINDOW TARGET: 8858 - 8878). MU and RIH w/2.20" ball drop nozzle,drifted with a 5/8" ball.Tag top of cement/sand plug @ 8868' ctmd,correct depth 8877' RKB puh 10 feet and flag pipe for depth control. Layed in a 24 bb115.8 ppg cement surry from 8867' RKB to safety and squeeze away a total of 8.3 bbls behind pipe before reaching 3000 psi squeeze pressure. Drop 5/8" ball and started pumping 1.5 ppb Biozan to contaminate cement after holding test for 1 hour. Contaminated cement down 8875' RKB washing tubing and jewelry while POOH. Left well shut and freeze protect with diesel for slickline to drift and tag and Little Red to perform a record leak off rate and pressure vs. time test. Job in Progress. GAUGED TBG TO 2.73" & TAG CEMENT PLUG @ 8872' RKB. MITT TO 1800# & 2000#. LOST 75# DURING EACH TEST. PASS. JOB COMPLETE. MU & RIH w/2.375" Underreamer Dressed for 4.5" 12.6# Casing to remove cement interface from 8872' RKB To estimated sand top @ 8880' RKB,MAX OD on underreamer =3.75".Run #2 MU & RIH w/2" JSN and tag hard fill @ 8881' RKB.Made several attemps to work through hard fill no luck. POOH freeze protect well to 2500'. MU & RIH WITH 2.70" JUNK MILL AND TAG TOP OF FILL @ 8876' ctmd 8872' RKB.MILL OUT CEMENT/ SAND INTERFACE FROM 8872' TO 8884' RKB.WORK MILL DOWN TO MIDDLE SET OF PERF @ 8925' RKB.POOH.RUN #2.MU & RIH WITH 2.5" OD JSN AND REMOVE SAND PLUG FROM 8925' RKB TO 8961' RKB EST 5' OF RAT HOLE WELL SHUT IN AND FREEZE PROTECTED FOR SLlCKLlNE TAG. . 3F-21 Well Events Summary . 8/12/07 TAGGED BOTTOM @ 8949' RKB. 7' OF FILL ABOVE BOTTOM PERFS @ 8956' RKB. RECOVERED SAMPLE OF SAND. JOB COMPLETE. 8/21/07 RIH WI 2.6 CENTI BAILER, TAG BTTM. @ 8945' RKB EST. 11' FILL. RIH WI 2.5"x 20' DUMMY TO BOTTOM, NO PROBLEMS. ****END JOB**** 9/1/07 FCO to Add perforations Tag fill @ 8944' CTM, Broke through 2 hard crust @ 8944' and 8956' CTM. Cleaned down to 9030' CTM. Well (Freeze Protected and left Shut In) 9/2/07 DRIFT TUBING WI 2.65" CENT & SAMPLE BAILER TO 8928' SLM. RECOVERED SAMPLE OF SAND WI FRAGMENTS OF CEMENT. 9/3/07 BROKE THRU BRIDGE @ 8930' SLM WI 2.5" DD BAILER. RAN 20' OF 2.5" DUMMY GUN DRIFT TO TAG @ 8984' SLM WI NO PROBLEMS. JOB COMPLETE 9/6/07 RAN DEPTH DETERMINATION AND TAGGED TD AT 9002'. ATTEMPTED TO SHOOT POWERSPIRAL GUN FROM 8936'-8956'. PRIMARY EXPLOSIVES FIRED, BUT ONLY TOP 6 INCHES OF DET-CORD IGNITED. RIH SAT DOWN IN INJ MANDREL AT 8322'. BELIEVE THAT PARTIAL DETONATION WAS DUE TO KNICKED DET-CORD FROM OVERPULLS PASSING THROUGH MANDREL AND JEWELRY. 9/7/07 PERFORATED FROM 8860'-8888' AND FROM 8910'-8956' WITH 2.5" HSD POWERJET 2506 6SPF CHARGES. . . ConocoPhillips Alaska, Inc. KRU 3F-21 API: 500292299100 Well Type: INJ Anole éa) TS: 53 deo éa) 8584 SSSV Type: Nipple Orig 1/19/2001 Angle @ TD: 58 deg @ 9151 Completion: Annular Fluid: Diesel/SW Last w/o: Rev Reason: TAG BOTTOM NIP (507-508. Reference Loo: Ref Loo Date: Last UDdate: 9/5/20Œ OD:3.5OO) Last Tao: 8984' SLM TD: 9151 ftKB TUBING (0-8421. _Date: 9/3/20Œ Max Hole Anole: 58 deo (â) 9151 OD:3.5oo. ID:2.992) DescriDtion Size Too Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 78 78 62.58 H-40 SURF CASING 7.625 0 4028 3193 29.60 L-80 BTCM PROD CASING 5.500 0 8389 5838 15.50 L-80 BTC MOD PROD CASING 4.500 8389 9147 6273 12.60 L-80 IBTM Injection I Size I Too I Bottom I TVD I Wt I Grade I Thread I ,ndrel/Dummy 1 3.500 1 0 1 8421 I 5858 1 9.30 1 L-80 1 EUE 8rd MOD I Valve 1 (8322-8323. SPF Date Tvoe OD:4.725) Interval TVD Zone Status Ft Comment 8848 - 8868 6111- 6123 A-3 C 20 0 8/5/20Œ Saz 8868 - 8888 6123- 6134 A-3 20 4 5/1 0/200 1 IPERF 2.5" HSD DP 60 & 120 deg Iph 8910- 8956 6146 - 6171 A-2 46 4 5/11/2001 IPERF 2.5" HSD DP 60 & 120 deg Iph NIP I Interval I Date I TVDe I Comment I (8366-8367, 8848 - 8868 8/5/20Œ A-3 SAND I OD:3.5OO) 1<:"""":::<:7<: PROD CASING St I MD I TVD I Man Mfr Man Type I V Mfr I V Type I V OD I Latch I Port I TRO I Date Run I C~~t (0-8389, OD:5.5oo, Wt:15.50) I 1 1 83221 57971 CAMCO KBG-2-9 1 CAMCO 1 DMY I 1.0 I BTM I 0.000 I 0 I 2/3/2001 I I Depth TVD TYDe Description ID 507 507 NIP Camco 'DS' Nipple 2.812 8366 5824 NIP Cameo 'D' Nipple w/2.75" No-Go Profile 2.750 SEAL 8404 5848 SEAL Baker 80-40 GBH-22 Seal Assemblv 3.000 (8404-8405. 9072 6233 PLUG BAKER E-Z DRILL PLUG 0.000 OD:4.0oo) 9145 6272 SHOE Weatherford Float Shoe 0.000 PROD CASING (8389-9147. OD:4.5OO. Wt:12.60) A-3 SAND .- SQUEEZE .... (8848-8868) f- Perf f- (8848-8888) - - __m ...-...... - - - - Perf (8910-8956) - - - - - - - - - - - - PLUG X (9072-9073. OD:3.958) SHOE (9145-9146, OD:4.5OO) .... .... MElVIORANDUlVI . State of Alaska . \Iaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor /! \/ skci.)7 1\((1>'1 0\1'1': rUèSda\ JUlle!ê2007 SLB.JECT: \1cchalllcal Integflt\ [",b CO~<OCOPHl [, LIPS~.L\SK-\ .'t·',,-I o 0 - d..t/3 ~. FROM: John Crisp Petroleum Inspeetor KLJPARUK RIV UNIT 3F-21 Sre: Inspector Reviewed Bv: P.I. Suprv5§,lZ---- Comm NON-CONFIDENTIAL Permit Number: 200-203-0 Inspector Name: John Crisp Inspection Date: 6/8/2007 Well Name: KUPARUK RIV UNIT 3F-2I Insp N urn: mitJCr070612l23656 ReI Insp Num: API Well Number: 50-029-22991-00-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~--~-1----~--~-'----'-- ,---·----¡---------_--~---·-I~--·~----·,---------··-··--,-··---.---..------¡-~-----.,--.-----------r-----.--___r___--.~.-..- Well i 3F-2l JType Inj. ¡ W I TVD i 5848 ¡ fA I 860 2980, 2960 : 2960, : lI.D:200~3~IType!~~~~r~Test p~l~ 1500_--=1 O~-T ·_~o_ 68~---___6;0-_---670--j-_-_-_==_~-_~-~-~ ~~aL 4YRTS~_ J>/F___~____~_Tubing..L_]930~ 1927_ ___~27_..J~927__~___!____ Notes: 1.4 bbl's pumped for test. SCANNED JUN 2 1 2007 Tuesday, June 12,2007 Page I of I . ~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 2, 2006 SCANNED SEP 082006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: 1-\... ~O 3 ;)vf)v ,? Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on August 14,2006 and is reported as follows. Sch1umberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 21-29, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043"i{you have any questions. f' / Sincerely, /~ //7 /1' //ß),(, // "/ IX'~.·~ /~ f J ·vV'V' ~# i ',.' / 'I M.J .love1and ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Initial Top Cement Final Top Sealant Well Name PTO # of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date . ;~f..ø:1 '. . . ··18ßív22&, .'. .', '21~' f NA . . . . ,.'\IM'.. . . : ····70;$/· ',' .8{~~ft2Q~l~.. . 3F-02 1 85-226 24' 7.0 8/1 4/2006 7.5 8/21 /2006 ..' ~~,.Q3 " :' ;,tafif~ì2'1.·· .... .... o .13~:4". '. f·.···· y2..3. . .:' I ~Wf~/2QØQ :.... > . .t1.~; '. "~812M~Q~~ 3F-04 ~ 80' 22.7 1 0' 8" 8/14/2006 38.2 8/21 /2006 ~ ~ f··..: 5.1' . .... '. . '.. " , . '8/if:i4/2:ÔÔ6; :. . 1;5· .. .' '8Æ1'lêØð:~F . '. 3F-06 185-244 Did not modify .3F~0¡7 : . . '. . '''j'35?Z45'' . . ': i[Ã,' . . 6.6 8/1:412.Q06 '" 7~5 . . .... 8/21/2f10i>· 3F-08 1 85-246 1 1 '4" 2.6 8/1 4/2006 6.6 8/21/2006 3F;Ø~ . . I t85f~O . Did not modify I· . 1:> " '. 3F-1 0 1 85-271 SF NA NA 6.6 8/21 /2006 '3f":U~ ""tá5~21~ '-,( ..... '.: :SF·. . NA. . N~.L . " ... 1.7 ~123}2.Ø;QQ; ,,~ ~-12 ~ 7'4" 1 .8 8/1 4/2006 6.2 8/23/2006 I" NA··· - 1- ·.···21"·· .' I '. :< A3/2~Î~OdØ - ~ 1 85-292 Did not "JUl 'Y ...·...-:1'~J~[r·é .$ 2A: I;. . .'. . . a'/'tlfI2Ç,taf)(' . '.- .. 812::t/ZØOß '. . 3F-1 6 1 ~ 6" NA NA 2.7 8/23/2006 :aEi11 r '.11'" .., . " 3.1 . I . 'àf1~12QQß: .: I .... 8. 812~J2(jt1E} > 3F-1 8 1 96-1 1 2 4' NA NA 28 8/23/2006 a~~;f:9,' <2Ð'¥í~6':i~~; f~;- .~:'. . . . NA I 8" . . .NA' _... L 2--, '. .â'f2'f)IŽØU6... 3F-20 199-079 36" NA NA 17.7 8/23/2006 3F~Z;t:·.. " .~: .2QOfîÔ3 . . "45"-. .' NA . . . 'NA .' . '. 3.1 .. 8/21ì21)'ð6 . MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg ·Y"t.t !llq,\O'S P.I. Supervisor 14 \ DATE: Monday, October 24, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F-21 KUPARUK RIV UNIT 3F-21 aoo/~D3 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: ~~ P.I. Suprv . _.J~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3F-21 Insp Num: mitCS051018075046 Rei Insp Num API Well Number 50-029-22991-00-00 Permit Number: 200-203-0 Inspector Name: Chuck Scheve Inspection Date: 10/17/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3F-21 Type Inj. w I TVD 5848 IA 1050 2010 1980 1980 TypeTest SPT Test psi --- P.T. 2002030 1462 OA 460 580 580 580 Interval 4YRTST P/F P Tubing I 2350 2350 2350 2350 Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. 5ÇANNEt) NO\~ 1. 7 2005 Monday, October 24,2005 Page I of 1 RE: MITs Due ) ') Jim, Thanks for the reminder. I appreciate your help in working together on compliance, much preferred over the alternative. We actually have 12 more MITIAs on our 2005 MITIA list. 3F-20 and 3F-21 are among those 12 wells. We've been scheduling this year's MITIAs between our diagnostic testing, waiver compliance testing, pre-rig testing, and repair work this summer and are about 90% complete so far. These last few tests might have been completed already, but the inspectors have been very busy this summer with meter proving and other high priority work, so we've also been working with their busy schedule per their request. I'm not sure when we'll be able to schedule these last few tests, it should only be 1 or 2 days of testing. It has been our understanding that the tests can be completed anytime within the calendar year in which they come due. While we have until Dec 31 to complete these tests, we prefer to complete them in the summer as winter testing is less efficient. I will attempt to schedule them before I leave on 10/19. We are currently in the middle of repairing the near surface, surface casing leaks on 3F-18 and 3F-17, so I'm unable to commit to a date for MITIAs at this time. Thanks, Marie McConnell Problem Well Supervisor 659-7224 -----Original Message----- From: J ame s Regg [~~.9.:.~.}:.t...?..~.j}.~_~.~.9.9.~?.?...9.~.~..~...:...~.~:.9.:..~:..~...:...9~...:...~!.?.] Sent: Wednesday, October 05, 2005 4:24 PM To: NSK Problem Well Supv Cc: Tom Maunder Subject: MITs Due ~^NNEU NO\! 1 7 2005 The Commission's records show MITs are due on the following wells: KRU 3F-20 (PTD 1990790) - last MIT 1/14/2001 ~KRU 3F-21 (PTD 2002030) - last MIT 7/21/2001 Please schedule MITs and provide at least 24 hrs advance notice for inspector witness. I'd appreciate confirmation of your scheduling by next Monday, 10/10/2005. Jim Regg AOGCC 1 of 1 10/13/2005 4:05 PM MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well 1 ÐY !5~2P-447 ~ ~ 2P-447 181""lb 1A-06 j2ðb..z'3J 3F-21 ~Gf.. T:tf> 1 H-05A SIGb Job # 10709677 10696820 10942812 10942813 10687716 USIT USIT INJECTION PROFILE INJECTION PROFILE MDT Log Description Date 12/30/04 ~ð2~~:(JÞ$ -7-Lf ~ L 'J;~'~r Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 NO. 3297 Company: Field: Kuparuk BL Color 12/24/03 01/07104 12/21/04 01/07/04 12/13/04 'F' A "a (' 1"\¿I'ì \\ ~ ~F fl.ïÜNEO ArK ~ ð uu,j î;J\J..n~~~ 1 1 1 1 1 DATE: If3f~ Please sign and retur one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ CD 1 ../ .........-' Permit to Drill 2002030 MD 9151 ~ TVD DATA SUBMITTAL COMPLIANCE REPORT 61212003 Well Name/No. KUPARUK RIV UNIT 3F-21 Operator CONOCOPHILLIPS ALASKA INC 6275 ," Completion Dat 5/10/2001 ~ Completion Statu WAGIN Current Status WAGIN APl No. 50-029-22991-00-00 UIC Y ~ REQUIRED INFORMATION Mud Log No Sample N._g.o Directional Survey ~ /Z.~. DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fret Log Log Run Name Scale Media No Interval Start Stop ED D~-- Ver LIS Verification · .,,~'"~-C -CW~'S~e Notes 1 ~Survey FINAL ,l~r~ional Survey FINAL CBL 5 FINAL Cement Bond Log2..2~,.25 FINAL CBL ~ 5 FINAL P,.Ems~ure Survey PSP 5 FINAL Press/Temp ~l~ction Profile 5 FINAL ~.~/ater flow Log [P-,.~T~ 5 FINAL 1 108 8250 8225 8250 8292 8775 8650 108 9097 8626 9070 8626 9030 9020 8850 9151 (data taken from Logs Podion of Master Well Data Maint) OH / Dataset CH Received Number Comments Open 1/3/2002 ~16 2/23/2001 Dir Survey Digital Data 2/23/2001 Dir Sruvey Paper Copy ch 3/16/2001 8250-8626 Color Print CH 5/1/2001 8225-9070 Color Print ch 3/16/2001 8250-8626 Color Print ch 6/1/2001 8292-9030 BL, Sepia CH 8/21/2001 8775-9020 BL, Sepia CH 8/21/2001 8650-8850 BL, Sepia ~ 10/30/2002 ,-1'1~53 Digital data: Rate of ~) I+ penetration, Dual Gamma Ray, Electormagnetic wave Resistivity Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y/~ Chips Received? ~ Analysis R P.c.~.iv~.d ? Daily History Received? Formation Tops ~)/N ~)/N Permit to Drill 2002030 MD 9151 Comments: 'I-VD DATA SUBMITTAL COMPLIANCE REPORT 61212003 Well Name/No. KUPARUK RIV UNIT 3F-21 Operator CONOCOPHILLIPS ALASKA INC 6275 Completion Dat 5/10/2001 Completion Statu WAGIN Current Status WAGIN APl No. 50-029-2299~1-00-00 UIC Y Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To: State of Alaska October 30, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation iLogs 3F-21, AK-MM-00345 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention oi~ Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3F-21: Digital Log Images 50-029-22991-00 1 CD Rom 01/17/02 Schlumkerger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1732 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color 2P-438 21276 DSI OH EDIT 05/28/01 1 2P-438 21276 DSI 05/28/01 I 1 2P-438 21276 DSl TVD 05/28/01 I 1 lC-131 STATIC BOTTOM HOLE SURVEY 12/15/01 I 1 1H-16 (REDO) PRODUCTION PROFILE W/DEFT 11/21/01 I 1 2N-348 JEWELRY LOG 12/09/01 I 1 2Z-07 LEAK DETECTION 12/21/01 I 1 ~3B-11 PRODUCTION PROFILE W/DEFT 12/11/01 I 1 3F-21 RST WATERFLOW LOG 12/10/01 I 1 3K-19 RST WATER FLOW LOG 12/09/01 I 1 3K-19 INJECTION PROFILE 12/09/01 I 1 DATE: RECEIVED JAN 2 5 2002 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8 WELL LOG TRANSM1TYAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska December 18, 2001 RE: MWD Formation Evaluation Logs 3F-21, AK-MM-00345 1 LDWG formatted Disc with verification listing. API#: 50-029-22991-00 PLEASE ACKNOWLEi}GE RECEIPT BY SIGNING. ANI) RETURNING A COpY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: RECEIVED Signed: 8/17/2001 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1382 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color ID-129 I C~"/~ 15 PRESSITEMPIGRADISURVEY 08108101 2M-15 /~/- ~..~_,~ PRODUCTION PROFILE 08106101 2Z-29 ,/?~,_/~r PRODUCTION PROFILE 08/03/01 3F-21 -~FY3-~-~ 7).'~ INJECTION PROFILE 08107/01 3F-21 WATER FLOW LOG 08/07/0t DATE: RECEIVED AUG 2 i 200i Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8~1~!B C01l$. Commmsion 5/30/2001 Schlumberger SchlUmberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1178 ComPany: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 AnchOrage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1B-01 1<~'O-/_~5~3 LEAK DETECTION LOG 05116/01 1 1 1B-01 J/ LEAK DETECTION LOG 05118101 I 1 1B-11 I~/-I.?~ LEAK DETECTION LOG 051t7./01 I 1 1 D-121 J c]"'/-I~! TEMPIPRESSIDENSITY SURVEY 05119101 I 1 1 D-135 c~OD-O~ ~ TEMPIPRESSIDENSITY SURVEY 051t9101 I t 2A-13 f~x:~.../~z/ LEAK DETECTION LOG 051t4101 3F-21 ~,~O-~'~ PRESSURE SURVEY 05111/01 I 1 1D-32~O~)-f ~, :~ 21224 SCMT 04124/0t 2A-15/~K'~- lC/(~ 21223 USIT 04123/01 1 2 P -417,~/'~/...~-~:~c~ 21243 FRACADE ADVISOR 05112/01 1 '"- -CEiVi D JUN01 2001 A~ska Oil & Gas Cons. C0mmbeion Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 661-8317. Thank you. ,ZlLilChOf~e STATE OF ALASKA (,,' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil E] Gas E] Suspended E] Abandoned r-] service [~1 WAMI Injector 2. Name of Operator .... . _,p,~.~l~;~._ ,. 7. Permit Number Phillips Alaska, Inc. ~.-..'~'~'~,~.%~'_ ....... ~ i · 200-203 3. Address ,~'~ ' 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 .'",.~.,.~~: , 50-029-22991-00 99' FNL, 185' FWL, Sec. 29, T12N, R9E, UM (ASP: 508685, 5985725) ~ Kuparuk River Unit At Top Producing Interval :i ~-',/~'~ - C_3/ 10. Well Number 308' FSL, 1336' FWL, Sec. 17, T12N, R9E, UM (ASP: 509808, 5991414) :l.'r..~.;'t":""";~;~ ~ 3F-21 At Total Depth ,~ ,..~./¢/_~__. i', 11. Field and Pool 560' FSL, 1392' FWL, Sec. 17, T12N, R9E, UM (ASP:509863, 5991666) ~,.,,.,~. ................ Kuparuk River Field 5. Elevation in feet (Indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 28 feetI ADL 25632 / 25643, ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if ollshore 16. No. o! Completions January 2, 2001 January 14, 2001 January 19, 2001I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 9151' MD/6275'TVD 9082' MD/6239'TVD YES [~] No DI N/A feet MD 1556' 22. Type Electric or Other Logs Run GR/Res/PWD, SCMT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE V~rl'. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 110' 24" 234 sxAS 1 7.625" 29.7# L-80 Surface 4040' 9.875" 310 sx AS III LW, 360 sx LiteCRETE 5.5" 15.5# L-80 Surface 8400' 6.75" 240 sx Class G 4.5" 12.6# L-80 8400' 9151' 6.75" included above 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD Interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 8422' N/A 8848'-8888' MD 6112'-6134' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8910'-8956' MD 6146'-6171' TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lilt, etc.) Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Pedod > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press, psi 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of o11, gas or water. Submit core chips. .,^ crc rc ,'?daska git ~,,. 6'as (;r~l~,s. '"' ' ~uoram~ss'°~'~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit In duplicate SENT BY' Date Comment -5-22-i ; 1'40PM · PHILLIPS AK, INC--,. (" 3F-21 Event History 907 276 7542;# 1/ 1 05/11/01 05/10/01 MADE FIRST 3 OF 4 PERFORATING RUNS, FINAL RUN TOMMOROW MORNING. PERFORATED: 8868'-8888' AND 8910'-8956', 4 SPF DEEP PENT. FIRST 3 OF 4 PERF RUNS. Post-it; Fax Note~ :, 7671 o-are ~]) ll~a~los~ , _ ,, , .~., ORIGINAL Page 1 of 1 5~2~1 3114101 Schlumberger NO. 1061 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print !3F-21 21102 SCMT 02/22/01 2 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317.'TIT~ifik ~/ou. 4/25/2001 Schlumberger NO. T84 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1D-40A ?c,/5-1c~O ~' PRESSURE SURVEY 04/11101 1Y-22 j ~ .~- ~-~ PROD PROFILEIGLS 04/10/01 3F-21 ~-~.C~ 21146 SCMT 03/05101 Ala a Oil &_Gas C0.s. Commiakm Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317, PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 April 18, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 3F-21 (200-203) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kuparuk well 3F-21. If you have any questions regarding this matter, please contact me at 265-6434 or Mark Chambers at 265-1319. Silcerely,~ __ J. Trantham Drilling Engineering Supervisor PA1 Drilling JT/skad AP/~ ~ 8 200/ ~qGna, s' Cons. C°n'~rnission · ' cnOrage ORIGINAL STATE OF ALASKA i( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OF:{ RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r-I Gas E! Suspended E] Abandoned E] Service [] WAMI Injector 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 200-203 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22991-00 4. Location of well at surface 9. Unit or Lease Name 99' FNL, 185' FWL, Sec. 29, T12N, RgE, UM (ASP: 508685, 5985725) ~' ":":: :' '" .... ': Kuparuk River Unit At Top Producing Interval ~:; '.'~ "--.'~'.-.'.i 10. Well Number , 308' FSL, 1336' FWL, Sec. 17, T12N, R9E, UM (ASP: 509808, 5991414) , 3F-21 ~-~r~ ~ ;-' '. ':::...~ At Total Depth ~ ~ 11. Field and Pool 560' FSL, 1392' FWL, Sec. 17, T12N, R9E, UM (ASP:509863, 5991666) '; ......................... ! Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 28 feetI ADL 25632 / 25643, ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if otlshore 16. No. ot Completions I January 2, 2001 January 14, 2001 January 19, 2001 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 9151' MD / 6275' TVD 9082' MD / 6239' TVD YES ['~ No E]I N/A feet MD 1556' 22. Type Electric or Other Logs Run GR/Res/PWD, SCMT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 110' 24" 234 sx AS 1 7.625" 29.7# L-80 Surface 4040' 9.875" 310 sx AS III LW, 360 sx LiteCRETE 5.5" 15.5# L-80 Surface 8400' 6.75" 240 sx Class G 4.5" 12.6# L-80 8400' 9151' 6.75" included above 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 8422' N/A None 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.) Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Pedod > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press, psi 24-Hour Rate > 28. CORE DATA Brief description of Ilthology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. /0.-9r~'7 ,~' "-'" '. APR 1 8 i~O0t ~C '~7_ -('~/ .,"N~ .Alaska Oil & Gas Cons. Co,mrdssior: ,/Y¢,~ Anchorage 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 recoverecl and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8584' 5957' Base Kuparuk C 8673' 6010' Top Kuparuk A 8817' 6094' Base Kuparuk A 9043' 6218' Annulus left open - freeze protected with diesel. 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 Mark Chambers 265-1319 1' Slgne~?. (~~~~ Title Dflllln,q En,qlneer n,q Supervisor Date James Tranthan Prepared by Sharon AIIsup-Dral(e INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1; Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5; Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24.' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21; Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23-' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28.' If no cores taken, indicate "none". Form 10-407 Operations Summary 3F-21 ~i Rpt No 12/31/00 1/1/01 1/1/01 1/1/01 1/1/01 1/1/01 01/02/01 01/02/01 01/02/01 01/02/01 01/02/01 01/02/01 01/02/01 1/3/01 1/3/01 1/3/01 1/3/01 1/3/01 1/3/01 1/4/01 1/4/01 1/4/01 1/5/01 1/5/01 1/5/01 1/5/01 1/5/01 1/5/01 1/5/01 1/5/01 1/6/01 1/6/01 1/6/01 1/6/01 1/6/01 1/6/01 1/6/01 1/6/01 1/6/01 1/7/01 1/7/01 1/7/01 1/7/01 Comments Trun key rig move f/lA pad to 3F pad 10.5 miles. Move camp ahead of rig. Rig @ CPF 3 at midnight. Continue trun key rig move F/CPF 3 to 3F pad. On location @ 02:00 AM. Back over well 3F-21. Accept rig for operation @ 0230 hrs 01/01/01 Berm up around cellar. Plywood walkway. Spot Baroid & Sperry-sun houses. Spot solid van. Work on diverter system. Load pipe shed w/DP. Change out drip pan under rotary. Take on 290 bbl's spud mud. Install riser. Load HWDP & BHA M/U and stand back 3.5" DP ( total 42 stands) Continue picking up & stand back dp-hwdp & 6 1/4" dc,s. Make up bit & bha #1-orientate & upload mwd. Test diverter system. Fill hole-check for leaks-Pre spud meeting. Drlg. from 108 to 163'. Repair grabber on top drive-loose piston belts. Drlg. & surveys from 163' to 902'. Drlg. & surveys from 902' to 2048'. Circ. hole clean for wiper trip-appeared to attempt a sidetrack while working pipe. Drilling from 2048' to 2145'. CBU. POH to bit-hole swabbing-pump out. Clean stabs & bit-down load mwd. Service top drive. RIH-wash 90' to bottom @ 2145'. Drlg. & surveys from 2145' to 3467'. Drlg. & surveys from 3467' to 4040' TD. (1 Accident) Dave Beaty pinched 2 fingers on right hand between tongs & pipe. Dr. checked out same-he is back working. Circ. bottoms up-work pipe. Wiper trip to 1800' & back to bottom. Circ.-condition hole for running 7 5/8" csg. POH to bha. Lay down bha #1. Drain stack & fish stripping rubber out of same. Finish lay down mud motor-down load mwd. Finish down load & lay down remainder of BHA. Clear floor & rig up to run 7 5/8" csg. PJSM-Run 94 jts. 7 5/8" 29.7# L-80 Buttress modified cs.-Hanger & landing jr.-Land same @ 4028'. Rig down fill up tool-rig up cement head & circ. hole clean-condition mud for cementing while waiting on dirty vac-(temp-35 deg.) PJSM-Test lines to 3000#-mix & pump 20 bbls. CW 100 preflush-40 bbls. mud push @ 10.5# & cement as per program @ 6 bpm. Pump down plug w/rig pump @ 6 bpm-bump plug on calculated strokes wi 1200#-check floats- OK. Flush stack w/water-lay down landing jr. & cement head. N/D diverter & riser. Install & orient csg. head & orient csg. valve-n/u tbg. head. Nipple up Tbg. head-remove annulus valve & install blind flange. N/U 11" bope-test csg. head seal to 1000#. Change out drip pan flange-Function test bope. Test bope to 250-3000#. Operations Summary 3F-21 1/7/01 1/7/01 1/7/01 1/8/01 1/8/01 1/8/01 1/8/01 1/8/01 1/8/01 1/8/01 1/9/01 Set wear ring. RIH picking up singles off pipe rack. Secure rig-convoy in for crew change-Phase 3 conditions. Changing out crews on convoy-Phase 3 conditions-winds gust to 45 mph. PJSM=POH w/3.5" dp & stand back-move pipe in derrick. Make up bha #3 & up load sperry equipment. RIH to 3917'. Slip & cut drlg. line. CBU to warm hole & mud. Secure well-shut down rig activities due to Phase 3 conditions.(No rig support possible.) Continue to clean out cement F/3945' to 4014' 1/9/O 1 1/9/01 1/9/O 1 1/9/O 1 1/9/01 1/9/01 1/9/01 1/9/01 1/9/O 1 1/9/01 1/9/01 1/9/01 1/9/01 1/9/01 1/9/01 1/10/01 1/10/01 1/10/01 1/10/01 1/10/01 1/10/01 1/11/01 1/12/01 1/12/01 1/12/01 1/12/01 1/13/01 1/13/O 1 CBU @ 80 SPM 1150 psi Test 7 5/8" casing to 3000 psi. C/O cement f/7 5/8" casing to 4028'. C/O Cement f/9 7/8" hole to 4040'. Drlg 6" new hole f/ 4040' to 4080'. CBU @ 100 SPM 1500 psi. LOT EMW 12.9 ppg DIr f/4040' to 4110' Change out mud system to Drill-N Drlg 6 3/4" hole f/4110' to 4401' MWD logging tool failed. POOH to 7 5/8" csg shoe @ 4028' Service rig. Monitor well. Blow down top drive. POOH Clean bit Drain mud motor Inspect bit Down load MWD RIH Test MWD RIH to shoe. @ 4028' Replace Glycol pump.( Baylar brake cooling) Mad pass f/4040' to 4401' Continue drlg 6 3/4" hole f/4401' to 4533' Continue drictional drill 6 3/4" hole F/4533' to 5284' MD 3961' TVD. Lost pulsar on MWD tool. Rotary wt 71 k Rotating up wt 72k Rotating down wt 70k. 70 RPM torque 3300 ft/Ib. Max ECD 10.57 ppg. CBU Blow down POOH Hole in good condition. Clean stablizers & bit O.K. Flush mud motor. Down load MWD. Change out Pulsar & up load. RIH w/BHA. Test mwd. Blow top drive. RIH Fill pipe & test mwd @ Shoe 4028'. Continue RIH to 5284' Hole in good condition. Drlg f/5284' to 5436' Continue directional drilling 6 3/4" hole F/5436' to 6520' MD 4718' TVD. Pump sweeps every 250 to 300' and as needed for bit bailing. Maximum ECD last 24 hrs 10.24 ppg. Continue to maintain angle @ 53 deg and drlg 6 3/4" hole F 6520' to 7503' MD 5298' TVD. Pumping sweeps every 250 to 300' Maximum ECD 11.08 ppg on a sweep. While drilling running 10.2 to 10.3 ppg. Hole looks good. Pump sweep rotate & reciporcate CBU for short trip. Made wiper trip to 5275'. Service top drive. RIH to 7407' Made up top drive washed to 7503'. Hole in good condition. Continue drlg 6 3/4" hole F/7503' Started increasing mud weight f/9.2+ to 10.5 ppg while drilling ahead, to 7636' MD 5379' TVD Continue drilling 6 3/4" hole f/7636' Maintaining 53 deg angle. While increasing mud weight to 10.5 ppg. to 8375' MD 5830' TVD. Maximum ECD while drilling 11.46 ppg Pump sweep rotate reciporcate. Clean hole to make a FIT. Maximum ECD of 12.0 ppg While pumping out sweep. Operations Summary 3F-21 i"' 1/13/01 1/13/01 1/14/01 1/14/01 1/14/01 1/14/01 1/14/01 1/15/01 1/15/01 1/15/O 1 1/15/01 1/15/01 1/15/01 1/15/01 1/16/01 1/16/01 1/16/01 1/16/O 1 1/16/01 1/16/01 1/16/01 1/16/01 1/16/01 1/17/01 1/17/01 1/17/01 1/17/01 1/17/01 1/17/01 1/17/01 1/17/01 1/17/01 1/17/01 1/18/01 1/18/01 1/18/01 1/18/01 1/18/01 FIT test at 4080' MD 3195' TVD original LOT. Mud weight 10.5 ppg slowly increase surface pressure to 390 psi. Hole pressure after 5 min 370 psi. For 12.73 ppg EMW and 11.7 ppg EMW @ 8375' MD 5830' TVD. Continue drilling 6 3/4" hole f/8375' to 8666' MD 6008' TVD. Continue drilling 6 3/4" hole F/8666' to 9151' MD TD 6274' TVD. Had gas cut mud @ 8911' Incressed mud weight f/10.5 to 10.8 ppg. Continue getting lite gas on connections. Increassed mud weight to 11.0 ppg. TD hole Pump sweeps clean hole and balanced mud @ 11.0 ppg. Maximum ECD 11.95 ppg. Pull 15 stand short trip 7700'. Service top drive. RIH to 9060 Make up top drive wash to 9151' Hole in good condition. Circulate and condition hole to run 5 1/2" X 4 1/2" casing. Gas cut mud on bottoms up. Increase mud weight to 11.2 ppg. Pump dry job spot at bit. POOH L/D drill pipe. Continue POOH L/D 3 1/2" DP & BHA. Dlown load MWD & L/D same. R/U to run csg. Pull Wear ring. R/U to run 5 1/2" By 4 1/2" csg. PJSM P/U and run 23 jt 4 1/2" 12.6# Csg 726' X/O 5" PBR X/O 5 1/2" 15.5# L-80 IBTM Csg to 4000' 7 5/8" Csg shoe. Circulate total volume surface to surface, Up wt 55k Dw wt 45k Run casing to 9151' Circulate last joint down and tag bottom 1.5 bpm 650 psi. No returns. reciporcate pipe 50' Continue to reciporcate pipe 150k up & 65k down. Lost 175 bbl's. M/U FMC casing hanger. Circ. & reciprocate. Cement csg. as per program-no returns-bump plug @ 1600#-leaked by @ 1600#. Rig down cement & handling equipment. Install 5.5" seal assemly to hanger-Test to 5000#-rilds. Prep to on load 3.5" tbg.-¢hange out bails-repair top drive bail tensioner-cut & slip drlg. line- change out top drive teflon slides-loading out equipment& pipe-off load extra tbg.-landing jr. & tbg. equipment. Onload-rack-tally & drift 3.5" tbg. Test csg. to 1760#-Pumping by-bled off to 1530# 1 min. RIH-picking up 3.5" tbg. 33 jts.-while waiting on sws.-stand in derrick. Rig up sws & rih w/gauge ring-junk basket. Run wireline gauge ring 3.64" & junk basket w/SWS to 8717'. Appears to be cement stringer @ 8717'=Spud on same-no-go-poh w/wireline & rig down SWS. RIH picking up 3.5" 9.6# tbg. while waiting on clean out tools-Picked up & make up 264 jts. 3.5" tbg. PJSM-service rig & top drive. POH installing new seals in collars. Load shed w/Clean out tools & pipe-drift & strap same. Pick up-make up & rih w/bha #6. Change out handling tools-rih w/2 stands 3.5" tbg. Make up top drive-circ, capacity of bha. Blow down top drive. RIH w/9 stands 3.5" tbg.-POH w/9 stands 3.5" tbg. Test bope 250-3500#--Freeze protect 7 5/8" X 5 1/2" annulus while testing bope. (Pump 150 bbls. water & 47 bbls. diesel) PJSM-rih w/bha #6. RIH w/milling assembly-tag cement stringer @ 8720 tbg. measurements. Clean out cement stringers @ 8720' & 8910'-circ to bottom @ 9081'-top of float collar. Drop ball-pump down & open circ. sub-pump hi-vis sweep @ 7 bpm-clean hole. Blow down top drive & POH. Change out handling equipment-Lay down & offload bha & tools. Operations Summary 3F-21 ~ 1 / 18/01 1 / 18/01 1/18/01 1/19/01 1 / 19/01 1/19/01 1 / 19/01 1/19/01 1 / 19/01 1/19/01 1/19/01 Rig up SWS-run 3.64 gauge ring & junk basket to 9080'-run baker cement retainer-set same w/ top @ 9072' wlm. POH & rig down SWS. Test csg. 3500# 30 min. chart same-held OK. Run 3.5" completion. Continue to run in hole w/completion & displace to clean seawater @ 8400'. Make up circ hose-locate sbe-tag no go-space out tbg. hanger-plug control port-drain bop stack- land hanger-rilds. Nipple up kill & choke lines to manifold & circ lines on landing jr. Test tbg. to 3500# 30 mins.-bleed to 1000# on tbg.-test annulus 3500#-bleed down & shear valve- lay down landing jt. & set two way check. Pull mouse hole-nipple down bope. PJSM-bring in tree & adapter & nipple up same. Test packoff to 5000#-test tree 250-5000#-pull two way check. Rig up lines & test-Pump 60 bbls. diesel down annulus-returns up tbg.-line up valves & 'U' tube same-flush diesel out of pumps-blow down pump lines-rig down lines-set BPV-rig down handy berm-vac out pits. (release rig @ 1800 hrs. 1-19-01. 01-Feb-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3F-21 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 9,151.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) DEFINITIVE Kuparuk River Unit Phillips Alaska Kuparuk 3F, Slot 3F-2~ 3F-2~ Surveyed: 15 January, 2001 SURVEY REPORT FebrUary, 200~ Your Ref: AP1500292299100 Surface Coordinates: 5985724.98 N, 508685.26 E (70° 22' 19.8695" N, Kelly Bushing: 84.25ft above Mean Sea Level 149° 55' 45.9094" VI/) DRII--LINB 5ERVI C E'''~ A Halliburton Company Survey Ref: svy9379 KuParuk River Unit Measured Depth fit) 0.00 145.37 208.15 300.81 390.60 482.79 574.89 666.81 -763.71 849.68 Incl. 0.000 0.360 0.320 0.570 2.280 3.490 3.54O 3.330 4.030 4.730 Azim. 0.000 165.570 193.600 354.860 8.170 2.640 8.550 10.670 14.460 4.270 sUb-Sea Depth -84.25 61.12 123.90 216.56 306.32 398.39 490.31 582.07 678.77 764.49 Vertical' Depth (ft) SPerry-SUn Drilling Services Survey Report for 3F-21 Your Ref: APl 500292299100 Surveyed: 15 January, 2001 ' Local Coordinates Northings Eastings fit) (ft) 0.00 0.00 N 0.00 145.37 0.44 S 0.11 208.15 0.80 S 0.12 300.81- 0.60 S 0.02 390.57 1.62 N 0.23 482.64 574.56 666.32 763.02 848.74 945.40 8.610 9.400 859.54 943.79 1037.90 9.380 6.030 950.91 1035.16 1129.72 11.700 10.490 1041.17 1125.42 1221.91 12.440 10.620 1131.32 1215.57 -1317.46 12.430 11.690 1224.63 1308.88 1318.52 1413.69 1505.21 1594.48 1680.02 1761.07 1839.10 1910.61 1983.20 2051.08 2114.69 2175.07 2235.09 2293.07 2348.52 10.780 10.590 12.090 13.490 13.000 12.590 11.980 12.040 12.160 12.620 14.710 17.070 20.390 26.780 31.330 12:300 12070 11.810 12.350 12.200 1414.05 1513.01 1609.66 1707.12 1805.00 1402.77 1497.94 1589.46 1678.73- 1764.27 1845.32 1923.35 1994.86 2067.45 2135.33 2198.94 2259.32 2319.34 2377.32 2432.77 1901.27 33.980 1997.50 37.640 2091.55 43,310 2191.88 43.990 2289.35 47.720 2386.52 50,480 2483.41 52.420 2580.63 51.330 2677.71 55.310 2774,47 54,770 6.24 N 11.85 N 17.28 N 23.34 N 29.80 N 0.62 1.18 2.09 3.46 4.48 40.81 55.14 71.73 90.69 110.87 5.95 7.87 10.35 13.88 17.86 133.10 159.72 190,14 228.13 274.39 22.26 27.28 33.42 42.10 52.98 325.04 380.05 439.74 507.45 575.75 N N N N N 64.47 76.44 89.14 103.66 118.67 647.46 721.53 796.35 872.47 949.95 N N N N' N 134.51 150.50 166.33 182.62 199.48 Global Coordinates Northings Eastings (ft) (ft) 5985724.98 N 508685.26 E 5985724.54 N 508685.37 E 5985724.18 N 508685.38 E 5985724.38 N 508685.28 E 5985726.60 N 508685.49 E 5985731.22 N 508685.88 E 5985736.83 N 508686.42 E 5985742.26 N 508687.33 E 5985748.32 N 508688.70 E 5985754.79 N 508689.71 E 5985765.80 N 508691.16 E 5985780.13 N 508693.06 E 5985796.73 N 508695.53 E 5985815.68 N 508699.04 E 5985835.87 N 508702.99 E 5985858.11N 508707.37 E 5985884.74 N 508712.36 E · 5985915.16 N 508718.46 E 5985953.16 N 508727.10 E 5985999.43 N 508737.92 E 5986050,10 N 508749.36 E 5986105.12 N 508761.26 E 5986164.82 N 508773.89 E 5986232.55 N 508788.33 E 5986300.87 N 508803.26 E 5986372.60 N 508819.02 E 5986446.68 N 508834.92 E 5986521.52 N 508850.66 E 5986597.66 N 508866.87 E 5986675.16 N 508883.64 E DEFINI '%VE Phillips Alaska Kuparuk 3F Dogleg Vertical Rate Section (°nOOft) 0.00 0.25 -0.41 0.27 -0.76 0.95 -0.58 1.93 1.63 Comment MWD Magnetic 1.35 6.24 0.40 11.85 0.27 17.35 0.76 23.57 1.21 30.10 4.10 41.18 1.01 55.61 2.68 72.37 0.80 91.65 0.24 112.22 2.37 134.88 2.39 161.97 3.47 193.00 6.58 231.96 4.65 279.45 2.76 331,38 3.82 387.66 6.03 448.68 0.68 517.93 3.84 587.85 2.85 661.27 2.01 737.03 1,14 813.50 4,12 891.34 0.57 970.63 I February, 2001 - 23:23 Page 2 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for 3F-2'! Your Ref: APl 500292299100 Surveyed: 15 January, 2001 Kuparuk River Unit Measured Depth (ft) Incl. 2871.60 53.880 2967.70 52.880 3064.43 52,570 3160.35 52,020 3257.65 53.800 3354.43 52.840 3451.75 51.930 3547.95 51.070 3644.83 53.800 3742.15 52.800 3839.57 52.180 3937.16 51.870 3988.85 51.560 4041.84 50.950 4140,12 53.430 12.120 11.670 11.550 12.090 11.780 11.740 11.950 11,630 9.730 10,070 10.250 10.020 10.860 12.140 11.570 4237.64 54,420 11.670 4334.61 53.660 10.890 4432.65 51.590 11,320 4529.17 52.000 11.140 4625.73 52.530 10.800 4722.93 51.340 10.800 4820.33 51.770 10.990 4917.47 52.590 10.670 5015.11 51.700 10.810 5110.91 52.510 11.150 5205.78 51.500 5300.43 52.220 5399.15 52.800 5495.37 51.590 5592.26 52.490 10,820 11.840 10.590 11,690 11,990 Sub-Sea Depth (ft) 2405.16 2462.48 2521.07 2579.73 2638.41 2696.22 2755.62 2815.50 2874.56 2932.72 2992.04 3052.09 3084.12 3117.28 3177.53 3234.95 3291.90 3351.41 3411.10 3470.20 3530.12 3590.68 3650.25 3710.17 3769.01 3827.41 3885.86 3945.95 4004.93 4064.53 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Easfings (ft) (ft) (ft) (ft) (ft) 2489.41 2546.73 2605.32 2663.98 2722.66 2780.47 2839.87 2899.75 2958.81 3016.97 3076.29 3136.34 3168.37 3201.53 3261.78 3319120 3376.15 3435.66 3495.35 3554.45 3614.37 3674.93 3734.50 3794.42 3853.26- 3911.66 3970.11 4030.20 4089.18 4148.78 1027.08 N 1102.56 N 1177.95 N 1252.23 N 1328.17 N 216.10 E 5986752.31N 508900.17 E 232.00 E 5986827.81 N 508915.99 E 247.50 E 5986903.22 N 508931.39 E 263.04 E 5986977.52 N 508946.85 E 279.09 E 5987053.47 N 508962.81 E 1404.15 1479.60 1553.30 1628.75 1705.62 N N N N N 294.91 E 5987129.47 N 508978.54 E 310.73 E 5987204.94 N 508994.27 E 326.11 E 5987278.66 N 509009.57 E 340.32 E 5987354.13 N 509023.69 E 353.73 E 5987431.01 N 509037.01 E 1781.68 1857.41 1897.31 1937.81 2013.80 367.36 E 380.90 E 388.25 E 396.49 E 412.43 E 2091.00 2167.97 2244.42 2318.81 2393.78 428.31E 443.66 E 458.67 E 473.44 E 487.97 E 2468.95 2543.86 2619.23 2694.97 2769.18 502.31 E 516.73 E 531.14 E 545.51 E 559.91 E 2842.58 2915.57 2992.40 3066.99 3141.75 N N N N N 5987507.09 N 509050.56 E 5987582.83 N 509064.01 E 5987622.74 N 509071.31 E 5987663.25 N 509079.50 E 5987739.25 N 509095.36 E 5987816.48 N 509111.14 E 5987893.47 N 509126.41 E 5987969.93 N 509141.32 E 5988044.34 N 509156.01E 5988119.33 N 509170.45 E 5988194.51N 509184.70 E 5988269.44 N 509199.03 E 5988344.82 N 509213.36 E 5988420.58 N 509227.64 E 5988494.81N 509241.95 E 574.16 E 5988568.22 N 509256.12 E 588.78 E 5988641.23 N 509270.66 E 604.01E 5988718.08 N 509285.80 E 618.70 E 5988792.68 N 509300.40 E 834.37 E 5988867.47 N 509315.99 E Dogleg Rate (°/100ft) Vertical Section 0.92 1049.52 1.11 1126.64 0.34 1203.61 0.73 1279.50 1.85 1357.11 0.99 1434.72 0.95 1511.80 0.93 1587.09 3.22 1663.86 1.07 1741.87 0.65 1819.13 O.37 1896.04 1.41 1936.61 2.21 1977.94 2.56 2055.57 1.02 2134,39 1.02 2212.88 2.14 2290.78 0.45 2366.63 0.62 2442.99 1,22 2519.52 0,47 2595.80 0.88 2672.53 0.92 2749.62 0.89 2825.21 1.10 2899.98 1.14 2974.42 1.16 3052.74 1.55 3128.76 0.96 3205.15 Phillips Alaska Kuparuk 3F Comment I February, 2001 - 23:23 Page 3 of 6 DrillQuest 2.00.06 Sperry. SUn Drilling Services Survey Report for 3F-21 Your Ref: APl 500292299100 Surveyed: 15 January, 2001 Kuparuk River Unit Measured Depth (ft) Incl. 5689.20 53.680 5786.45 52.140 5882.12 52.980 5979.53 54.260 6076.25 53.620 Azim. 10.180 11.490 10.110 9.810 12.120 6173.91 52.580 9.960 6270.53 52.460 9.360 6367.74 50.240 9.200 6463.59 50.470. 9.200 6561.06 50.300 9.970 Sub-Sea Depth (ft) 4122.75 4181.40 4239.58 4297.34 4354.28 4412.92 4471.71 4532.42 4593.57 4655.72 6658.95 52.560 11.030 4716.75 6756.32 53.330 11.600 4775.43 6853.46 54.140 12.000 4832.89 6952.12 54.000 12.070 4890.78 7049.01 53.130 11.350 4948.32 7147133 54.060 11.080 7244.62 53.340 11.820 7341.19 54.510 12.600 7437_78 53.190 12.360 7534.11 53.870 11.190 12.730 9.910 10.210 11.040 12.030 7631172 54.940 7728.73 53.640 7825.16 51.500 7922.53 51.910 8019.79 52.650 8116.32 51.880 8213.26 52.490 '8309.79 51.520 8407.29 52.320 8504.13 52.350 10.620 11 760 10.500 10.750 11.250 5006.67 5064.27 5121.14 5178.11 5235.37 5292.19 5348.82 5407.42 5467.77 5527.27 5586.35 5645.78 5705.21 5765.34 5824.52 Vertical Depth (ft) 4207.00 4265.65 4323.81 4381.59 4438.53 4497.17 4555.96- 4616.67 4677.82 4739.97 4801.00 4859.68 4917.14 4975.03 5032.57 5090.92 5148.52 5205.39 5262.36 5319.62 5376.44 5433.07 5491.67 5552.02 5611.52 5670.60 5730.03 5789.46 5849.59 5908.77 Local Coordinates Northings - (fi) 3217.81N 3294.00 N 3368.61N 3445.85 N 3522.60 N 3599.25 N 3674.83 N 3749.75 N 3822.61N 3896.64N 3971.89 N 4048.08 N 4124.75 N 4202.88 N 4279.21N 4356.83 N 4433.68 N 4509.96 N 4586.11N 4661.94 N 4739.59N 4816.81N 4892.20 N '4967.31N 5042.68 N 5117.53 N 5192.66 N 5267.29 N 5342.72 N 5417.97 N Eastings (ft) 649.26 E 663.83 E 678.06 E 691.63 E 706.49 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5988943.54 N 509330.79 E 5989019.74 N 509345.27 E 5989094.37 N 509359.41 E 5989171.63 N 509372.89 E 5989248.40 N 509387.66 E 721.45 E 5989325.06 N 509402.54 E 734.32 E 5989400.66 N 509415.31 E 746.56 E 5989475.60 N 509427.47 E 758.36 E 5989548.47 N 509439.19 E 770.86 E 5989622.52 N 509451.60 E 784.82 E 5989697.78 N 509465.47 E 800.07 E 5989773.99 N 509480.63 E 816.09 E 5989850.67 N 509496.56 E 832.74 E 5989928.83 N 509513.13 E 848.57 E 5990005.17 N 509528.86 E 863.96 879.52 896.03 912.89 928.69 E 5990082.81 N 509544.16 E E 5990159.67 N 509559.63 E E 5990235.98 N 509576.06 E E 5990312.15 N 509592.82 E E 5990388.00 N 509608.54 E E 5990465.66 N 509624.90 E E 5990542.90 N 509640.29 E E 5990618.31N 509653.57 E E 5990693.43 N 509667.58 E E 5990768.82 N 509682.88 E 945.14 960.62 973.99 988.08 1003.47 1018.46 1033.33 1048.02 1062.17 1076.80 E 5990843.69 N 509697.79 E E 5990918.83 N 509712.56 E E 5990993.48 N 509727.17 E E 5991068.93 N 509741.23 E E 5991144.20 N 509755.77 E 1.93 1.91 1.44 1.34 2.04 2.06 0.51 2.29 0.24 0.63 2.46 0.92 0.90 0.15 1.08 0.97 0.96 1.38 1.38 1.21 1.69 2.71 2.23 0.79 1.11 1.40 1.12 1.44 0.84 0.41 Vertical Section 3282.65 3360.22 3436.17 3514.57 3592.75 3670.84 3747.48 3823.35 3897.10 3972.15 4O48.68 4126.38 4204.70 4284.58 4362.53 4441.66 4520.07 4598.11 4676.08 4753.54 4832.90 4911.66 4988.21 5O64.62 5141.55 5217.89 5294.47 5370.54 5447.28 5523.94 Phillips Alaska Kuparuk 3F Comment I February, 2001- 23:23 Page 4 of 6 DrillQuest 2.00.06 Sperry-SUn Drilling Services Survey Report for 3F-2'1 Your Ref: APl 500292299'i00 Surveyed: 15 January, 2001 Kuparuk River Unit Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) Vertical Depth (ft) 8600.35 52.950 11.060 5882.89 5967.14 8697.04 53.930 10.470 5940.49 6024.74 8793.47 55.110 11.510 5996.46 6080.71 8890.85 56.370 11.920 6051.27 6135.52 8989.02 57.380 12.280 6104.92 6189.17 Local Coordinates Northings Eastings (fi) 5493.02 N 1091.59 E 5569.31N 1106.10 E 5646.39 N 1121.07 E 5725.20 N 1137.42 E 5805.59 N 1154.65 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/lOOft) 5991219.26 N 509770.48 E 5991295.57 N 509784.90 E 5991372.67 N 509799.78 E 5991451.49 N 509816.03 E 5991531.90 N 509833,17 E 908501 58.370 12.790 6155.96 6240.21 5884.94N 1172.30 E 5991611.28 N 9151.00 58.370 12.790 6190.57 6274.82 5939.73 N 1184.73 E 5991666.08 N 509850.73 E 509863.10 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well, Magnetic Declination at Surface is 26.135° (01-Jan-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 11.300° (True). Based upon Minimum Curvature tyPe calculations, at a Measured Depth of 9151.00ft., The Bottom Hole Displacement is 6056.73ft., in the Direction of 11.280° (True). 0.64 1,13 1.51 1.34 1.07 1.13 0.00 Vertical Section 5600.43 5678.09 5756.61 5837.09 5919.29 6000.56 6056.73 Phillips Alaska Kuparuk 3F Comment Projected Survey DrillQuest 2.00. 06 I February, 2001 - 23:23 Page 5 of 6 Kuparuk River Unit Comments Measured .Depth (ft) 9151.00 SPerry-Sun Drilling Services Survey Report for 3F-21 Your Ref: APl 500292299100 Surveyed: 15 January, 2001 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6274.82 '5939.73 N 1184.73 E -- Comment Projected Survey Phillips Alaska Kuparuk 3F Survey tool program for 3F-21 From To Measured Vertical. MeasUred Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0:00 9151.00 6274.82 SurVey Tool DeScription MWD Magnetic I February, 2001 - 23:23 Page 6 of 6 DrillQuest 2.00.06 TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-319:2 PHONE: (907) 279-1433 FAX: (907) 276-7542 James Tranthml Drilling Engineering Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Kuparuk River Unit 3F-21 Phillips Alaska, Inc. Permit No: 200-203 Sur Loc: 99'FNL, 185'FWL, Sec. 29, T12N, R9E, UM Btmhole Loc. 658'FSL, 1414'FWL, Sec. 17, TI2N, R9E, UM Dear Mr. Tranthan: Enclosed is tile approved application for permit to drill tile 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 has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 3F-21. 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 annular disposal on Drill Site 3F must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annUlar space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the CommiSsion to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this _~ '~'Y-/~ day of December, 2000 dlf/Enclosurcs CCi 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: Ddll [~] Reddll F-] I lb. Type of well. Exploratory [--] Stratigraphic Test F-~ Development Oil r'] Re-entl¥ [~] Deepen [~I Service [~] Development Gas D Single Zone ['~ Multiple Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 84 feet 3. Address .6. ProDerN.Desianation ~, Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25632 ALK 2565 Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.0251) 99' FNL, 185' FWL, Sec. 29, T12N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 273' FSL, 1336' FWL, Sec. 17, T12N, R9E, UM 3F-21 #59 52 180 At total depth 9. Approximate spud date Amount 658' FSL, 1414' FWL, Sec. 17, T12N, R9E, UM December 21,2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1414 @ TD feetI 3F-01 22.3' @ 580' feet 2560 9296' MD/6394' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 800 MD Maximum hole angle 52.7° Maximum surface 2531 psig At total depth (TVD) 3200 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantib/of Cement Hole Casln~l Welt, Iht Grade CoupIin~l Len~h MD TVD MD TVD /include stac, le data) 20" 16" 62.5# R-3 Weld 26' 84' 84' 110' 110' 230 sx AS I 9.875" 7.625" 29.7# L-80 BTC-Mod 3941' 84' 84' 4025' 3199' '260 sx AS3 Lite, 360 sx LiteCrete 6.75" 5.5" 15.5# L-80 BTCM 8374' 84' 84' 8458' 5886' 234 sx Class G GasBIok 6.75" 4.5" 12.6# L-80 BTCM 838' 8458' 5886' 9296' 6394' see above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) tree vertical feet Effective Depth: measured feet Junk (measured) tree vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface o RECEIVED Production 685' 4.5" see above 9296' 6394' DEC 01 2000 Perforation depth: measured Alaska 0il & Gas Cons. Commission tree vertical Anchorage 20. Attachments Filing fee r~] Property Plat ['"] BOP Sketch D Dive,er Sketch r'~ Drilling program [~] Drilling fluid program r~ Time vs depth plot r--~Refraction analysis D Seabed report r'~ 20 AAC 25.050 requirements D 21. i hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Mark Chambers 265-131(` Signed [ ~c~.~_~ ~ ~, · _. Title: Drilling Engineering Supervisor Date ¥?- ~ James Tranthan J Pret~ared bv Sharon AIIsut~-Dral(~ Commission Use Onl} PermitNumber,~(.~_~~J APInumber I l~~k''''(:~'~/~'3~'') If°r°therrequlrements ' 50- ~:)~..~'~' '" ,,~'-',~---~'~:::~/~ ~'~-~ Approval date ISoe cover letter Conditions of approval Samples required D Yes [~ No Mud Icg r~quired D Yes ~] No Hydrogen sulfidemeasures [~] Yes E] No Directional surveyrequired '~] Yes r'] No Required working pressure for BOPE E] 2M; ~ D 5M; [--~ 10M; r'] D Other: by order of ORIGINAL SIGNED BY comm,ssioner the corem,ss,on Date Approved by r~ T ....... r~,. ---J- .. I'~,. ORIGINAL Form 10-401 Rev. 12/1/85 · Submit in triplicate 3F-21 Drillin.q Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 9-7/8" Hole 1 7-518" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach ... Moderate Monitor cellar continuously during intervai. Well Collision Low Careful well planning and surveying, adherence to anti-collision policy Gas Hydrates Moderate Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, Iow mud temperatures Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted sweeps, run gravel isolation string. Abnormal Pressure in Low Diverter drills, increased mud weight Surface Formations Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of Iow density cement slurries 6-3/4" Hole 1 5-112 x 4-1/2" Casing Interval Event , , Risk Level Mitigation Strategy Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) moni.toring, weighted sweeps. ... Abnormal Reservoir Moderate Well control drills, increased mud weight, Pressure contingencies for top set casing string. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers 3F-21 Ddlling Hazards Summary. doc prepared by Steve McKeever 12/27/00 Page I of 1 KRU 3F-21 Proposed Completion Surface csg. 7 5/8" 29.7# L-80 BTCM (+/- 4025' MD / 3199' TVD) 200' TVD Below Base of West Sak All Depths Reference Nordic 3 RKB Production csg. 5~1/2" 15.5# L-80 BTCM run XO/SBE to surface (+/- 8458' MD / 5886' TVD) Set XO/SBE +/- 100' above estimated top perforation Future Thru-Tubing Perforations Production csg. 4-1/2" 12.6# L-80 BTCM run TD to XO/SBE (+/- 9296' MD / 6394' TVD) 3-1/2' Gen V Tubing Hanger with 3-1/2' L-80 EUE 8RD Mod pin down 3-1/2' 9.3# L-80 EUE 8RD Mod Tubing to surface 3-1/2' Camco 'DS' nipple w/2.812' No-Go Profile. 3-1/2' x 6' L-80 pup installed above. 3-1/2' x 6' L-80 flow coupling installed below, EUE 8RD-Mod set at +/- 500' MD 3-1/2" 9.3# L-80 EUE 8RD-Mod Tubing from GLM to 'DS' Nipple. RECEIVED DEC 0 'I 2000 Alaska 0il & Gas Cons. Commission Anchorage 3-1/2" x 1" Camco 'KI~G-2-9' GLM (Max. OD 4.725'', ID 2.90") w/Dump Kill Valve pinned for 3000 psi shear (casing to tubing differential), 6' L-80 crossover handling pups (BTC x Special Clearence EUE 8RD) installed on GLM; 1 Joint 3-1/2" '9.3# L-80 EUE 8RD Mod TUbing. 3-1/2" Camco ;D' landing nipple with 2.75" ID and No-Go Profile (Max OD 4.50"). I Joint 3-1/2" 9.3# L-80 EUE 8RD MOd Tubing. Baker 4-1/2" 'GBH-22' Locator Seal Assembly w/15' of seals & Iocator 3-1/2'' x 6' handling pup installed on top. EUE 8RD-Mod box up. I!aker XO Coupling aker 5" OD x 4" ID S,e,? Bom Extension aker XO, SBE x 4-1/2 BTCM et at +/- 8458' MD /5886' TVD 4-1/2" 12.6# L-80 BTC Mod Tubing from Landing Collar to SBE. Landing Collar. 1 Joints 4-1/2" 12.6# L-80 BTC Mod Tubing. Float Collar: 1 Joints 4-1/2" 12.6# L-80 BTC Mod Tubing. Float Shoe: MAC 11/26/00 GENERAL DRTLL AND COMPLETE PROCEDURE KUPARUK RTVER UNZT- TN.lECTOR KRU 3F-21 General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up Nordic Rig 3. Install diverter & function test same. 3. Spud and directionally drill 9-7/8" hole to 7-5/8" surface casing point (200q-VD below base West Sak @ +/- 4025' MD / 3199' TVD) according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering 4. Run and cement 7-5/8" 29.7# L-80 BTC Mod casing to surface using lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during cement job. Displace cement with mud. Note: A port collar will not be run in this casing string. If cement does not circulate to surface a top job will be performed. AOGCC approval must be obtained prior to proceedinq with to~ iob. 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 psi. Record results. 6. Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. 7. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 14.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FTI' or LOT EMW). 8. Drill 6-3/4" hole to well total depth (+/- 9296' MD / 6394' TVD) according to directional plan, running LWD logging equipment as needed. 9. Run and cement 5-1/2" 15.5# L-80 BTC Mod x 4-1/2" 12.6# L-80 BTC Mod tapered casing string with polished seal bore as part of XO. Adequate cement will be pumped to place cement top +\- 500' above the Kuparuk sands. DisplaCe cement with mud. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. 10. Pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. 11. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. 12. Freeze protect well. Pull landing joint. Tnstall BPV. Nipple down BOP stack and nipple up production tree. Pull BPV. Tnstall test plug. Pressure test production tree. Pull test plug. 13. Secure well. Release rig. 14. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. Note: As a dedicated injector, cased hole cement .bond logs will be run to establish isolation prior to perforating. RECEIVED DEC O1 2000 Alaska 0ii & Gas Cons. commission Anchorage DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRZLLING AREA RISKS KRU 3F-21 Drillinq Fluid Properties: Properties .Spud to Base Permafrost Base Permafrost to 7~5/8" Casing Point Drillout to 'FD Density 8.5 - 9.4 9.4 - 9.5 9.0 - 10.6 PV 8 - 18 / 10 - 20 10 - 20 13 - 20 YP 20 - 50 20 - 40 15 - 25 Viscosity 100 - 150 80 - 110 45 - 58 Initial Gel 10 - 25 10 - 20 4 - 8 10 Minute Gel 20 - 50 20 - 50 6 - 15 API Filtrate 8 - 10/6 - 8 5 - 7 < 4 PH 8 - 9 8 - 9 9.5 % Solids 4- 8 / 6 - 11 6 - 11 9 - 14 Drillinq Fluid System: Nordic Riq 3: Tandem Geolograph/Swaco Shale Shakers Mud Cleaner, Degassers Pit Level Indicator (Visual/Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Flow Line Cleaner Notes: RECEIVED DEC 0 1 2000 Alaska Oil & Gas Cons. Commission Anchorage Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (HASP) seen by the surface casing string along the 3F-21 well path can be determined as follows: If surface shoe LOT is acceptable and the well is drilled out of surface casing to TD as planned, the MASP can be calculated based on an A-sand reservoir pressure of 3200 psi at 6082' TVD (0,5261 psi/fi) and a gas gradient of 0,11 psi/fi, In this case, MASP would occur at 2554 psi, MASP= (6082 ft)(0.5261-0.11) = 2531 psi Therefore, Phillips Alaska, Inc. will test the BOP equipment to 3000 psi prior to drilling out of surface casing. In the event that the well must be top set above the Kuparuk, the maximum anticipated pressure for the intermediate casing string would continue to be the pressure exerted by the Kuparuk A-sands at the surface and would remain at 2531 psi as calculated previously. Therefore, Phillips Alaska, Inc. will test the BOP equipment to 3000 psi prior to drilling out of intermediate casing 'if an intermediate string is needed. Based the anticipated pressures shown, a maximum mud weight requirement for this well is established based on the potential reservoir pressure in the Kuparuk A-sands. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.6 ppg can be predicted as the maximum mud weight needed to safely conduct rig operations, assuming a TVD of 6082' (Top A-Sand). MW = [(6082 ft)(O.S261)+lSO]/6082/.052 = 10.6 ppg ]~n order to allow for a long string design, the minimum LOT in the Mid-HRZ or surface casing shoe must be greater than ECD (equivalent circulating density) with a :10.6 ppg drilling fluid as modeled or as measured with the Pressure While Drilling (PWD) sub, plus adequate safety margin. Well Proximity Risks: The nearest existing well to 3F-21 is 3F-01. As designed, the minimum distance between the two wells would be 22.3' at 580' MD. Drillinq Area Risks: Risks in the 3F-21 drilling area include lost circulation and possible differential pressure between the "A" and "C" sands in the Kuparuk formation. The pressure differential between the "A" and "C" sands has been estimated at +/- 200 psi pressure resulting in a Iow risk of lost circulation or differential sticking. Lost circulation above and through the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. !f lost circulation cannot be controlled with LCM and a reduction of Circulating pressure, 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #3 or a coiled tubing unit will drill out 4-3/4" hole and run a 3-1/2" liner to TD. Careful analysis of pressure data from offset wells shows that a mud weight of 10.6 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 14.0 ppg upon drilling out of the casing. Annular Pumpinc~ Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class !! disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus). The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3F-21 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. !f isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. At the end of drilling operations, a request for 3F-2:1 to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 3F pad, per regulation 20 AAC 25.080, will be submitted. 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 in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in. the following table: RECEIVED DEC 2000 Alaska Oil & Gas Cons. Commission Anchorage Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTCM 4,790 psi NA 6,890 psi 5,856 psi 5-1/2" 15.5 L-80 3 BTCM 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3-1/2" * 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi * if needed Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). RECEIVED, DEC 0 2000 Alaska Oil & Gas P, ons. Commission Anchor~e Kuparuk Development 3F-21. Surface String Cement Loads and CemCADE Summary 45 % Excess Below Frost, 250% Above, 9-7/8" Hole, 7-5/8" Casing: TMD @ 4025' Single Stage Design. Port Collar at 1000' md for no cement to surface contingency. Base of permafrost at 1580' MD. Fluid Sequence: Pump 20 bbls CW100 Wash, 40 bbls Water. Drop Bottom Plug.Cement from 4025' to 1450' (500' above the Ugnu) with 12.0 ppg LiteCRETE and from 1450' to surface with AS 3 Lite. Lead Slurry_: Arctic Set 3 Lite @ 10.7 ppg, Class G with 50% D124, 9.0% D44, 0.4% D46, 30% D53, 1.5% S1 and 1.5% D79, 4.43 ft3/sk (1450'- 120') x 0.2148 ft3/ft x 3.5 (250% excess) = 999.9 ft3 (120') x 0.8595 ft3/ft x 1.0 (0% excess) = 103.1 ft3 Total Lead Slurry Requirement; 1103.0 ft3 / 4.43 ft3/sk = 249 sacks Round up to 260 sacks. HAVE 185 additional sacks AS3 Lite on hand for top job ( up to 1000') Tail Slurry_: LiteCRETE @ 12.0 ppg, 2.46 ft3/sk (1580'- 1450') x 0.2148 ft3/ft x 3.5 (250% excess) = 97.7 ft3 (4025', 1580') x 0.2148 ft3/ft x 1.45 (45% excess) = 761.5 ft3 (80' (shoe joints) x 0.2578 = 20.6 ft3 Total Tail Slurry Requirement: 879.8 ft3, 879.8 ft3 / 2.46. ft3/sk = 358 sacks Round up to 360 sacks CemCADE Summary: Fluid Sequence: 20 bbl CW100 Wash, 40 bbl Water, 260 sacks (205 bbls) AS3 Lite, 360 sacks (158 bbls) LiteCRETE. CIRCULATION: Mud circulation over 8 to 9 BPM risks formation breakdown. Circulation and cementing at or under 6 bpm is within safe ECD to avoid breaking down any formations and allows sufficient turbulent contact time for water preflush. Recommend dropping displacement rate towards end of displacement, if necessary, to maintain 1:1 returns. Recommended cementing displacement rate is 6 BPM for Mud removal and avoiding breakdown. Expected pressure to bump plug is 500 psi. At 6 BPM, exPect 20 minutes U.tubing. Use top and bottom plug. Run plugs immediately before and after cement to isolate slurries when travelling down casing. Recommended Conditioned Mud Properties: = 9.6 -10.0 ppg, Pv = under 15, Ty = under 15 Kevin Tanner can be reached at office or home for additional details and/or assistance on this job design 336-0067(H) or 265-6205(0). RECEIVED DEC 0 ZOO0 Alaska Oil 8, Gas Cons. Commissio, Anchoraoe Kuparuk Development, 3F-2i, Cement and Spacer Loads and CemCADE Summary. 50% Excess, 6-3/4" Bit, 5-112" by 4-112" Tapered Production String: TMD @ 9296', 5.5" by 4.5" x-over @ 8458', TOC @ 7958' Volume Calcs: 20 bbls CW100 Wash, 40 bbls MudPUSH XL Spacer (12 ppg) Cement from 7529' to 6450' with Class G GasBlok Tail Slurry: Class G GasBlok Class G with 0.1 gps D47, 3.0% D53, 0.66% D65, 0.1 gps D135, 2 gps D600 and 0.12% D800, 15~8 ppg, 1.20 ft3/sk, 15.8 ppg (9296'-8458') x 0.1381 ft3/ft x 1.5 (50% excess) = 173.6 ft3 (4.5" by 6.75" annulus) (8458'-7958') x 0.0835 ft3/ft x 1.5 (50% excess) = 62.6 ft3 (5.5" by 6.75" annulus) 60' (shoe joints) x 0.08544 = 5.1 ft3 Total Tail Slurry Requirement: 241.3 ft3 241.3 ft3/1.20 ft3/sk = 201 sacks. Round to 210 sacks (45 bbls). Load out for 50 bbls, 234 sacks. Pump minimum of 45 bbls. CemCADE Summary: Fluid Sequence: 20 bbl CW100 Wash, 40 bbl 12.0 ppg MudPUSH XL Spacer, 210 sacks (45 bbls) Class G GasBlok. CIRCULATION: Mud circulation over 6.0 to 7.0 BPM risks formation breakdown (10.7 ppg, Pv/Ty of 10/10). Circulation and cementing at or under 5.0 bpm is within safe ECD to avoid breaking down any formations. Recommend dropping displacement rate if necessary to maintain 1:1 returns towards end of displacement to avoid losses. Recommended cementing displacement rate is 4-5 BPM for Mud removal and avoiding breakdown. Expected wellhead pressure to bump dart is 1450 psi. At 3.5 to 5.0 BPM, NO U-tubing expected. SPACER AND MUD NOTES: For best chances at effective mud removal in laminar flow across pay zone, with proposed Centralizer program, the following conditions applied. Centralizer 1/jt Rigid 4.5" by 6.5" Spirolizer centralizer from shoe to crossover, and 2/jt. on shoe joint. 1/jt. Weatherfor Sl102551 Bow spring centralizer on 5-1/2" casing from crossover to TOC (7958' MD) ' Recommended Conditioned Mud Properties; At or Under 10.6 ppg, Pv = 10 or less, Ty = 10 or leSs. 12.0 ppg Spacer target rheology, Pv >=20, Ty >= 25. Kevin Tanner can be reached at office or home for additional details and/or assistance on this job design 336-0067(H) or 265-6205(0). KVT 11-27-00 RECEIVED. DEC 07 2000 Alaska Oil a Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 3F 21 slot #21 Kuparuk River Unit North Slope, Alaska PRO PO SAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 21 Version #6 Our ref : prop4280 License : Date printed : 29-Nov-2000 Date created : 9-Nov-2000 Last revised : 29-Nov-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 22 20.956,w149 55 51.299 Slot location is n70 22 19.982,w149 55 45.887 Slot Grid coordinates are N 5985724.482, E 508685.008 Slot local coordinates are 99.00 S 185.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED DEC 0 1 2000 Alaska Oil & Gas Cons. CommiSsion Anchorage Phillips Alaska, Inc. Pad 3F,21~ Kuparuk River Unit,North Slope, Ala~ PROPOSAL LISTING ,?age 1 Your ref : 21 Vj on 96 Last revised : 29-N% 2000 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth C O 0 R D I N A T E S Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 300.00 0.75 11.30 300.00 400.00 2.25 11.30 399.96 450.00 3.00 11.30 449.91 0.00 N 0.00 N 0.32 N 2.89 N 5.13 N 500.00 3.00 11.30 499.84 7.70 N 800.00 3.00 11.30 799.43 23.10 N 900.00 4.50 11.30 899.21 29.51 N 950.00 5.25 11.30 949.03 33.68 N 975.00 6.00 11.30 973.91 36.08 N 1075.00 9.00 11.30 1073.04 48.88 N 0.00 E 0.00 0.00 0.00 0.00 N/A 0.00 E 0.00 0.65 0.65 0.38 N/A 0.06 E 0.33 0.78 0.78 0.45 N/A 0.58 E 2.95 1.06 1.05 0.60 11.30 1.03 E 5.24 1.20 1.18 0.68 11.30 1.54 E 7.85 1.35 1.31 0.75 11.30 4.61 E 23.55 2.27 2.11 1.20 11.30 5.90 E 30.09 2.62 2.37 1.35 11.30 6.73 E 34.34 2.81 2.51 1.43 11.30 7.21 E 36.79 2.91 2.58 1.47 11.30 9.76 E 49.84 3.43 2.87 1.62 11.30 1175.00 12.00 11.30 1171.36 66.75 N 13.33 E 68.07 4.08 3.17 1.77 11.30 1275.00 15.00 11.30 1268.58 89.64 N 17.91 E 91.41 4.90 3.49 1.94 11.30 1375.00 18.00 11.30 1364.45 117.48 N 23.47 E 119.81 5.91 3.83 2.11 11.30 1475.00 21.00 11.30 1458.71 150.21 N 30.01 E 153.18 7.09 4.21 2.29 11.30 1558.52 23.51 11.30 1536.00 181.23 N 36.21 E 184.81 8.24 4.54 2.46 11.30 1575.00 24.00 11.30 1551.08 187.74 N 37.51 E 191.45 8.46 4.60 2.50 11.30 1675.00 27.00 11.30 1641.33 229.95 N 45.94 E 234.49 10.02 5.03 2.72 11.30 1775.00 30.00 11.30 1729.20 276.73 N 55.29 E 282.20 11.76 5.48 2.98 11.30 1875.00 33.00 11.30 1814.46 327.97 N 65.52 E 334.45 13.67 5.96 3.27 11.30 1975.00 36.00 11.30 1896.86 383.50 N 76.62 E 391.08 15.76 6.45 3.61 11.30 2046.62 38.15 11.30 1954.00 425.84 N 85.07 E 434.25 17.37 6.82 3.89 11.30 2075.00 39.00 11.30 1976.19 443.19 N 88.54 E 451.95 18.01 6.96 4.00 11.30 2175.00 42.00 11.30 '2052.22 506.87 N 101.26 E 516.89 20.42 7.49 4.44 11.30 2275.00 45.00 11.30 2124.75 574.36 N 114.75 E 585.71 23.00 8.01 4.93 11.30 2375.00 48.00 11.30 2193.58 645.49 N 128.96 E 658,24 25.72 8.55 5.48 11.30 2475.00 51.00 11.30 2258.51 720.05 N 143.85 E 734.28 28.58 9.07 6.09 11.30 2531.27 52.69 11.30 2293.28 763.43 N 152.52 E 778.52 30.24 9.37 6.46 11.30 2941.60 52,69 11.30 2542.00 1083.47 N 216.46 E 1104.88 42.39 11.53 9.20 11.30 3000.00 52.69 11.30 2577.40 1129.01 N 225.56 E 1151.33 44.12 11.84 9.59 11,30 3500.00 52.69 11.30 2880.48 1518.98 N 303.46 E 1549.00 58.99 14.50 13.01 11.30 3695.53 52.69 11.30 2999.00 1671.49 N 333,93 E 1704.52 64.82 15.55 14.36 11.30 4000.00 52.69 11.30 3183.55 1908.95 N 381.37 E 1946.67 73.90 17.18 16.46 11.30 4025.48 52.69 11.30 3199.00 1928.82 N 385.34 E 1966.94 74.66 17,31 16.64 11.30 4500.00 52.69 11.30 3486.63 2298.92 N 459.28 E 2344.35 88.82 19.86 19.94 11.30 5000.00 52.69 11.30 3789.71 2688.88 N 537.19 E 2742.02 103.75 22.56 23.41 11.30 5500.00 52.69 11.30 4092.78 3078.85 N 615.10 E 3139.69 118.69 25.25 26.90 11.30 6000.00 52.69 11.30 4395.86 3468.82 N 693,01 E 3537.37 133.63 27.95 30.39 11.30 6500.00 52.69 11.30 4698.94 3858.79 N 770,91 E 3935.04 148.57 30.65 33.88 11.30 7000.00 52.69 11.30 5002.02 4248.75 N 848.82 E 4332.71 163.51 33.36 37.37 11.30 7500.00 52.69 11.30 5305.09 4638.72 N 926.73 E 4730.39 178.45 36.06 40.86 11.30 8000.00 52.69 11.30 5608.17 5028.69 N 1004.64 E 5128,06 193,40 38.77 44.36 11.30 8220.79 52.69 11.30 5742.00 5200.89 N 1039.04 E 5303.66 200,00 39.96 45.90 11.30 8405.56 52.69 11.30 5854.00 5345.00 N 1067.83 E 5450.62 205.52 40,96 47.19 11.30 8458.35 52.69 11.30 5886.00 5386.17 N 1076.06 E 5492.61 207.10 41.25 47.56 11.30 8500.00 52.69 11.30 5911.25 5418.66 N 1082.55 E 5525.74 208.35 41.47 47.85 11.,30 8557.33 52.69 11.30 5946.00 5463.37 N 1091.48 E 5571.34 210.06 41.78 48.25 11.30 8624.97 52.69 11.30 5987.00 5516.13 N 1102.02 E 5625.13 212.08 42.15 48.73 11.30 8783.35 52.69 11.30 6083.00 5639.65 N 1126.70 E 5751.10 216.82 43.01 49.84 11.30 8801.50 52.69 11.30 6094.00 5653.80 N 1129.53 E 5765.53 217.36 43.10 49.96 11.30 t £CEIVED o£C 0 1 2000 Alaska Oil & Gas Coos. C°mr~ission Anchorage Ail data is in feet unless otherwise stated. Coordinates from slot 921 and TVD from Estimated Nordic 3 (86.00 Ft above mean sea level). Bottom hole distance is 6159.17 on azimuth 11.30 degrees from wellhead. Vertical section is from wellhead on azimuth 11.30 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 3F,21 i:'" Kuparuk River Unit,North Slope, Ala Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S PROPOSAL LISTING~.~""~ge 2 Your ref : 21 ~ on #6 Last revised : 29-Nbo 2000 Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 9000.00 52.69 11.30 6214.32 5808.62 N 9296.42 52.69 11.30 6394.00 6039.81 N 1160.46 E 5923.41 223.29 44.18 51.35 11.30 1206.64 E 6159.17 232.16 45.78 53.42 11.30 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 9296 ARCO (H.A. Mag) User specified 232.16 45.78 53.42 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a random relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. RECEIVED b£C 0 1 ZOO0 Alaska Oil & Oas Cons. Commission AnChOrage All data is in feet unless otherwise stated. Coordinates from slot #21 and TVD from Estimated Nordic 3 (86.00 Ft above mean sea level). Bottom hole distance is 6159.17 on azimuth 11.30 degrees from wellhead. Vertical section is from wellhead on azimuth 11.30 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 3F,21 Kuparuk River Unit,North Slope, Ala~ PROPOSAL LISTING Page 3 Your ref : 21 '~' on #6 Last revised 29-N~ .000 Comments in wellpath MD TVD Rectangular Coords. Comment 250 450 800 950 1558 2046 2532 2941 3695 4025 8220 8405 8458 8557 8624 8781 880] 9296 00 250.00 0.00 N 0.00 E Beg D'nl Nudge 00 449.91 5.13 N 1.03 E EOC 00 799.43 23.10 N 4.61 E KOP 00 949.03 33.68 N 6.73 E Beg 3/100 Build 52 1536.00 181.23 N 36.21 E Base Permafrost 62 1954.00 425.84 N 85.07 E Top Ugnu 27 2293.28 763.43 N 152.52 E EOC 60 2542.00 1083.47 N 216.46 E Top W Sak 53 2999.00 1671.49 N 333.93 E Base W Sak 48 3199.00 1928.82 N 385.34 E 7 5/8 Casing 79 5742.00 5200.89 N 1039.04 E Top U Kalubik 56 5854.00 5345.00 N 1067.83 E Top L Kalubik 35 5886.00 5386.17 N 1076.06 E 5 1/2" Casing 33 5946.00 5463.37 N 1091.48 E Top C4 97 5987.00 5516.13 N 1102.02 E Top C1 .35 6083.00 5639.65 N 1126.70 E Top A5 .50 6094.00 5653.80 N 1129.53 E 3F-21/A4/ll-17-00 42 6394.00 6039.81 N 1206.64 E TD - Csg Pt Casing positions in string 'A' Top MD TOD TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 9296.42 6394.00 6039.81N 1206.64E 4 1/2 Casing 0.00 0.00 0.00N 0.00E 8458.35 5886.00 5386.17N 1076.06E 5 1/2 Casing 0.00 0.00 0.00N 0.00E 4025.48 3199.00 1928.82N 385.34E 7 5/8 Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 3F-21/A4/ll-17-00 509808.000,5991379.000,0.0000 6094.00 5653.80N 1129.53E 17-Nov-2000 t £CEIVED DEC O l 2000 Zilaska Oil & Gas Cons. Commission Anchorage iPhillips Alaska, Inc.-..-" c~.~ .... .,,-, ........ s~l=,, i =' Field : Kuporuk River Unit Location : North Slope.-Alaska} Ve~lic~ ~lhs ~e iel~ence [~im~l~d ~(A INTgO ..................................................................................................... } :.. ................................................................................................. ~ ..................................................................................................................................................................................................................................................................................................................................................... · ' Point iBe9 D'ni Nudge !'EO'C i I< 0 P iBe9 3/t'00 Build ~ Bas'e Permafrost iTop UDnu i EOC !Top W $ok PROFILE COMMENT DATA MD Inc Dir TVD North East V. 'Sect 250.00 0.00 0.00 250.00 0..00 0.00 0.00 -~' 5. 450.00 3.00 '11 .~0 449.9 i 13 '1.03 5.24 800. O0 3.0.0 11.30 799:43 23.10 4.61 23. o5 950:00 5. ? 5 '11.50 949.03 53'. 68 6.. 75 54.34 ' = ._ .:,1 1 .... '1 '184:81 135,.°,.52 25.c-' :1.$0 1536.00 '181 ?5 3a.2 2046.62 38.1 5 '11.30 19R4. _ . O0 ==~n=,.'o*=~ 85.07 434'.25 2531.27 52.69 11.30 ??95 ~8 763.43 152.52 778.52 2941.60 52.69 11 ;30 "2~42 O0 1085.47 2 '16.46' 1104.88 .; Deg/l OOi O:OOi 0.00~ . 1 5.00i 3.00 3.00 0.00 {7 ,~/'8 3~o,04. '1966'.94 C O. si ng 4025.48 oz.= o .6a.~ I "1 :.5'0 'S 199.00 ' :,=,:a"o2. a'o,~,, o , C) lTop J' I<alubil< 8220.79 52.69 11 50 5742.00 5,_.00.8:: 1059 '04 5,_-503.66 ~_ ~-: o.-,-- . ,~RrS'a = = I 0F, 7.8, ~ 5'450.6? iTop L I{c lu. bil:,:, 840,3 .... (5, 5::6:) 'l 'I ,50 ....... O0 3540.00 ' - ' 15 1/2 Cas~n9 8458.,55 5.2.69 t1.50 588.'6..00 5586.17 1076.06 3492.61 iTcp C4 8.037.33 5?.69 I'1 -50 J946..00 5465.37 1091.4.8 5571 34 ~,:vo = = ~ 6 t'3 1102.02 5625.1 Top C1 8624:97 50 69 '1 '1.30 =""=7.00 ~d, . iTop A5 8785.55 52';69 I 'I .30 6083.00 5639.65 1 '126'.70 57o I. I0 - r ~ .'80 1 55 5765 55 !Target 880'] .50 =,'>.69 1 '1 70 a(~:~4.0(, =,~S'= 1 . i- ' ¢ ?.- o =o Re' "' -5 7 ..~ 5~ .o ~TD - Csg F't ' -~ 46 4 o, : ~ ,.0 6,_,94.00 - 60,_9 .... '1 '206.:64 ' '6159."17 ................................................................ ...................................................................................... tr,...~.. :......:' ............ '~ ............................................. ~7....: ....................................................... : ........................................................................................................................................................................................................................................................................ '0. O0 0.00i 0.00 0.00' 0.00! o.oo~ 0..00 0.00 0.0.0 Phillips Alaska, Inc. Pad 3F 21 slot #21 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Mughes INTEQ Your ref : 21 Version #6 Our ref : Drop4280 License : Date printed : 29-Nov-2000 Date created : 9-Nov-2000 Last revised : 28-Nov-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on nT0 22 20.956,w149 55 51.299 Slot location is n70 22 19.982,w149 55 45.887 Slot Grid coordinates are N 5985724.482, E 508685.008 Slot local coordinates are 99.00 S 185.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. PGMS <0-8070'>,,7,Pad 3F 21-Nov-1991 PMSS <550 - 8132'>,,19,Pad 3F 5-Mar-1999 PMSS <644 - 7165'>,,17,Pad 3F 5-Mar-1999 PGMS <0-6975'>,,14,Pad 3F 21-Nov-1991 PGMS <0-7570'>,,12,Pad 3F 21-Nov-1991 PGMS<0-6913'>,,4,Pad 3F 21-Nov-1991 PGMS <0-7966'>, 3,Pad 3F 21-Nov-1991 PGMS <0-7864'>, 2,Pad 3F 21-Nov-1991 PMSS <475 - 6868'> ,18,Pad 3F 5-Mar-1999 PGMS <0-8730'>, 1,Pad 3F 21-Nov-1991 PGMS <0-7717'>, 6,Pad 3F 21-Nov-1991 PGMS <0-7050'>, 8,Pad 3F 21-Nov-1991 PGMS <0-7785'>, 9,Pad 3F 21-Nov-1991 PGMS <0-6650'>,,10,Pad 3F 21-Nov-1991 PGMS <0-8600'>,,il,Pad 3F 21-Nov-1991 PGMS <0-8108'>,,13,Pad 3F 8-Apr-1999 PGMS <0-7455'>,,15,Pad 3F 21-Nov-1991 PGMS <0-8600'>,,16,Pad 3F 21-Nov-1991 PMSS <7121-8580'>,,16A.,Pad 3F 5-Mar-1999 PGMS <0-8102> Depth Shifted Nordic III,,13,Pad 30-Aug-1999 PMSS <6594 - 9350'>,,13A, Pad 3F 15-0ct-1999 PGMS <0-8875'>,,5,Pad 3F 5-Mar-1999 PMSS <0-7542'>,,20,Pad 3F 13-Nov-2000 169.1 1063.9 2208.3 336.6 300.0 300.0 462.2 460.0 460.0 381.6 1263.9 1263.9 342.1 1230.6 1230.6 97.4 958.3 958.3 73.6 660.0 660.0 48.8 600.0 600.0 183.5 450.0 450.0 22.3 580.0 580.0 141.7 997.2 997.2 191.7 1086.1 1086.1 262.8 1163.9 1163.9 288.1 1197.2 1197.2 323.3 500.0 500.0 374.8 0.0 660.0 412.6 1252.8 1252.8 447.3 520.0 520.0 4080.6 5700.0 5700.0 374.8 0.0 660.0 374.8 0.0 660.0 55.1 1008.3 1008.3 479.6 0.0 1430.6 RECEIVED 01 £000 ,~laska Oil & Gas Cons. Co~mission Anchorage 3 $ 0 Phillips Alasi..:~,, !nc. Structure : Pod SF Well : 21 Field : Kuporuk River Unif Locafion : North Slope, Alaska ..... 340 TPLIE NORTH 20 50CI 2gO 28O '-~ 70 260 ~'50 510 ,/+ 155! ',, '"" 40" ~ f.~./.¢. 1600 ,, ~250 520 / , '"'w" /t / %., ,' ." .%. ,. + 600 ,, '% 22q0" ..... "x{ "',,, ~ · 2'600.,_ 2800 .:.'~ 20 · .:-I-C) / ,.. . · ./ 4O . -200 2942 ,m ;~ g . "~ 'i O0 ., 18~0 20,0': ~ 'soo 60,. <~7.1/un exr~,~,:.j '~' 90 "80 ' 70 No ..... ot P one Trovel 'nc C'~ 'nae.- - Feet Al. 3eotns st-'cw''~ ore V]eosLireo CleDtns on Reference Wel RECEIVED .DECO 1 2000 Alaska Oil & Bas Cons. Commission Anchorage, INTEQ Internal Use ONLYi Safety Criteria Applied: 1.5% * MD from 0-3333' MD, 50' thereafter. Safety Criteria violation indicated by 'DANGER!'. Warning Criteria Applied: 0.005 * MD. Warning Criteria violation indicated by 'Warning!'. Phillips Alaska, Inc. Pad 3F 21 slot %21 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 21 Version #6 Our ref : prop4280 License : Date printed : 29-Nov-2000 Date created : 9-Nov-2000 Last revised : 29-Nov-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 22 20.956,w149 55 51.299 Slot location is n70 22 19.982,w149 55 45.887 Slot Grid coordinates are N 5985724.482, E 508685.008 Slot local coordinates are 99.00 S 185.00 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 7A Version #2,,7A,Pad 3F PGMS <0-8070'>,,7,Pad 3F PMSS <550 - 8132'>,,19,Pad 3F PMSS <644 - 7165'>,,17,Pad 3F PGMS <0-6975'>,,14,Pad 3F PGMS <0-7570'>,,12,Pad 3F PGMS <0-6913'>,,4,Pad 3F PGMS <0-7966'>,,3,Pad 3F PGMS <0-7864'>,,2,Pad 3F PMSS <475 -6868'>,,18,Pad 3F PGMS <0-8730'>,,1,Pad 3F PGMS <0-7717'>,,6,Pad 3F Closest approach with 3-D Minimum Distance method Last revised Distance il-Aug-2000 )90 21-Nov-1991 )158 5-Mar-1999 )333 5-Mar-1999 )457 21-Nov-1991 )368 21-Nov-1991 )329 21-Nov-1991 )88 21-Nov-1991 )66. 21-Nov-1991 )42. 5-Mar-1999 )179. 21-Nov-1991 )18. 21-Nov-1991 )132. INTEQ Internal Use M.D. 1( 8420.0 8420 9( 1230.6 2241 3 ( 371.4 2941 7( 480.0 480 7( 1341.7. 1341 9( 1286.1 1286 6( 1019.4 1019 7( 871.4 871 8( 780.0 7660 5( 480.0 480 0( 580.0 580 5( 1052.8 1052 ONLY! Diverging from M.D. Req'd Sep. Status .0 50.0 Warning! .7 18.5 OK .6 5.6 OK .0 7.2 OK .7 20.1 OK .1 19.3 OK 4 15.3 OK 4 13.1 OK 0 11.7 OK 0 7.2 OK 0 8.7 OK 8 15.8 OK RECEIVED DEC O1 000 Alaska Oil & Gas Cons. Commission Anchorage INTEQ Internal Use ONLY! PGMS <0-7050'>,,8,Pad 3F 21-Nov-1991 PGMS <0-7785'>,,9,Pad 3F 21-Nov-1991 )252 PGMS <0-6650'>,,10,Pad 3F 21-Nov-1991 )276 PGMS <0-8600'>,,il,Pad 3F 21-Nov-1991 )319 PGMS <0-8108'>,,13,Pad 3F 8-Apr-1999 )369 PGMS <0-7455'>,,15,Pad 3F 21-Nov-1991 )400 PGMS <0-8600'>,,16,Pad 3F 21-Nov-1991 )442 PMSS <7121-8580'>,,16A, Pad 3F 5-Mar-1999 )4080 PGMS <0-8102> DeDth Shifted Nordic III,,13,Pad 30-Aug-1999 )369 PMSS <6594 - 9350'>,,13A, Pad 3F 15-0ct-1999 )369 PGMS <0-8875'>,,5,Pad 3F 5-Mar-1999 )47 PMSS <0-7542'>,,20,Pad 3F 13-Nov-2000 )479 )181 5( 6( 4( 0( 8( 7( 1141.7 1186.1 1252.8 520.0 720.0 1286.1 9( 540.0 6( 5700.0 9( 720.0 9( 720.0 4( 1008.3 0( 220.0 1141.7 1186.1 1252.8 520.0 720.0 1286.1 8020.0 7380.0 720.0 9040.0 1008.3 1463.9 17.1 OK 17.8 OK 18.8 OK 7.8 OK 10.8 OK 19.3 OK 8.1 OK 50.0 OK 10.8 OK 10.8 OK 15.1 OK 3.3 OK INTEQ Internal Use ONLY! RECEIVED DEC 0 1 ,?.000 Alaska Oil & Gas Cons. CommJssjor~ Anchor~e INTEQ Internal Use ONLY! M.D. 8400.0 Reference wellpath T.V.D. Rect Coordinates 5850.6 5340.7N 1067.0E Object wellpath : 7A Version ~2,,TA,Pad 3F Horiz Min'm M.D. T.V.D. Rect Coordinates Bearing Dist 8691.5 5903.5 5292.0N 676.0E 262.9 397.6 ElliDse Sep'n Req'd Sep. Status )90.3( 50.0 Warning! INTEQ Internal Use ONLY! RECEIVED DEC 01 2000 Alaska 0ii & Gas cons. Commission Anchorage Phillips Alaska, Inc. Pad 3F 21 slot #21 KuDaruk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 21 Version #6 Our ref : prop4280 License : Date printed : 29-Nov-2000 Date created : 9-Nov-2000 Last revised : 29-Nov-2000 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on n70 22 20.956,w149 55 51.299 Slot location is n70 22 19.982,w149 55 45.887 Slot Grid coordinates are N 5985724.482, E 508685.008 Slot local coordinates are 99.00 S 185.00 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 seDaration 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 7A Version #2,,7A, Pad 3F PGMS <0-8070'>,,7,Pad 3F PMSS <550 - 8132'>,019,Pad 3F PMSS <644 - 7165'>,,17,Pad 3F PGMS <0-6975'>,,14,Pad 3F PGMS <0-7570'>,,12,Pad 3F PGMS <0-6913'>,,4,Pad 3F PGMS <0-7966'>,,3,Pad 3F PGMS <0-7864'>,,2,Pad 3F PMSS <475 - 6868'>,,18,Pad 3F PGMS <0-8730'> ,1 Pad 3F PGMS <0-7717'> PGMS <0-7050'> PGMS <0-7785'> PGMS <0-6650'>, PGMS <0-8600'>, PGMS <0-8108'>, PGMS <0-7455'>, PGMS <0-8600'>, PMSS <7121-8580'> Closest approach with 3-D Minimum Distance method Last revised Distance ,6 Pad 3F ,8 Pad 3F ,9 Pad 3F 10 Pad 3F 11 Pad 3F 13 Pad 3F 15 Pad 3F 16 Pad 3F ,16A, Pad 3F 5-Mar-1999 Il-Aug~2000 21-Nov~1991 5-Mar~1999 5-Mar-1999 21-Nov-1991 21-Nov-1991 21-Nov-1991 21-Nov~1991 21-Nov-1991 5-Mar-1999 21-Nov-1991 21-Nov-1991 21-Nov-1991 21-Nov-1991 21-Nov-1991 21-Nov-1991 8-Apr-1999 21-Nov~1991 21-Nov-1991 PGMS <0-8102> Depth Shifted Nordic III,,13,Pad 30-Aug-1999 PMSS <6594 - 9350'>,,13A, Pad 3F 15-0ct-1999 PGMS <0-8875'>,,5,Pad 3F 5-Mar-1999 PMSS <0-7542'>,,20,Pad 3F 13-Nov-2000 )90 1( )158 9( )333 3( )457 7( )368 7( )329 9( )88 6( )66 7( )42 8( )179 5( )18 0( )132 5( )181 5( )252 6( )276.'4( )319.0( )369.8( )400.7( )442.9( )4080.6( )369.9( )369.9( )47.4( )479.0( M.D. 8420.0 8420 1230.6 2241 371.4 2941 480.0 480 1341.7 1341 1286.1 1286 1019.4 1019 871.4 871 780.0 7660 480.0 480 580,0 580 1052.8 1052 1141.7 1141 1186.1 1186 1252.8 1252 520.0 520 720.0 720 1286.1 1286 540.0 8020 5700.0 7380 720.0 720 720.0 9040 1008.3 1008 220.0 1463 Diverging from M.D. RECEIVED DEC 01 2000 Alaska Oil & Gas Cons. Commission Anchoraoe Phillips Alaska, Inc. Pad 3F,21 Kuparuk River Unit,North Slope, Alask~ Reference wellpath CLEARANCE LISTING ~ ~ 2 Your ref : 21 V~ on #6 Last revised : 29-Nov-2000 Object wellpath : 7A Version #2,,TA, Pad 3F M.D. T.V.D. Rect Coordinates M.D. T.V.D. 7400.0 5244.5 4560.7N 911.1E 7673.3 5758.7 7500.0 5305.1 4638.7N 926.7E 7767.4 5798.5 7600.0 5365.7 4716.7N 942.3E 7958.5 5867.8 7700.0 5426.3 4794.7N 957.9E 8152.7 5890.7 7800.0 5486.9 4872.7N 973.5E 8229.7 5892.5 7900.0 5547.6 8000.0 5608.2 8100.0 5668.8 8200.0 5729.4 8300.0 5790.0 8400 0 5850.6 8500 0 5911.2 8600 0 5971.9 8700 0 6032 5 8800 0 6093 1 8900 0 6153 7 9000 0 6214 3 9100 0 6274 9 9200.0 6335 6 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 4305.2N 795.7E 204.3 585.7 )489.6( 4389.8N 785.4E 209.6 570.4* )469.9( 4566.3N 764.0E 229.9 553.6* )449.8( 4757.2N 740.8E 260.2 513.9' )400.4( 4833.6N 731.6E 260.8 473.8* )345.5( 4950.7N 989.1E 8306.7 5894.3 4910.0N 5028.7N 1004.6E 8383.6 5896.2 4986.4N 5106.7N 1020.2E 8460.6 5898.0 5062.8N 5184.7N 1035.8E 8537.6 5899.8 5139.2N 5262.7N 1051.4E 8614.6 5901.7 5215.6N 5340.7N 1067.0E 8691.5 5903.5 5292.0N 5418.7N 1082.5E 8768.5 5905.3 5368.3N 5496.7N 1098.1E 8845.5 5907.2 5444.7N 5574.6N 1113.7E 8922.5 5909.0 5521.1N 5652.6N 1129.3E 8999.4 5910.8 5597.5N 5730.6N 1144.9E 9076.4 5912.7 5673.9N 5808.6N 1160.5E 9153.4 5914.5 5750.3N 5886.6N 1176.0E 9230.3 5916.3 5826.7N 5964.6N 1191.6E 9299.6 5918.0 5895.4N 722.3E 713.0E 703.8E 694.5E 685.2E 676.0E 666.7E 657 4E 648 2E 638 9E 629 6E 620 4E 611 1E 602 7E 261.3 261.7 262.1 262.4 262 7 262 9 263 1 263 3 263 4 263 6 263 7 263 8 263 9 263 3 439.4* )291.8 412.0' )239.7 393.2* )190.2 384.2* )145.0 385.7 )108.4 397.6 )90.3 418.9 )101.5 448.4 )136.8 484.6 )184.4 526.1 )237.8( 571.7 )294.2( 620.5 )352.5( 671.8 )411.8( 725.2 )473.2( Phillips Alaska, Inc. Pad 3F,21 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 3 Your ref : 21 Version #6 Last revised : 29-Nov-2000 Reference wellpath Object wellpath : PGMS <0-8070'>,,7,Pad 3F M.D. T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 0.0 0.0 100.0 100.0 ' 200.0 200.0 300.0 300.0 400.0 400.0 500.0 499.8 600.0 599.7 700.0 699.6 800.0 799.4 900.0 899.2 1000.0 998.8 1100.0 1097.7 1200.0 1195.8 1300.0 1292.7 1400.0 1388.2 1500.0 1482.0 1600.0 1573.9 1700.0 1663.5 1800.0 1750.8 1900.0 1835.3 2000.0 1917.0 2100.0 1995.5 2200.0 2070.7 2300.0 2142.3 2400.0 2210.2 2500.0 2274.1 2600.0 2334.9 2700.0 2395.6 2800.0 2456.2 2900.0 2516.8 3000.0 2577.4 3100.0 2638.0 3200.0 2698.6 3300.0 2759.2 3400.0 2819.9 3500.0 2880.5 3600.0 2941.1 3700.0 3001.7 3800.0 3062.3 3900.0 3122.9 4000.0 3183.6 4100.0 3244.2 4200.0 3304.8 4300.0 3365.4 4400.0 3426.0 4500.0 3486.6 4600.0 3547.2 4700.o 3607.9 4800.0 3668.5 4900.0 3729.i 5000.0 3789.7 0.0N 0.0E 0.0N 0.0E 0.0N 0.0E 0.3N 0.1E 2.9N 0.6E 7.7N 1.5E 12.8N 2.6E 18.0N 3.6E 23.1N 4.6E 29.5N 5.9E 38.8N 7.8E 52.9N 10.6E 72.0N 14.4E 96.1N 19.2E 125.2N 25.0E 159.1N 31.8E 197.9N 39.5E' 241.2N 48.2E 289.1N 57.8E 341.5N 68.2E 398.0N 79.5E 458.7N 91.6E 523.4N 104.6E 591.8N 118.2E 663.8N 132.6E 739.2N 147.7E 817.0N 163.2E 895.0N 178.8E 973.0N 194.4E 1051.0N 210.0E 1129.0N 225.6E 1207.0N 241.1E 1285.0N 256.7E 1363.0N 272.3E 1441.0N 287.9E 1519.0N 303.5E 1597.0N 319.0E 1675.0N 334.6E 1753.0N 350.2E ' 1831.0N 365.8E 1908.9N 381.4E 1986.9N 397.0E 2064.9N 412.5E 2142.9N 428.1E 2220.9N 443.7E 2298.9N 459.3E 2376.9N 474.9E 2454.9N 490.4E 2532.9N 506.0E 2610.9N 521.6E 2688.9N 537.2E 7.2 0.2 107.8 100.8 207.6 200.6 307.2 300.2 407.3 400.3 507.1 500.1 606.8 599.8 706.8 699.8 806.5 799.5 906.7 899.7 1006.3 999.3 1106.1 1099.0 1207.0 1199.6 1306.2 1298.0 1403.8 1394.4 1505.6 1493.9 1611.5 1596.2 1720.6 1699.6 1833.1 1803.3 1939.7 1898.5 2051.6 1994.8 2158.2 2082.5 2261.8 2164.6 2361.5 2241.7 2459.8 2316.2 2565.1 2394.6 2669.5 2469.7 2766.8 2539.5 2863.2 2609.4 2959.3 2679.6 3054.4 2749.7 3148.9 2820.2 3244.7 2892.5 3337.8 2963.6 3430.9 3035.4 3526.5 3109.9 3637.9 3195.1 3747.2 3276.7 3857.5 3356.6 3975.8 3439.7 4080.6 3510.8 4182.2 3579.1 4282.7 3646.5 4381.4 3712.5 4480.0 3778.8 4578.0 3844.7 4676.4 3911.0 4776.8 3978.8 4876.1 4045.6 4972.4 4110.7 5070.7 4177.5 71.0N 71.0N 71.2N 71.5N 71.9N 72.2N 72.5N 72.8N 72.9N 73.1N 73.5N 76.6N 84.6N 96.2N lll. SN 132.8N 159.5N 19~.3N 234.3N 279.3N 332.9N 389.4N 448.4N 508.7N 570.7N 639.4N 709.6N 775.1N 839.3N 902.6N 964.7N 1025.5N 1086.2N 1144.2N 1201.2N 1259.1N 1328.2N 1398.4N 1471.5N 1552.1N 1625.7N 1697.6N 1769.1N 1839.3N 1909.3N 1978.7N 2048.3N 2119.3N 2189.6N 2257.5N 2326.'6N 161.0W 293.8 176.0 160.7W 293.9 175.7' 160.1W 294.0 175.2' 159.7W 294.0 174.9' 159.4W 293.4 174.2' 159.0W' 291.9 173.1' 158.8W 290.3 172.1' 158.6W 288.7 171.2' 158.5W 287.0 170.6' 158.3W 284.9 169.9' 157.9W 281.8 169.2' 156.9W 278.1 169.1' 154.6W 274.3 169.5 151.4W 270.0 170.7 149.0W 265.6 174.6 146.6W 261.6 180.7 142.0W 258.1 186.9 133.4W 255.2 191.2 118.8W 252.8 192.2 102.6W 250.0 192.4 82.8W 248.1 191.5' 60.9W 245.5 188.9' 38.9W 242.4 187.2' 19.5W 238.9 189.2 3.7W 235.7 196.2 ll.6E 233.7 207.3 29.7E 231.2 218.0 47.3E 227.6 228.9 64.7E 224.1 241.2 81.7E 220.8 254.9 98.2E 217.8 270.1 114.3E 214.9 286.7 130.6E 212.4 304.9 146.4E 209.9 324.8 162.2E 207.7 346.1 178.2E 205.7 368.6 197.2E 204.4 389.4 216.4E 203.1 407.6 237.1E 201.9 422.6 261.3E 200.5 434.8 284.1E 199.0 443.6 306.0E 197.5 451.9' 327.3E 196.1 459.9 348.2E 194.7 468.0 369.4E 193.4 476.5 390.5E 192.1 485.2 411.4E 190.9 494.3 432.6E 189.8 503.6 453.7E 188.7 512.7 474.3E 187.6 522.2 495.3E 186.6 532.3 N/A 174.8 173.5 172.3 170.8 168.7 166.9 165.1 163.6 161.9 160.3 159.5 159.0 159.2 161.8 166.4 170.9 173.3 172.2 170.3 167.2 162.7 159.3 159.7 165.1 174.7 184.3 194.3 205.7 218.6 232.8 248.5 265.7 284.5 304.8 326.1 345.6 362.5 376.1 386.8 394.2 400.8 407.1 ')413.4 )420,0 )426.9 )434.0( )441.3( )448.3( )455.7( )463.7( RECEIVED DEC 0 1 000 ~mska Oil& {~s' Cons. Commis Anchor~e Phillips Alaska, Inc. / Pad 3F,21 Kuparuk River Unit,North Slope, Ala ~ CLEARANCE LISTING j e 4 Your ref : 21 V~ on #6 Last revised : 29-Nov-2000 Reference wellpath Object wellpath : PGMS <0-8070'>,,7,Pad 3F M.D. T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 5100.0 3850.3 2766.9N 5200.0 3910.9 2844.9N 5300.0 3971.6 2922.9N 5400.0 4032.2 3000.9N 552.8E 5170.4 4245.1 568.4E 5273.6 4314.9 583.9E 5376.1 4383.7 599.5E 5474.5 4449.5 2396.6N 2469.4N 2542.1N 2612.0N 516.6E 185.6 542.4 )471.6( 538.6E 184.5 552.4 )479.3( 560.7E 183.5 561.6 )486.3( 582.2E 182.6 570.7 )493.0( Phillips Alaska, Inc. Pad 3F,21 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 5 Your ref : 21 Version #6 Last revised : 29-Nov-2000 Reference wellpath Object wellpath : PMSS <550 - 8132'>,,19,Pad 3F M.D. T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 0.0 0 0 100.0 100 0 200.0 200 0 300.0 300 0 400.0 400 0 500.0 499 8 600.0 599 7 700.0 699 6 800.0 799 4 900.0 899 2 1000 0 998 8 1100 0 1097 7 1200 0 1195 8 1300 0 1292 7 1400 0 1388 2 1500 0 1482 0 1600.0 1573 9 1700.0 1663 5 1800.0 1750 8 1900.0 1835 3 0.0N 0.0N 0.0N 0.3N 2.9N 7.7N 12.8N 18.0N 23.1N 29.5N 38.8N 52.9N 72.0N 96.1N 125.2N 159.1N 197.9N 241.2N 289.1N 341.5N 0 0E 10.0 0 0 0 0 1 2 3 4 5 7 10 14 19 25 31 0.0 0E 110.0 100.0 0E 212 . 6 202 . 6 1E 309.4 299.4 6E 401.0 390.8 5E 490.6 479.5 6E 584.1 571.1 6E 679.0 663.4 6E 772 . 5 754 . 0 9E 864.5 842.4 8E 952.8 926.5 6E 1038 . 6 1007 . 1 4E 1125.6 1087 . 4 2E 1210.4 1163.8 0E 1303.7 1246.2 8E 1394.1 1325.3 136 0N 136 ON 136 0N 136 7N 142 2N 154 iN 173 iN 194 8N 218 ON 243 4N 270 ON 299 5N 332 9N 369 6N 413 2N 456 7N 39 5E 1474.9 1394.8 497 9N 48 2E 1559.5 1465.7 544 iN 57 8E 1644.1 1535.0 592 5N 68.2E 1724.3 1599.0 640.8N 309.0W 293.8 337.6 N/A 309.0W 293.8 337.6* )336 6( 308.5W 293.8 337.1' )335 307.7W 293 9 336.6* )333 306.5W 294 305.5W 295 303.5W 297 301.1W 300 298.8W 302 296.3W 305 294.0W 307 292.5W 309 291.0W 310 288.9W 311 285.2W 312 281.7W 313 279.6W 313 278.2W 312 277.2W 312 276.6W 311 4 337.4 )333 5 340.8 )336 6 346.7 )341 1 354.1 )348 7 363.5 )357 3 374.5 )367 5 386.9 )378 1 401.1 )391 5 416.1 )405 6 431.6 )419 9 446.4 )432 5 459.7 )443 2 473.3 )455 9 487.3 )467 2 500.8 )478 0 514.2 )489 Phillips Alaska, Inc. Pad 3F,21 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 6 Your ref : 21 Version #6 Last revised : 29-Nov-2000 Reference wellpath Object wellpath : PMSS<644 - 7165'>,,17,Pad 3F 400 500 6O0 700 80O 9O0 1000 1100 1200 M.D. T.V.D. 0 0 0.0 100 0 100.0 200 0 200.0 300 0 300.0 0 400.0 0 499.8 0 599.7 0 699.6 0 799.4 0 899.2 0 998.8 0 1097.7 0 1195.8 Rect Coordinates 0.0N 0.0N 0.0N 0 3N 2 9N 7 7N 12 8N 18 ON 23 iN 29 5N 38 8N 52 9N 72 0N M.D. T.V.D. 0.0E 10.0 0 0 0.0E 110.0 100 0 0.0E 212.2 202 2 0.1E 313.6 303 6 0.6E 408.4 398 3 1.5E 501.8 491 7 2 . 6E 594 . 0 583 6 3.6E 688.3 677 5 4.6E 788.7 777 5 5 ~ 9E 888.9 877 2 7.8E 981.7 969.6 10.6E 1067.3 1054.7 14 . 4E 1140.9 1127 . 6 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 187.0N 425.0W 293 7 464 3 N/A 187.0N 425.0W 293 7 464 186.7N 424.9W 293 7 464 185.4N 424.5W 293 6 463 183.1N 425.3W 292 9 462 179.5N 427.6W 291 8 462 432.0W 290 5 464 174.9N 169.2N 438.4W 288.9 467 162.7N 445.5W 287.2 471 155.9N 452.3W 285.4 475 149.4N 458.7W 283.3 480 143.8N 466.1W 280.8 487 139.3N 474.9W 277.8 498 3* )463 3( 1' )462 1( 2* )460 2( 4* )458 5( 3* )457 8( 0 )459 2( 7 )462 4( 8 )466 0( 8 )469 6( 3 )473.4( 2 )479.6( 6 )490.2( ,ECEIVED DEC 0 2000 Alaska Oil & Gas Cons. Anchorage Phillips Alaska, Inc. $ Pad 3F,21 Kuparuk River Unit,North Slope, Alaska CLEARA/~CE LISTING Page 7 ~ Your ref : 21 V~ ~n #6 Last revised : 29-Nov-2000 Reference wellpath Object wellpath : PGMS <0-6975'>,,14,Pad 3F M.D. T.V.D. Rect Coordinates M.D. T.V.D. 0 0 0O 100 0 100 0 200 0 200 0 300 0 300 0 400 0 400 0 500 0 499 8 600.0 599 7 700.0 699 6 800.0 799 4 900.0 899.2 1000.0 998.8 1100.0 1097.7 1200.0 1195.8 1300.0 1292.7 1400.0 1388.2 1500.0 1482.0 1600.0 1573.9 1700.0 1663.5 1800.0 1750.8 1900.0 1835.3 2000.0 1917.0 0.0N 0.0N 0.0N 0.3N 2.9N 7.7N 12.8N 2 18.0N 3 23.1N 4 29.5N 5 38.8N 7 52.9N 10 72.0N 14 96.1N 19 125.2N 25 159.1N 31 197.9N 39 241.2N 48 289.1N 57 341.5N 68 398.0N 79 0 0E 0 0 0 0 1 7.3 0.3 0E 108.2 101.2 0E 208.3 201.3 1E 309.4 302.4 6E 410.1 403.1 5E 509.9 502.8 6E 609.7 602.6 6E 709.8 702.8 6E 810.6 803.6 9E 911.1 904.1 8E 1010.6 1003.5 6E 1108.8 1101.7 4E 1205.0 1198.0 2E 1301.9 1294.8 0E 1397.6 1390.5 8E 1491.8 1484.7 5E 1584.1 1577.0 2E 1674.0 1666.9 8E 1758.8 1751.7 2E 1842.3 1835.2 5E 1924.2 1917.2 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 161.0N 160.9N 160.6N 160.2N 159.6N 159.1N 364.2W 292 158.6N 363.6W 291 158.1N 363.0W 290 157.5N 362.3W 290 156.8N 361.3W 289 156.2N 360.2W 287 155.6N 359.1W 285 155.0N 358.4W 282 154.4N 358.0W 278 153.9N 357.5W 274 153.5N 356.9W 269 153.3N 356.2W 263 153.0N 355.4W 257 152.6N 354.7W 251 152.0N 354.4W 245 151.6N 354.2W 240 366.0W 293.7 399.8 N/A 365.9W 293.7 399.7* )398.8( 365.7W 293.7 399,4* )397.6( 365.4W 293.6 398.9* )396.3( 364.9W 293 2 397.7* )394.2( 5 395.9* )391.6( 7 394.2* )388 9( 9 392 5* )386 4( 1 390 1 388 7 386 5 383 6 381 8 381 3 383 2 388 6 398 7 413 8* )383 7* )380 3* )377 7* )373 9* )370 7* )368 6 )369 8 )372 2 )380 1 )393 7 434.5 )413 9 463.1 )440 4 498.9 )474.6 Phillips Alaska, Inc. Pad 3F,21 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 8 Your ref : 21 Version #6 Last revised : 29-Nov-2000 Reference wellpath Object wellpath : PGMS <0-7570'>,,12,Pad 3F M.D. T.V.D. Rect Coordinates M.D. T.V.D. 0.0 0.0 100.0 100.0 200.0 200.0 300.0 300.0 400.0 400.0 500.0 499.8 600.0 599.7 700.0 699.6 800.0 799.4 900.0 899.2 1000.0 998.8 1100.0 1097.7 1200.0 1195.8 1300.0 1292.7 1400.0 1388 2 1500.0 1482 0 1600.0 1573 9 1700.0 1663 5 1800.0 1750 8 1900.0 1835 3 0.0N 0.0N 0.0N 0.3N 2.9N 7.7N 12.8N 18.0N 23.1N 29.5N 38.8N 52.9N 72.0N 96.1N 125.2N 159.1N 197.9N 241.2N 289.1N 341.5N 0.0E 6.8 -0.2 0.0E 106 . 3 99 . 3 0.0E 206.1 199 . 1 0.1E 305.9 298 . 9 0.6E 405.7 398.7 1.5E 505.4 498.4 2.6E 605.2 598.2 3 . 6E 705.4 698 . 4 4.6E 806.5 799.5 5.9E 908.4 901.4 7 . 8E 1008.8 1001 . 8 10.6E 1107 . 6 1100.6 14.4E 1203.8 1196.7 19.2E 1299.9 1292.9 25.0E 1387 . 1 1380.1 31.8E 1469.2 1462.1 39.5E 1550.4 1543.1 48.2E 1627.2 1619.5 57 . 8E 1690.6 1682 . 3 68.2E 1755.5 1746.1 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 141.0N 141.0N 141.1N 141.4N 141.5N 141.6N 141.6N 141.7N 141.9N 142 0N 142 2N 142 iN 141 7N 141 3N 141 3N 141 9N 142 3N 141 4N 139 5N 136 4N 321.0W 293.7 350.6 N/A 321.1W 293.7 350.7 )349.8 321.3W 293.7 350.9 )349.2 321.5W 293.7 351.1 )348.6 321.8W 293.3 350.9* )347.5 322.1W 292.5 350.3* )346.0 322.6W 291.6 349.7* )344.5 323.0W 290.8 349.2* )343.2 323.2W 289.9 348.7* )341.7 322.9W 288.9 347.5* )339.6 322.1W 287.4 345.7* )336.7 321.2W 285.0 343.5* )333.5 320.6W 281.8 342.2* )330.8 320.5W 277.6 342.7 )330.0 321.6W 272.7 347.1 )333.2 324.7W 267.2 357.4 )342.2 330.0W 261.5 375.0 )358.5 337.7W 255.5 401.0 )383.1 346.3W 249.7 436.3 )417.3 357.6W 244.3 480.9 )460.8 Phillips Alaska, Inc. Pad 3F,21 Kuparuk River Unit,North Slope, Alaska Reference wellpath CLEARANCE LISTING Page 9 Your ref : 21 Version ~6 Last revised : 29-Nov-2000 M.D. T.V.D. 0.0 0 0 100 0 100 0 200 0 200 0 300 0 300 0 400 0 400 0 500 0 499 8 600 0 599 7 700 0 699 6 800 0 799 4 900 0 899.2 1000 0 998.8 1100 0 1097.7 1200 0 1195.8 1300 0 1292.7 1400 0 1388.2 1500 0 1482.0 1600 0 1573 . 9 1700 ..0 1663.5 1800.0 1750.8 1900.0 1835.3 2000.0 1917.0 2100.0 1995~5 Object wellpath : PGMS <0-6913'>,,4,Pad 3F Rect Coordinates 0.0N 0.0N 0.0N 0.3N 2.9N 7.7N 12.8N 18.0N 23. iN 29.5N 38.8N 52.9N 72.0N 96.1N 125.2N 159.1N 197.9N 241.2N 289.1N 341.5N 398.0N 458.7N 0.0E 0.0E 107 0.0E 207 0.1E 306 0 6E 406 1 5E 5O6 2 6E 606 3 6E 706 4 6E 806 M.D. T.V.D. 71 01 2 100 2 0 200 0 8 299 8 8 399 8 7 499 7 6 ' 599 6 8 699 8 8 799 8 5 9E 907.1 900 1 7 8E 1006.8 999 8 10 6E 1105.9 1098 8 14 4E 1203.9 1196 9 19 2E 1300.7 1293 6 25 0E 1396.2 1389.2 31 8E 1489.9 1482.9 39.5E 1581.9 1574.9 48.2E 1672.2 1665.2 57.8E 1763.1 1756.0 68.2E 1851.5 1844.4 79.5E 1935.6 1928.5 91.6E 2017.2 2010.0 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 40.0N 40.0N 39.8N 39.7N 39.8N 40.1N 40.8N 41.7N 42.4N 43.1N 43.7N 44.5N 45.7N 46.9N 47.7N 48.3N 48.8N 49.4N 50.4N 52.2N 54.1N 56.1N 92.0W 293.5 100.3 91.9W 293.5 100.2' 91.8W 293.5 100.0' 91.9W 293.2 100.0' 92.0W 291.7 99.7* 92.1W 289.1 99.1' 92.0W 286.5 98.6* 91.7W 284.0 98.2* 91.4W 281.4 97.9* 90.7W 278.0 97.5* 89.7W 272.9 97.6 88.6W 265.2 99.5 87.6W 255.6 1'05.4 N/A 99.3 98.3 97.4 96.3 94.8 93.4 92.1 90.9 89.6 88.6 89.5 94.2 87.0W 245.1 117.1 )104.8 86.6W 235.2 135.9 )122.6 86.4W 226.8 162.0 )147.8 86.2W 220.2 195.0 )179.8 86.1W 215.0 234.2 )218.1 85.9W 211.0 278.6 )261.9 84.9W 207.9 327.4 )310.2 83.3W 205.3 380.8 )362.9 81.4W 203.3 438.5. )420.0 RECEIVED DEC 0 1 000 ~,l.aska Oil & Gas.Cons. Commis,, Anchorage 2200.0 2070.7 523.4N 104.6E 2094.0 2086.8 57.9N 79.4W 201.6 500.7 )481.6( Phillips Alaska, Inc. CLEARANCE LISTING Page 10 Pad 3F,21 Your ref : 21 Version #6 Kuparuk River Unit,North SIope, Alaska Last revised : 29-Nov-2000 Reference wellpath Object wellpath : PGMS <0-7966'>, ,3,Pad 3F M.D. T.V.D. Rect Coordinates M.D. T.V.D. Moriz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 0.0 0.0 0.0N 0.0E 7.0 0.0 30.0N 100.0 100.0 0.0N 0.0E 107.0 100.0 29.8N 200.0 200.0 0.0N 0.0E 207.0 200.0 29.6N 300.0 300.0 0.3N 0.1E 307.0 300.0 29.4N 400.0 400.0 2.9N 0.6E 406.9 399.9 29.2N 500.0 499.8 7.7N 1.5E 506.9 499.9 29.1N 600.0 599.7 12.8N 2.6E 606.8 599.8 29.1N 700.0 699.6 18.0N 3.6E 706.7 699.7 29.0N 800.0 799.4 23.1N 4.6E 806.6 799.6 29.1N 900.0 899.2 29.5N 5.9E 906.5 899.5 29.3N 1000.0 998.8 38.8N 7.8E 1006.1 999.1 29.4N 1100.0 1097.7 52.9N 10.6E 1104.5 1097.5 28.9N 1200.0 1195.8 72.0N 14.4E 1200.3 1193.2 25.2N 1300.0 1292.7 96.1N 19.2E 1293.8 1286.3 17.3N 1400.0 1388.2 125.2N 25.0E 1381.9 1373.7 6.0N 1500.0 1482.0 159.1N 31.8E 1466.0 1456.4 8.0S 1600.0 1573.9 197.9N 39.5E 1543.2 1532.0 23.1S 1700.0 1663.5 241.2N 48.2E 1612.4 1599.1 39.05 1800.0 1750.8 289.1N 57.8E 1672.2 1656.5 55.2S 1900.0 1835.3 341.5N 68.2E 1722.6 1704.2 70.85 69.0W 293.5 75.2 N/A 69.1W 293.3 75.3 )74.4( 69.2W 293.1 75.2* )73.5( 69.2W 292.8 75.1' )72.5( 69.3W 290.7 74.7* )71.2( 69.4W 286.8 74.1' )69.7( 69.3W 282.7 73.7* )68.5( 69.2W 278.6 73.6* )67.5( 69.0W 274.7 73.9 )66.9( 68.8W 269.9 74.7 )66.7( 68.3W 263.0 76.7 )67.8( 68.0W 253.0 82.2 )72.3( 67.5W 240.3 94.4 )83.9( 66.2W 227.3 116.5 )105.5( 63.5W 216.6 149.2 )137.8( 59.1W 208.5 191.9 )180.1( 53.6W 202.8 243.4 )231.1( 48.2W 199.0 303.3 )290.5( 43.4W 196.4 371.0 )357.8( 39.3W 194.6 445.8 )432.1( Phillips Alaska, Inc. Pad 3F,21 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 11 Your ref : 21 Version #6 Last revised : 29-Nov-2000 Reference wellpath Object wellPath: PGMS <0-7864'>,,2,Pad 3F M.D. T.V.D. 0.0 0.0 100.0 100.0 200.0 200.0 300.0 300.0 400.0 400.0' Rect Coordinates M.D. T.V.D. 0.0N 0.0E 7.0 0.0 0.0N 0.0E 107.0 100.0 0.0N 0.0E 207.1 200.1 0.3N 0.1E 307.0 300.0 2.9N 0.6E 407.0 400.0 500.0 499.8 7.7N 1.5E 506.9 499~9 600.0 599.7 12.8N 2.6E 606.8 599.8 700.0 699.6 18.0N 3.6E 706.7 699.7 800.0 799.4 23.1N 4.6E 806.6 799.6 900.0 899.2 29.5N 5.9E 906.5 899.5 1000.0 998.8 38.8N 1100.0 1097.7 52.9N 10.6E 1106 1200.0 1195.8 72.0N 14.4E 1205 1300.0 1292.7 96.1N 19.2E 1302 1400.0 1388.2 125.2N 25.0E 1397 1500.0 1482.0 159.1N 31.8E 1485 1600.0 1573.9 197.9N 39~5E 1568 1700.0 1663.5 241.2N 48.2E 1643 1800.0 1750.8 289.1N 57.8E 1707 1900.0 1835.3 341.5N 68.2E 1770 2000.0 1917.0 398.0N 79.5E 1826 7.8E 1006 5 999.5 8 1099.7 7 1198.0 8 1293 9 3 1386 4 6 1471 8 9 1551 1 6 1620 9 7 1679 6 1 1735 6 7 1785 8 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 21. ON 21.0N 20.9N 20.8N 20.7N 20.6N 20.4N 20.2N 20.0N 19.8N 19.0N 16.3N ll.4N 5.9N 0.SN 4.7S 1114S 19.1S 27.75 37.9S 46.0W 294.5 50.6 N/A 46.0W 294.5 50.6* )49.7( 46.0W 294.5 50.5* )48.8( 45.9W 294.0 50.3* )47.7( 45.9W 291.0 49.7* )46.3( 45.8W 285.2 49.1' )44.8( 45.7W 278.9 48.8* )43.6( 45.4W 272.6 49.1 )43.0( 45.1W 266.5 49.8 )42.8( 44.7W 259.1 51.5 )43.6( 43.6W 248.9 55.1 )46.7( 39.5W 233.8 62.1 )53.2( 30.1W 216.3 75 3 )66.0( '16.0W 201.3 96 9 )87.2( 2.5E 190.3 126 5 )116.1( 24.2E 182.6. 164 3 )153 0( 48.6E 177.5 210 7 )198 2( 74.0E 174.3 265 0 )251 2( 98.4E 172,7 327 3 )312 2( 123.8E 171.7 396 2 )379 7( 48.65 148..0E 171.3 470 5 )452 7( Phillips Alaska, Inc. Pad 3F,21 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 12 Your ref : 21 Version #6 Last revised : 29-Nov-2000 Reference wellpath Object wellpath : PMSS <475 - 6868'>,,18,Pad 3F M.D. T.V.D. 0.0 0.0 i00.0 100.0 200.0 200.0 300 0 300.0 400 0 400.0 500 0 499.8 600 0 599.7 700 0 699.6 800 0 799.4 900 0 899.2 1000 0 998.8 1100 0 1097.7 1200.0 1195.8 1300.0 1292.7 Rect Coordinates M.D. T.V.D. 0,0N 0.0N 0.0N 0.3N 2.9N 7.7N 12.8N 18.0N 23.1N 29.5N 38.8N 52.9N 72.0N 96.1N 0.0E 10.0 0.0 0.0E 110.0 100.0 0.0E 211.3 201.3 0.1E 312.6 302.5 0.6E 411.8 401.3 1.SE 509.5 497.3 2.6E 605.2 589..7 3.6E 694.3 674.4 4.6E 781.2 755.4 5.9E 866.1 833.4 7.8E 950.0 909.1 10.6E 1032.3 983.0 14.4E 1110.5 1052.8 19.2E 1184.9 1119.1 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 76.0N 76.0N 76.2N 75.1N 66.3N 49.0N 25.1N 1.8S 31.8S 64.6S 99.65 135.1S 169.5S 202.8S 171.0W 294.0 187.1 N/A 171.0W 294.0 187.1' )186.1( ~ r ~'~ I"" , , , ~'l~% 170.5W 294.1 186.8' )184.8( ' K L.I IVI L) 169.8W 293.8 185.6' )182.6( 172.0W 290.2 183.9' )180.2( 177.5w 283.0 183.8. )179.6( DEC O1 2000 183.7W 2738 187.0 )181.9( 190.8W 264.2 197.0 )191.1( 199.1w 254.9 215 5 )2°8'~laska Oil & Gas Cons. Commission 207.7W 246.2 242 5 )234. 215.9W 238.3 277 9 )269.6( An0n0raOe 223.5W 231.2 321 4 )312.5( 230.3W 225.4 372 3 )362.9( 236.2W 220.5 429 8 )419.9( 1400.0 1388.2 125.2N 25.0E 1256.4 1182.7 235.1S 241.6W 216.5 493.1 )482.8( Phillips Alaska, Inc. . CLEARANCE LISTING . . 13 Pad 3F,21 Your ref : 21 Version #6 Kuparuk River Unit,North Slope, Alaska Last revised : 29-Nov-2000 Reference wellpath Object wellpath : PGMS <0-8730'>,,1,Pad 3F M.D. T.V.D. Rect Coordinates M.D. T.V.D. 0.0 0.0 0.0N 100.0 100.0 0.0N 200.0 200.0 0.0N 300.0 300.0 0.3N 400.0 400.0 2.9N 500.0 499.8 7.7N 600.0 599.7 12.8N 700.0 699.6 18.0N 800.0 799.4 23.1N 900.0 899.2 29.5N 1000.0 998.8 38.8N 1100.0 1097.7 52.9N 1200.0 1195.8 72.0N 1300.0 1292.7 96.1N 1400.0 1388.2 125.2N 1500.0 1482.0 159.1N 1600.0 1573.9 197.9N 4 5 7 10 14 19 25 31 39 0.0E 7.0 0.O 0.0E 106.9 99.9 0.0E 206.9 199.9 0.1E 306.9 299.9 0.6E 407.1 400.1 1 5E 507.8 500.8 2 6E 607.5 600.0 3 6E 705.4 696.7 6E 801.7 791.1 9E. 896.2 882.8 8E 985.7 968.6 6E 1071.8' 1049.9 4E 1150.0 1122.6 2E 1227.3 1193.4 0E 1300.4 1259.5 8E 1368.5 1320.4 5E 1433.6 1378.1 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 10 0N 10 0N 10 3N 10 7N 10 7N 7 9N 0 5N 11 0S 25 3S 41 7S 59 9S 80 3S 101 4S 124 7S 148 1S 170 6S 192 3S 23.0W 293.5 25.1 23.1W 293.5 25.2 23.4W 293.7 25.5 23.6W 293.6 25.9 23.9W 287.8 25.7* 22.0W 270.4 23.6* 16.3W 236.8 22.6* 7.0W 200.0 31.0 5.7E 178.7 49.1 21.4E 167.7 74.7 N/A 24.3 23.8 23.3 22.3 19.7 18.2 26.0 43.3 68.1( 39.3E 162.3 107.9 )100.5( 59.0E 160.0 149.6 )141.2( 78.6E 159.7 198.8 )189.6( 99.3E 160.1 255.0 )244.8( 119.9E 160.9 316.7 )305.4( 140.2E 161.8 382.9 )370.5( 161.0E 162.7 453.1 )439.5( Phillips Alaska, Inc. Pad 3F,21 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 14 Your ref : 21 Version #6 Last revised : 29-Nov-2000 Reference wellpath Object wellpath : PGMS <0-7717'>,,6,Pad 3F M.D. T.V.D. Rect Coordinates M.D. T.V.D. 0.0 0.0 0.0N 100.0 100.0 0.0N 200.0 200.0 0.0N 300.0 300.0 0.3N 400.0 400.0 2 . 9N 500.0 499.8 7.7N 600.0 599 . 7 12 . 8N 700.0 699.6 18.0N 800.0 799 . 4 23 . iN 900.0 899 · 2 29.5N 1000.0 998.8 38.8N 1100.0 1097.7 52.9N ' 1200.0 1195.8 72.0N 1300.0 1292.7 96.1N 1400.0 1388.2 125.2N 1500.0 1482.0 159.1N 1600.0 1573 . 9 197 . 9N 1700.0 1663.5 241.2N 1'800.0 1750.8 289 . IN 1900.0 1835.3 341.5N 2000.0 1917.0 398.0N 2100.0 1995.5 458.7N 2200.0 2070.7 523.4N 2300.0 2142.3 591.8N 00E 7.1 0.1 0 0E 107.3 100.3 0 0E 207.5 200.5 0 1E 307.4 300.4 0 6E 407.4 400.4 1 5E 507.3 500.3 2 6E 607.3 600.3 3 6E 707.6 700.6 4 6E 807.7 800.7 5 9E 907.4 ' 900.4 7 8E 1006.6 999.6 10 6E 1105.3 1098.3 14 4E 1203.1 1196.1 19 2E 1301.0 1294.0 25 0E 1403.7 1396.6 31 8E 1507.7 1500.3 39.5E 1612.7 1604.4 48.2E 1718.9 1708'.5 57.8E 1817.6 1803.5 68.2E 1914.5 1894.7 79.5E 2013.6 1985.4 91.6E 2108.7 2069.8 104.6E 2192.2 2142.4 118.2E 2272.1 2209.9 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 60 0N 59 59 59 59 59 59 59 59 58 58 58 57 57 57 58 63 71 78 85 94 105 116 127 5N 137.0W 293.7 149.6 9N 136.9W 293.6 149.5' 8N 136.7W 293.6 149.2' 8N 136.3W 293.6 148.7' 7N 136.0W 292.6 147.9' 6N 135.8W. 290.7 146.8' 5N 135.5W 288.7 145.7' 3N 135.0W 286.6 144.6' iN 134.2W 284.6 143.4' 8N 133.3W 281.9 142.3' 4N 132.6W 277.9 141.7' 1N 132.1W 272.1 142.8 7N 131.8W 264.4 146.9 1N 131.6W 255.5 155.7 0N 128.9W 246.1 168.6 9N 121.5W 236.8 184.1 7N 108.8W 227.9 202.3 5N 89.1W 219.0 222.9 9N 63.6W 210.0 248.4 8N 31.7W 201.3 280.8 7N 7.3E 193.4 319.2 7N 49.5E 186.8 363.2 7N 89.5E 182.1 413.2 130.7E 178.5 469.4 N/A 148.6 147.4 146.2 144.5 142.5 140.5 138.5 136.4 134.3 132.8 132.8 135.6 143.2 155.3 170.1 187.7 207.9 233.0 264.8 302.1 344.2 392.0 445.4 Phillips Alaska, Inc. Pad 3F,21 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 15 Your ref : 21 Version #6 Last revised :29-Nov-2000 Reference wellpath Object wellpath : PGMS <0-7050'>,,8,Pad 3F M.D.' T.V;D. 0.0 0.0 i00.0 100.0 200.0 200.0 300.0 300.0 400.0 400.0 500.0 499.8 600.0 599.7 700.0 699.6 800.0 799.4 900.0 899.2 1000.0 998.8 1100.0 1097.7 1200.0 1195.8 1300.0 1292.7 1400.0 1388.2 1500.0 1482.0 1600.0 1573.9 1700.0 1663.5 1800.0 1750.8 1900.0 1835.3 2000.0 1917.0 Rect Coordinates 0.0N 0. ON 0.0N 0.3N 2.9N 7.7N 12.8N 18. ON 23. iN 29.5N 38.8N 52.9N 72. ON 96. iN 125 ..2N 159. iN 197.9N 241.2N 289.1N 341.5N 398. ON M.D. T.V.D. 0.0E 6.9 -0.1' 0.0E 107.0 100.0 0.0E 207.7 200.7 0.1E 307.7 300.7 0.6E 408.1 401.1 1.5E 508.0. 501.0 2.6E 607.8 600.8 3.6E 707.5 700.5 4.6E 807.4 800.4 5.9E 907.5 900 5 7.8E 1007.3 1000 10.6E 1106.1 1099 14.4E 1203.8 1196 19.2E 1300.3 1293 25.0E 1395.1 1388 31.8E 1488.5 1481 39.5E 1579.9 1572 48.2E 1670.2 1663 57.8E 1758.5 1751 68.2E 1843.5 1836 79.5E 1925.7 1918 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 81.0N 81.1N 184.0W 293.8 201 80.9N 183.9W 293.8 200 80.8N 183.6W 293.7 200 80.6N 183.2W 292.9 199 80.3N 182.7W 291.5 198 80.1N 182.2W 290.0 196 80:0N 181.7W 288.5 195 79.8N 181'.2W 287.0 194 79.5N 180.8W 285.0 193 78.9N 180.2W 282.1 192 78.3N 179.5W 277.6 191 77.5N 178.9W 271.6 193 76.6N 178.4W 264.4 198 75.6N 178.1W 256.3 209 74~6N 177.9W 248.0 226 73.6N 177.7W 240.2 250 72.7N 177.5W 233.3 281 72.2N 177.0W 227.3 319 71;9N 176.4W 222.2 364 71.7N 175.7W 218.0 414 184.0W 293..8 201 0 1 9* 5* 6* 1' 6* 4* 3* 3* 2* 7* 4 6 0 1 3 7 7 0 3. N/A 200.2 i99.2 197.9 196.1 193.8 191.4 189.3 187.3 185.3 183.2 181.7 182.1 185.9 195.0 210.7 233.7 264.0( 301.0( 344.4( 393.8( RECEIVED Ooo ~laska Oil & Gas Cons. CommissJo~ Anchorage 2100.0 1995.5 458.7N 91.6E 2004.1 1997.1 71.5N 175.0W 214.5470.2 )448.7( Phillips Alaska, Inc. ID CLEARANCE LISTING ~ e 16 Pad 3F,21 ~ Your ref : 21 V~on #6 Kuparuk River Unit,North Slope, Alaska Last revised : 29-Nov-2000 Reference wellDath Object wellpath : PGMS <0-7785'>,,9,Pad 3F M.D. T.V.D. Rect Coordinates M.D. T.V.D. 0.0 0.0 0.0N 0.0E 7.0 0.0 iII.0N 100.0 100.0 0.0N 0.0E 107.2 100.2 l10.8N 200.0 200.0 0.0N 0.0E 207.3 200.3 110.5N 300.0 300.0 0.3N 0.1E 307.4 300.4 ll0.1N 400.0 400.0 2.9N 0.6E 407.6 400.6 109.8N 500.0 499.8 7.7N 1.5E 508.1 501.1 109.6N 600.0 599.7 12.8N 2.6E 608.3 601.3 109.6N 700.0 699.6 18.0N 3.6E 708.5 701.5 109.3N 800.0 799.4 23.1N 4.6E 808.5 801.5 108.9N 900.0 899.2 29.5N 5.9E 908.6 901.6 108.3N 1000.0 998.8 38.8N 7.8E 1009.6 1002.5 107.3N 1100.0 1097.7 52.9N 10.6E 1109.2 1102.2 106.0N 1200.0 1195.8 72.0N 14.4E 1202.7 1195.5 101.SN 1300.0 1292.7 96.1N 19.2E 1292.6 1285.1 94.2N 1400.0 1388.2 125.2N 25.0E 1373.9 1365.7 84.6N 1500.0 1482.0 159.1N 31.8E 1449.4 1440.0 72.2N 1600.0 1573.9 197.9N 39.5E 1525.0 1513.7 56.8N 1700.0 1663.5 241.2N 48.2E 1586.7 1573.2 41.6N 1800.0 1750.8 289.1N 57.8E 1640.6 1624.6 26.4N 1900.0 1835.3 341.5N 68.2E 1683.4 1664.8 12.8N Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 252.0W 293.8 275.4 N/A 252.1W 293.7 275.3* )274.4( 252.1W 293.7 275.3* )273.5( 252.1W 293.5 275.1' )272.5( 252.1W 292.9 274.4* )270.9( 251.9W 291.9 273.1' )268.8( 251.4W 290.8 271.8' )266.5( 250.8W 289.8 270.3* )264.2( 250.2W 288.6 268.9* )261.9( 249.6W 287.1 267.3* )259.4( 248.7W 285.0 265.5* )256.6( 247.4W 281.6 263.4* )253.8( 247.0W 276.5 263.1' )252.6( 248.6W 269.6 267.9 )256.5( 252.4W 261.7 281.3 )268.8( 258.2W 253.3 305.7 )292.2( 264.8W 245.1 340.8 )326.3( 271.0W 238.0 387.1 )371.9( 277.1W 231.9 443.9 )428.0( 282.7W 226.9 510.1 )493.7( PhilliPs Alaska, Inc. Pad 3F,21 Kuparuk River Unit,North Slope, Alaska Reference wellpath M.D. T.V.D. CLEARANCE LISTING Page 17 Your ref : 21 Version #6 Last revised : 29-Nov-2000 Object wellpath : PGMS <0-6650'>,,10,Pad 3F Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n · 0.0 0.0 0.0N 0.0E 7.0 0.0 120.0N 100.0 100.0 0.0N 0.0E 106.8 99.8 119.9N 200.0 200.0 0.0N 0.0E 206.8 199.8 119.7N 300.0 300.0 0.3N 0.1E 307.3 300.3 119.2N 400.0 400.0 2.9N 0.6E 406.9 399.9 118.7N 500.0 499.8 7.7N 1.5E 506.9 499.9 118.3N 600.0 599.7 12.8N 2.6E 607.7 600.7 l18.1N 700.0 699.6 18.0N 3.6E 708.2 701.2 118.0N 800.0 799.4 23.1N 4.6E 808.5 801.5 117.7N 900.0 899.2 29.5N 5.9E 908.9 901.9 117.2N 1000.0 998.8 38.8N 7.8E '1008.9 1001.9 116.6N 1100.0 1097.7 52:9N 10.6E 1107.8 1100.7 l16.1N 1200.0 1195.8 72.0N 14.4E 1205.6 1198.6 115.7N 1300.0 1292.7 96.1N 19.2E 1302.1 1295.1 115.3N 1400.0 1388.2 125.2N 25.0E 1397.6 1390.6 114.8N 1500.0 1482.0 159.1N 31.8E 1490.3 1483.2 114.2N 1600.0 1573.9 197.9N 39;5E 1582.4 1575.4 113~8N 1700.0 16'63.5 241.2N 48.2E 1672.4 1665.3 113.4N 1800.0 1750.8 289.1N 57.8E 1758.9 1751.9 l13.1N 1900.0 1835.3 341.5N 68.2E 1842.7 1835.6 112.6N 2000.0 1917.0 398.0N 79,5E 1923.6 1916.6 l12.1N 2100.0 1995.5 458.7N 91.6E 1999.6 1992.6 lll.9N Phillips Alaska, Inc. Pad 3F,21 Kuparuk River Unit,North Slope, Alaska 274.0W 293.7 299.1 N/A 274.1W 293.6 299.2 )298.3( 274.3W 293.6 299.3 )297.5( 274.5W 293.4 299.2* )296.6( 274.6W 292.8 298.6* )295.1( 274.8W 291.8 297..7* )293.4( 274.7W 290.8 296.6* )291.4( 274.3W '289.8 295.4* )289.3( 273.8W 288.8 294.1' )287.1( 273.2W 287.4 292.5* )284.6( 272.3W 285.5' 290.7* )281.7( 271.3W 282.6 288.9* )278.9( 270.4W 278.7 288.1' )276.8( 269.6W 273.8 289.4 )276.7( 268.8W 268.0 294.0 )279.7( 268.2W 261.5 303.3 )287.5'( 267.7W 254.7 318.5 )301.1( 267.1W 247.9 340.2 )321.3( 266.5W 241.5 368.9 .)348.6( 266.0W 235.6 405.1 )383.5( 265.7W 230.4 448.3 )425.6( 265.5W 225.8 497.9 )474.2( Reference wellpath M.D. T.V.D. 0.0 0.0 100.0 100.0 200.0 200.0 300.0 300.0 400.0 400.0 500.0 499.8 600.0 599.7 700.0 699.6 800.0 799.4 900.0 899.2 1000.0 998.8 1100.0 .1097.7 1200.0 1195.8 1300.0 1292'.7 CLEARANCE LISTING Page 18 Your ref : 21 Version #6 Last revised : 29-Nov-2000 Object Wellpath : PGMS <0-8600'>,,il,Pad 3F Rect Coordinates 0.0N 0. ON 0.0N 0.3N 2.9N 7.7N 12.8N 18.0N 23.1N 29.5N 38.8N 52.9N 72.0N 96.1N M.D. T~V.D. 0.0E 7.2 0.2 0 . 0E 107 . 6 100.6 0.0E 206.9 199.9 0.1E 306.9 299.9 0.6E 406.3 399.3 1.5E 501.9 494.9 2.6E 588 7 581 . 6 3 . 6E 679 8 672 . 1 4 . 6E 771 7 762.6 5 . 9E 853 6 842 . 3 7.8E 937 2 922.2 10.6E 1020 1 1000.3 14 . 4E 1099 7 1073 . 9 19 . 2E 1165 1 1133 . 4 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 131 0N 297.0W 293.8 324.6 N/A 131 131 131 132 132 I30 9N 125 5N 115 7N 102 6N 86 4N 66 6N 43 9N 23.1N ON 296.9W 293.8 324.5* )323.6( 2N 296.7W 293.9 324.4* )322.6( 6N 296.5W 293.9 324.3* )321.7( iN . 296.3W 293.5 323.8* )320.3( 5N 296.6W 292.7 323.3* )319.0( 300.3W 291.3 325.6 )320.8( 309.1W 289.0 331.8 )326.5( 321.2W 285.9 340.7 )334.7( 335.3W 282.1 3'53.5 )346.8( 353.3W 277.5 372.1 )364.4( 373.1W 272.0 396.1 )387.3( 393.1W 266.1 426.3 )416.3( 410.6W 260.4 464.2 )453.2( t ECEIVED DEC 0 1 2000 Oil & Gas Cons, Cor~missl~ Anchorage 1400.0 1388.2 125.2N 25.0E 1231.6 1192.9 Phillips Alaska, Inc. ' Pad 3F,21 Kuparuk River Unit,North Slope, Alaska 0.5N 429.8W 254.7 510.4 )498.3( CLEARANCE LISTING Page 19 Your ref : 21 Version #6 Last revised : 29-Nov-2000 Reference wellDath Object wellpath : PGMS <0-8108'>,,13,Pad 3F M.D. T.V.D. Rect Coordinates M.D. T.V.D. 0.0 0.0 0.0N 0.0E 6.8 -0.2 100.0 100.0 0.0N 0.0E 106.3 99.3 200.0 200.0 0.0N 0.0E 205.4 198.4 300.0 300.0 0.3N 0.1E 304.6 297.6 400.0 400.0 2.9N 0.6E 404.1 397.1 500.0 499.8 7.7N 1.5E 504.4 497.4 600.0 599.7 12.8N 2.6E 604.4 597.4 700.0 699.6 18.0N 3.6E 700.9 693.9 800.0 799.4 23.1N 4.6E 794.3 787.3 900.0 899.2 29.5N 5.9E 887.2 879.9 1000.0 998.8 38.8N 7.8E 975.4 967.6 1100.0 1097.7 52.9N 10.6E 1068.0 1058.7 1200.0 1195.8 72.0N 14.4E 1152.4 1141.0 1300.0 1292.7 96.1N 19.2E 1235.4 1221.1 1400.0 1388.2 125.2N 25.0E 1322.0 1304.0 1500.0 1482.0 159.1N 31.8E 1403.5 1381.0 1600.0 1573.9 197.9N 39.5E 1476.4 1448.9 1700.0 1663.5 241.2N 48.2E 1562.8 1527.8 1800.0 1750.8 289.1N 57.8E 1666.3 1620.4 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 151.0N 151.0N 150.9N 151.0N 151.4N 343.0W 293.8 374.8 N/A 343.1W 293.7 374.8 )374.1( 343.4W 293.7 375.1 )373.7( 343.9W 293.7 375.5 )373.4( 344.5W 293.3 375.7 )372.8( 151.8N 152.1N 152.4N 154.6N 160.3N 345.1W 292.6 375.4* )371.9( 345.6W 291.8 375.0* )370.7( 346.3W 291.0 374.9* )369.9( 347.8W 290.5 376.4 )370.6( 350.0W 290.2 379.7 )373.2( 169.8N 185.6N 204.1N 225.0N 248.6N 352.5W 290.0 384.6 )377.3( 355.5W 289.9 391.3 )383.1( 358.9W 289.5 399.7 )390.4( 364.6W 288.6 411.1 )400.6( 373.3W 287.2 425.4 )413.4( 272.8N 384.3W 285.3 443.0 )429.4( 296.5N . 396.4W 282.8 464.1 )448.9( 327.5N 412.9W 280.6 488.4 )471.1( 369.6N 432.2W 279.3 513.4 )493.6( Phillips Alaska, Inc. Pad 3F,21 Kuparuk River Unit,North Slope, Alaska Reference wellpath CLEARANCE LISTING Page 20 Your ref : 21 Version #6 Last revised : 29-Nov-2000 Object wellpath : PGMS <0-7455'>,,15,Pad 3F M.D.T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 0.0 0.0 0.0N 0.0E 7.4 0.4 171.0N 100.0 100.0 0.0N 0.0E 108.3 101.3 170.8N 200.0 200..0 0.0N 0.0E 208.0 201.0 170.5N 300.0 300.0 0.3N 0.1E 308.5 301.5 170.2N 400.0 400.0 2.9N 0.6E 408.4 401.4 170.2N 'l.5E 508.2 501.2 170.8N 2.6E 606.0 599.0 171.9N 3.6E 706.3 699.3 173.2N 4.6E 806.3 799.3 ' 174.4N 5.9E 905.1 898.1 175.6N 500.0 499.8 7.7N 600.0 599.7 12.8N 700.0 699.6 18.0N 800.0 799.4 23.1N 900.0 899.2 29.5N 38.8N 7.8E 1006.6 999.6 176.7N 52.9N 10.6E 1104.9 1097.8 178.0N 72.0N 14.4E 1201.9 1194.8 179.3N 96.1N 19.2E 1292.8 1285.7 180.8N 125.2N 25.0E 1371.7 1364.5 182.4N 1000.0 998.8 1100.0 1097.7 1200.0 1195.8 1300.0 1292.7 1400.0 1388.2 31.8E 1453.8 1446.4 183.8N 39.5E 1526.6 1518.7 184.4N 48.2E 1600.0 1591.4 184.7N 57.8E 1668.4 1658.6 186.0N 1500.0 1482.0 159.1N 1600.0 1573'.9 197.9N 1700.0 1663.5 241.2N 1800.0 1750.8 289.1N Phillips Alaska, Inc. Pad 3F,21 KuParuk River Unit,North Slope, Alaska 389.0W 293.7 424.9 N/A 388.9W 293.7 424.7* )423.8( 388.7W 293.7 424.5* )422.7( 388.5W 293.6 424.1' )421.5( 388.2W 293.3 423.2* )419.8( 387.5W 292.7 421.8' )417.5( 386.9W 292.2 420.7* )415.5( 386.6W 291.7 419.9' )413.8( 386.1W 291.2 419.0' )412.0( 385.9W 290.4 418.1' )410.2( 385.5W 289.3 416.7' )407.8( 385.0W 287.6 414.8' )404.8( 384.5W 285.1 413.0' )401.7( 385.0W 281.8 413.0' )400.7( 387.5W 277.9 417.1 )403.6( 393.2W 273.3 427.2 )412.3( 401.2W 268.3 444.4 )428.1( 411.9W 263.0 469.2 )451.4( 424.3W 257.9 501.5 )482.3( CLEARANCE LISTING Page 21 Your ref : 21 Version #6 Last revised : 29-Nov-2000 Reference wellpath Object wellpath : PGMS <0-8600'>,,16,Pad 3F. M.D. T.V.D. Rect Coordinates M.D. T.V.D. 0.0 0.0 100.0 100.0 200.0 200.0 300.0 300.0 400.0 400.0 500.0 499.8 600.0 599.7 700.0 699.6 800.0 799.4 900.0 899.2 1000.0 998.8 1100.0 1097.7 1200.0 1195.8 0. ON 0.0N 0.0N 0.3N 2.9N 0.0E 7.3 0.3 0.0E 108.1 101.1 0.0E 207.6 200.6 0.1E 307.1 300.1 0.6E 408.5 401.5 7.7N 12.8N 18.0N 23.1N 29.5N 1.5E 505.0 498.0 2.6E 592.7 585.7 3.6E 681.6 674.5 4.6E 767.0 759.5 5.9E 851.7 843.6 38.8N 52.9N 72.0N 7.8E 944.3 934.9 10.6E 1032.1 1020.7 14.4E 1120.6 1106.5 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 181.0N 181.0N 181.0N 181.1N 180.8N 412.0W 293.7 450.0 N/A 411.8W 293.7 449.9* )449.0( 411.5W 293.7 449.6* )447.9( 411.5W 293.7 449.5* )446.9( 411.4W 293.4 448.8* )445.3( 180.4N 181.5N 184.9N 190.7N 199.6N 411.3W 292.7 4'47.5* )443.2( 412.5W 292.1 448.2 ')443.4( 415.4W 291.7 451.8 )446..5( 419.6W 291.6 457.9 )452.0( 425.6W 291.5 467.2 )460.7( 213.5N 230.6N 251~2N 432.7W 291.6 478.1 )470.8( 439.1W 291.6 489.6 )481.3( 446.5W 291.2 502.5 )493.0( t?£CEIVE , DEC 0 000 Z~laska 0,'1 &..Gas COns. ~nchorage Phillips Alaska, Inc. Pad 3F, 21 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 22 Your ref : 21 Version #6 Last revised : 29-Nov-2000 Reference wellpath Object wellpath : PGMS <0-8102> Depth Shifted Nordic III,,13,Pad 3F M.D. T.V.D. Rect Coordinates M.D. T.V.D. 0.0 0.0 0.0N 100.0 100.0 0.0N 200.0 200 . 0 0 . 0N 300.0 300.0 0.3N 400.0 400.0 2.9N 500.0 499.8 7.7N 600.0 599 . 7 12 . 8N 700.0 699 . 6 18 . 0N 800.0 799.4 23.1N 900.0 899.2 29.5N 1000.0 998.8 38.8N 1100.0 1097.7 52.9N 1200.0 1195 . 8 72 . 0N 1300.0 1292.7 96. iN 1400.0 1388.2 125.2N 1500.0 1482 . 0 159 . IN 1600.0 1573 . 9 197 . 9N 1700.0 1663.5 241.2N 1800.0 1750.8 289.1N 0.0E 0.8 -0.2 0.0E 100.3 99.3 0.0E 199.4 198.4 0.1E 298.6 297.6 0.6E 398.1 397.1 1.5E 498.4 497.4 2.6E 598.4 597.4 3.6E 694.9 693.9 4.6E 788.3 787.3 5.9E 881.2 879.9 7.8E 969.4 967.6 10.6E 1062.0 1058.7 14.4E 1146.4 1141.0 19.2E 1229.4 1221.1 25.0E 1316.0 1304.0 31.8E 1397.5 1381.0 39.5E 1470.4 1448.9 48.2E 1556.8 1527.8 57.8E 1660.3 1620.4 Moriz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 151.0N 151.0N 150.9N 151.0N 151 4N 151 8N 152 iN 152 4N 154 6N 160 3N 169 8N 185 6N 204 iN 225 0N 248 6N 272 8N 296 5N 327 5N 369 6N 343 0W 293 8 374 8 343 343 343 344 345 345 346 347 350 352 355 358 364 373 384 396 412 432 N/A 1W 293 4W 293 8W 293 4W 293 1W 292 6W 291 3W 291 8W 290 OW 290 5W 290 5W 289 9W 289 6W 288 3W 287 3W 285 4W 282 9W 280 2W 279 7 374 7 375 1 )373 7 375 5 )373 3 375 6 )372 6 375 4* )371 8 375 0* )370 0 374 9* )369 5 376.4 )370 2 379.7 )373 8 )374 1 7 4 9 9 8 9 7 2 0 384.6 )377.3 9 391.3 )383.1 5 399.7 )390.5 6 411.1 )400.6 2 425.4 )413.4 3 443.0 )429.4 7 464.1 )448.9 6 488.4 )471.1 3 513.4 )493.6 Phillips Alaska, Inc. Pad 3F,21 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 23 Your ref : 21 Version #6 Last revised : 29-Nov-2000 Reference wellpath Object wellpath : PMSS <6594 - 9350'>,,13A, Pad 3F M.D. T.V.D. 0.0 0 0 100.0 100 0 200.0 200 0 300.0 300 0 400.0 400 0 500.0 499 8 600.0 599 7 700.0 699 6 800.0 799 4. 900.0 899 2 1000.0 998 8 1100.0 1097 7 1200.0 1195 8 1300.0 1292 7 1400.0 1388 2 1500.0 1482 0 1600.0 1573 9 1700.0 1663 5 1800.0 1750 8 Rect Coordinates 0.0N M.D. T.V.D. 0.0N 0.0N 0.3N 2.9N 7.7N 12.8N 18.0N 23.1N 29.5N 38.8N 52.9N 72.0N 96.1N 125.2N 159.1N 197.9N 241.2N 289.1N Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 0 0E 0.8 -0,2 151.0N 0 0E 100.3 99.3 151.0N 0 0E 199.4 198.4 150.9N 0 1E 298.6 297.6 151.0N 0 6E 398.1 397.1 151.4N 1 5E 498.4 497.4 151.8N 2 6E 598.4 597.4 152.1N 3 6E 694.9 693.9 152.4N 4.6E 788.3 787.3 154.6N 5.9E 881.2 879.9 160.3N 7.8E 969.4 967.6 169.8N 10.6E 1062.0 1058.7 185.6N 14.4E 1146.4 1141 0 204.1N 19.2E 1229.4 1221 1 225.0N 25.0E 1316.0 1304 0 248.6N 31.8E !397.5 1381 0 272.8N 39.5E 1470.4 1448 9 296.5N 48.2E 1556.8 1527 8 327.5N 57.8E 1660.3 1620 4 369.6N Phillips Alaska, Inc. Pad 3F,21 Kuparuk River Unit,North Slope, Alaska 343 OW 293 8 374.8 N/A 343 1W 293 343 4W 293 343 8W 293 344 4W 293 345 1W 292 345 6W 291 346 3W 291 347 8W 290 350 0W 290 352 5W 290 355 5W 289 358.9W 289 364.6W 288 373.3W 287 384.3W 285 7 374.8 )374.1( 7 375.1 )373~7( 7 375.5 )373.4( 3 375.6 )372.9( 6 375.4* )371.9( 8 375.0* )370.8 0 374.9* )369.9 5 376.4 )370~7 2 379.7 )373.2 0 384.6 )377.3 9 391.3 )383.1 5 399.7 )390.5 6 411.1 )400.6 2 425.4 )413.4 3 443.0 )429.4 396.4W 282.7 464.1 )448.9 412,9W 280.6 488.4 )471.1 432.2W 279.3 513.4 )493.6 CLEARANCE LISTING Page 24 Your ref : 21 Version #6 Last revised : 29-Nov-2000 Reference wellpath Object wellpath :PGMS <0-8875'>,,5,Pad 3F M.D. T.V.D. 0.0 0.0 100.0 100.0 200.0 200.0 300.0 300.0 400.0 400.0 500.0 499.8 600 0 599.7 700 0 699.6' 800 0 799.4 900 0 899.2 1000 0 998.8 1100 0 1097.7 1200 0 1195.8 1300 0 1292.7 1400 0 1388.2 1500 0 1482.0 1600 0 1573.9 1700 0 1663.5 1800 0 1750.8 Rect Coordinates M.D. T.V.D. 0 ON 0 0N 0 0N 0 3N. 2 9N 7 7N 12 8N 18 0N 23 1N 29 5N 38 8N 52.9N 72.0N 96.1N 125.2N 159.1N 197.9N 241.2N 289.1N 0.0E 6.9 -0.1 0.0E 106.8 99.8 0.0E 207.3 200.3 0.1E 307.9 300.9 0.6E 411.4 404.3 1.5E 515.4 508.1 2.6E 618.4 610.3 3 6E 721.0 711.2 4 6E 822 . 9 810.2 5 9E 921.0 904.4 7 8E 1015.5 993.5 10 6E 1107 . 4 1078.4 14 4E 1199.4 1161.9 19.2E 1290.1 1242.7 25.0E 1379.7 1321.3 31.8E 1468.9 1397.9 39.5E 1555.1 1470 .'0 48.2E 1640.4 1539 3 57.8E 1722.3 1603 8 68.2E 1801.0 1663 7 79 . 5E 1881 . 5 1722 91~6E 1964.6 1781 104.6E 2046.1 1836 1900.0 1835.3 341.5N 2000.0 1917.0 398.0N 2100.0 '1995.5 458.7N 2200~0 2070.7 523.4N 2300.0 2142.3 591~8N 118.2E 2128.6 1889 RECEIVED DEC 01 000. ~im~ka Oil Horiz Min'm Ellipse (~ ~aS C'~ln$. , ~ec~ Coordinates, ~ar~ ~st Se~'~ ' Ancllor~e Co~issio~ 50.0N 49.8N 49.2N 48.4N 47.7N 49 7N 55 5N 63 3N 71 9N 81 iN 93 ON 108 2N 127 ON 148.8N 173.5N 201,0N 230.7N 262.7N 294,1N 325.2N 6 359.1N 368 1 396.9N 414 2 436.4N 459 5 478.5N 506 115.0W 293.5 125.4 N/A 115.2W 293.4 125.5 )124.8( 115.5W 293.1 125.5 )124.1( 115.6W 292.5 125.3' )123.1( 113.7W 291.4 122.8' )120.0( 106.9W 291.2 116.6' )113.0( 95.1W 293.6 107.1' )102.8( 78.5W 298.9 94.5* )89.3( 56.2W 308.7 78.8* )72.8( 30.3W 325.0 63.3* )56.4( 1.2W 350.7 55,2* )47.6( 30.4E 19.7 61.9 64.2E 42.2 81.6 98.9E 56.5 107.8 134.2E 66.2 136.8 170 7E 73.2 167.7 207 4E 78.9 200,1 245 6E 83.8 234,2 285 0E 88.7 270,7 325 6E 93.6 309.8 7E 97.7 350.6 0E 100.9 392.0 2E 103.8 434.0 0E 106.3 476.6 )53.8( )73.O( )98.2( 126.0( 155.3 186.0 218.1 252.4 289.1 327.2 365.6 404.4 443.5 2400.0 M.D. 0.0 100.0 200.0 300.0 400.0 500.0 600.0 2210.2 663.8N 132.6E 2224.6 1950.6 529.6N 559.7E 107.4517.5 )480.1( Phillips Alaska, Inc. { CLEARANCE LISTING ~ e 25 Pad 3F,21 Your ref : 21 Version #6 Kuparuk River Unit,North Slope, Alaska Last revised : 29-Nov-2000 Object wellpath : PMSS <0-7542'>,,20,Pad 3F Reference wellpath Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n T.V.D. Rect Coordinates M.D. T.V.D. 0.0 0.0N 0.0E 1.6 -0.4 193.2N 439.0W 293.8 479.6 N/A 100.0 0.0N 0.0E 100.9 98.9 192.9N 439.2W 293.7 479.7 )479.2( 200.0 0.0N 0.0E 199.8 197.8 192.2N 439.9W 293.6 480.1 )479.0( 300.0 0.3N 0.1E 296.8 294.8 191.9N 440.8W 293.5 480.7 )479.2( 400.0 2.9N 0.6E 387.9 385.9 192.0N 442.4W 293.1 481.8 )479.7( 499.8 7.7N 1.5E 473.8 471.7 193.2N 445.4W 292.5484.8 )482.2( 599.7 12.8N 2.6E 550.1 547.8 196.7N 450.7W 292.1 491.9 )488.8( RECEIVED DEC 0 ? 2000 Alaska Oil & Gas Cons. Commission Anchorage All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #21 and TVD from Estimated Nordic 3 (86.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 11.30 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ :c,,¢t,-' ,~. ~ ..... FOr: .~1. Cha'mbe,'s INTE() ................ Phillips AtasI.:a, Inc · Structure : Pod 3F Well : 21 Field : Kuporuk River Unit Location : North Slope, Alaska' ............. 11.30 AZIMUTH 5766' (TO TARGET) · ..Plane of 500 ESTIM~'[ED TD 660' FSL, 1412' FWL SEC:, 1 ?. T 12n. FgE TARGET LOCATIOh 274' FSL, 1534' FWL SEC. 17, Tl£r,h F, gE 50o 500 10(30 500 2000 _ 2500 - 3000 - 3.:00 - 4000 45,00 5000 5500 60Ga 6500 500 Est. RI',B Elevation: ,56' 0.75Beg D'nt Nudge EOC t',OP 4.50 Beg 5/100 Build 9,00 '15.013 21,00 DLS 3,00 ~eg ; er Bose Permafrost 2'L00 ,, 33.00 '~,.39.00 Top ugnu _. 45.00 %% 51.00 ~ EOC -,% To:, N SOt OC ft · ,,. Bose 'vV Sal. ~.'(.~' '7 5/8 Cosh-g TANGENT ANGLE "%. 52.69 DEG. ' .... · ,, - ¢:,/"B Casing ""'- ESTIMATE[.~ '""~ SLIP, FACE LOC'AITOH '"-. 99' FNL, 185' FWL j SEC 29. T121,I RgE "'-,,% ",,,% TOO ~ =' 1'/'~ C. osmg Tar, _ l'.olubik "-...~: "'" TO~O C4 Top C1 "",, ap A5 "~: Targe~ TD - Csg 500 1000 3500 2000 2500 5000 5500 400'3 4500 500( Vertical Section (feet) -> Azimuth 11.,30 with reference 0,00 N, 0.00 E from slot -~21 5500 6000 6500 East (feet) -> 0 500 1000 TE°C c,o bgnu Bose Permafrost ~.~) Beg Z, '0C Build EOC Beg D'n Nudge 500 6500 [6000 5,30,3 4-500 4000 5500 30C,J. 2500 2003 500 I000 500 RECEIVED DEC 01 2000 Alaska Oil & Gas Cons. Commission Anchorage For: ,N[. Chambers NTEO Structure : Pad 3F Well : 21 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) 140 120 100 80 60 40 £0 0 20 40 60 80 100 120 140 160 280 i ~ i i ~ 5 i i i i i i i r I I I i I I I i t i I i ~ I i i I ,' ." 1700 26O ,' iI .,. " ~ 4100 , 240 ' " 4'1800 ,, , 220 ,,' ,' 400C .' ~ 160o 200 180 5900 , . '500 .,-'300 160 5800 ' · · ' 200 ,,,$700- ~ 400 ... .... .,. ,, 3~00 / '+' ~ 1 O0 .. o "' '" ........... O0 '(~, ,,." :ooo.,...'..,',;'-"t' 300 1900 ............. 1000~ 1800 ................... '"~" ';"/":"'" .... + .... .' 900 1700. .............. 80~._..' ~ '200 ,. 1600+,, ' 700~ ....... . ................. ~ ........ ~0 ,.[.-? ............. ~00~..."""*" ..... 2400 320~ ,,, .t O0 ~ ' *~900 3300 ~t. "" ~'1000 500 "~'300 " 40 3400 ~ ' 000 ~oo e ;~oo' jgoo 1200 + ; 800 20 -~500 ~ F' · 700 1300 ~ 1.00· '"*'~ '6JO~,~O0 '200 ' r..~ 1300~ 500 o '4oo . - ~.~?.~._', 37oo 600 ........ 1500 ..... 1500 '~ 700~ ..... ~600 . . 3800 .... 800 '.. -... 1700 .. 40 '600 ~ , --.. 900%.. · ..... 60 I I I" I I ~ I~ 140 120 100 80 60 40 20 0 20 40 60 80 '00 '20 East (feet) -> /% 140 I 120 '1 O0 L i , , ' 40 ~ 60 80 8O 2,=~0 2 ,E,O 240 22C £oo ' 4,3 Z 20 0 00 ,,-,e- RECEIVED DEC 01 2000 Alaska 011 & Gas Cons. Commissio~ Anchorage Phillips Alaska, Inc.. Structure : Pad 3F Well : 21 Field : Kuporuk River Unit Location : North SLope, Alaska East (feet) -> 600 500 400 500 :00 100 0 100 200 SO0 40:, 500 600 %30 500 900 10.3,3 1700 1600 i500 1400 1300 1200 ,,^\' 1 O0 I 1000 900 0 Z ~oo 700 . 2000 600 500 ~ + 2400 + 1800 2600 2400 2200 2000 o 180C 1600 2400 _ '400 2200 5600 j' 5000 40o',cT;~"<':: 2200 ,, . 12oo j ~,¢~ ,',.~4o~,.'6°° 2ooo ,' r 1800 · . 1000 30o 2CI00 i ". "4000 ~ 1400 [ .,, / . ~"'}''"'~CO0 _~__-- 4200 .~,..~0~000.~ 120~800 1800 , 200 ~8o'o*~.~1o~6OO ~6oo , , '00 , 600 500 400 300 200 100 C 3400 ~ 28,00 5200 ., 3000 + ~ 2600 I / 2800 , + / J 2400 i 2600 + iI * 5200 / ~000 Y2200 . ~ " 48C)0 ,t 2000 J 2000 ~ 460,3 iI ' 1800 ~a30 · · '1600 .. .. ........... '~800 54 30 "2 '_00 5000 1600 - "" 1400 ........ ' /600 ~' 'i~oo · 00 200 300 40,3 500 600 700 800 906 East (feet) -> f ~ 00 70O ·500 '400 · 300 £00 1 O0 1000 soo $00 v 70O 600 500 400 300 2OO 100 '000 RECEIVED DEC 0 1 2.000 Alaska 0il & Gas Cons. Commission Anchorage For: 5I. Chambers INTEQ ?hitlips si,:a, !n,, Structure : Pod 3F Well : 21 Field : Kuporuk River Unit Location : North Slope. Alosko 2900 2500 2700 2600 25OO 2400 2500 I ,.,-2 - % :ooo- 0 Z - 900 - 1500 '1700 1600 1500 1400 1300 4OO East (feet) -> 400 300 £00 1 O0 0 I O0 200 300 400 560 6,-0 700 8'-hO 900 1C,,301 lC,,Z, 1 i i . 4600 I 3800 ~ 4400 3000 2800 2600 5600. 5600 iI 3400 ~. t.¢ 45 O0 i I t i i .i ,t 5800 ~ 520£ .'l .'1 3000 4200 2905 500 2?00 2E, O0 2500 2400 2300 2200 2103 ~ D" 2000~ .-,. 1900 500 1700 1600 34004· 1500 2400 2800 _ 6000 1400 ,, 3200 ~ .. 300 200 100 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 East (feet) -> RECEIVED DEC O1 2000 Alaska Oil & Gas Cons. Commissio~ Anchorage Phillips laslca Structure : Pod 3F Well: 21 Field : Kuporuk River Unit Location : North Slope, Alaska East (feet) - 1000 800 600 .4.00 '"00 0 200 400 60,:~ 800 I000 1 £00 1400 1600 ~ $00 20001 "£00 6000 5800 5600 5400 5200 5000 4800 I 4600 4400 4_'oo 40C0 5800 360C 340C 5200 5000 2800 2600 j~ 6200 ~ 6000 ~ 58,00 iI ~ 5600 6200 6000 ; 54,30 . 5800 ~ 5200 . 5600 5800 . itt o 5400 I . 6,200 .t. 5000 5200 - ¥ . 6000 4800 . 5000 ~ ~ 56,50:5800 . 4800 4600 ti + 5600 T I . 4600 /"='400T; ...,40C) 44-00 4400 5200 iI 4'200 / , 4200 tt , 5000 .4000 4000 ~ . 4800 i . 3800 it 4600 3800 .i 1000 800 600 400 2 O0 0 200 400 60C 800 1000 12 O0 East (feet) -.'...- '400 '600 '800 6000, 5800 5600 5200 4800 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2000 2200 RECEIVED DEC O1 2000 AlaSka Oil &Gas Cons.' Commission Anchorage Z PHILL ', S Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 December 1,2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: KRU 3F-21 Surface Location: Target Location: Bottom Hole Location: 99' FNL, 185' FWL, Sec. 29, T12N, R9E 273' FSL, 1336' FWL, Sec. 17, T12N, R9E 658' FSL, 1414' FWL, Sec. 17, T12N, R9E Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 3F pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 3F pad. The well is designated as a monobore injector and is planned to penetrate the Kuparuk C and A sands using a 7-5/8" surface casing string and a 5-1/2" x 4-1/2" tapered production casing string with a crossover seal bore. Completion plans call for running 3-1/2" production tubing as a tieback string. The well will be drilled and completed using Nordic Rig 3. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 3F, or hauled to an approved Prudhoe or GKA Class II disposal well. Also note that Phillips Alaska, Inc. does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report Sharon AIIsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Mark Scheihing, Geologist 265-6072 Please note that the anticipated spud date for this well is December 21, 2000. If you have any questions or require further information, please contact Mark Chambers at (907) 265-1319 or James Trantham at (907) 265-6434. Sincerely, / Mark Chambers Operations Drilling Engineer RECEIVED DEC 0 1 2 000 Alaska 0il & l~as Cons. Commission Anchorage Phillips Alaska, Inc,. For: M. Chambers p,o..~: -'O-.o~-:ooo Structure : Pad 3F Well : 21 ~. ~.~,~ ..... ~ .~o~ ~:~. Field : Kuparuk River Unit Locotion : No~h Slope. Alaska INTEO ................................................ : ............................................. 2900 2800 2700 2600 2500 2400 2300 I 2200 ,-i- Q) 2100 ~ 2000 0 Z 1900 1800 1700 1600 1500 1400 1500 East (feet) -> 400 300 200 100 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 i i i i i [ i i i i i i i i i I i i i I . 3200 . 3000 _ 2800 2600 ., 2400 3800 3400.: i r I i i i i I ~ i i / / ,- + 4600 4400 5600 T / - / ~: 4200 I I 3400. t,~ 4000 ii/' I/ ! .,; - tI 3600 ~ /I I : ~ 3000 I / t / ~ 2~00 .~ t 32oo: / ........... 400 300 200 1 O0 0 1 O0 200 500 400 500 600 700 800 900 1000 East (feet) -> 2900 2800 2700 2600 2500 2400 2500 2200 2100 2000 '900 '800 1700 ~600 1500 %000 1400 1300 -lO0 120o Am94 .¢ ess Cash Advance Draft 152 DATE . Engbwood, CaLCo NOT VALID FOR AMOUNT OVER $ I ~ ~ ~ Pay~ No~t B~k of G~d Jun~n - Downtown. NA ~ d Jun on, o ' i:~OE~OO~OOl:SS ,,,O~?SOOO~B~,'O~S~ WELL PERMIT CHECKLIST COMPANY /~/~/~::)-'~' ' ' WELL NAME ~/~'~/' PROGRAM: exp ~ FIELD & POOL /-'/?~_.~)/~)~".~ INI~' CLAS~ ~'~"/'~ t~" GEOL AREA ADMINISTRATION DATE,, 1. Permit fee attached. ~..~ .~ 2. Lease number approl:;ri~,t;:~. ~i'~. ".~.'~,,i ~'.'~.~. / ' 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ ~N. 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can. be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING APPR DANTE Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... dev redrll Y¸N ~ serv / wellbore seg ~ann. disposal para req ~ UNIT# ~)i//l'//~i'"~ ON/OFFSHORE 14. Y N 15. Y N too ~',.~%~',~'~ \"~"'~,. 16. 18. 19. 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... ~ ~'-~{"~ ~ ~1~ ~ . 22. Adequate wellbore separation proposed ............. ~ N q-.'~:~c.c.,.,ho¢~--..~.c_. ~,.~--~"~--\'~c~ 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 _ ~ ~ ' 26. BOPE press rating appropriate; test to ~>O~L~ psig. '~). N t,~b,_~.~'~ ~..J~,~,.,,.~'~ ~r,,~.~;-~ 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~ N 28. Work will occur without operation shutdown... ........ ~.) .~!. ~ ' , ~ ~ , r- ~ , ~ .., / _ 29. Is presence of H~S gas probable ................. y N~~,,~,--~¥.~-~.~,~\c3 ~cc_\,.~e..~ 30. Permit can be issued w/o hydrogen sulfide measures ..... Y 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. ~,j~-"Y N 33. Seabed condition survey (if off-shore) ............ ,,.-,-' Y N 34. Contact name/phone for weekly progress reports [expl~3~ry only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N Y N Y N Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: 8¢s Comments/Instructions: O Z O Z --I "I- c:\msoffice\wordian\diana\checklist (rev. 11/01//00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infOrmatiOn, information, of this. .nature is accumulated at the end of the file under APPENDIXi No 'special'effort has been made to chronologically organize this category of information. 3F-21.tapx Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Dec 07 14:07:05 2001 Reel Header Service name ............. LISTPE Date ..................... 01/12/07 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 0i Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. RECEIVED Alaska Oit & Gas Cons. Commission Anc~rage Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/12/07 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 0l Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: AP1 NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 1 JOB NUMBER: AK-MM-00345 LOGGING ENGINEER: R. MCNEILL OPERATOR WITNESS: D. WESTER 3F-21 500292299100 Phillips Alaska, Inc. Sperry Sun 07-DEC-0i MWD RUN 2 MWD RUN 3 AK-MM-00345 AK-MM-00345 R. MCNEILL R. MCNEILL D. HIEM D. HIEM MWD RUN 4 JOB NUMBER: AK-MM-O0345 LOGGING ENGINEER: A. WEAVER OPERATOR WITNESS: D. WESTER SUR[~CE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING MWD RUN AK-MM-00345 A. WEAVER D. WESTER 29 12N 9E 99 185 · O0 84.2~ 53.90 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 108.0 6.750 7.625 4028.0 REMARKS 1. 3F-21. "ca'6,:: ALL DEPTHS ARE MEASURED DEPTH (MD] UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). MWD RUNS 1 & 2 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS 4. MWD RUNS 3 - 5 WERE DIRECTIONAL, DGR, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). THE EWR4 TOOL FAILED DURING MWD RUN 3. RESISTIVITY DATA OVER THE RUN 3 INTERVAL WERE ACQUIRED WHILE RIH FOR MWD RUN 4. THESE DATA ARE INCLUDED IN RUN 4 FILES. 5. DEPTH SHIFTING/CORRECTION STATUS OF MWD DATA IS PENDING, PER E-MAIL FROM R.KALISH (SSDS) TO D.SCHWARTZ (PHILLIPS ALASKA) DATED 09/12/0].. MWD RUNS i - 5 REPRESENT WELL 3F-21 WITH API#: 50-029-22991-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9151'MD/6275'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE STAR%' DEPTH STOP DEPTH GR 108.0 9097.5 ROP 108.5 9151.0 FET 4010.0 9104.5 RPD 4010.0 9104.5 RPM 4010.0 9104.5 RPS 4010.0 9104.5 RPX 4010.0 9104.5 $ BASELINE CURVE FOR SHIFTS: 3URVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH Page 2 BASELINE DEPTH $ MERGED DATA SOURCE ?BU TOOL CODE MWD MWD MWD MWD $ REMARKS: BIT RUN NO 1 2 3 4 5 MERGED MAIN PASS. $ MERGE TOP 108.0 2144.5 4039.5 4010.0 5284.0 Data Format Specification Record Data Record Type .................. Data Specification Bloc)< Type ..... Logging Direction ................. Down Optical log depth units ........... FeeT. Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Units Size Nsam Rep Name Service Order 3F-21.taox MERGE BASE 2144.5 4039.5 4401.5 5284.0 9151.(, Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 3R MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 i 68 28 8 Name Service Unit Min Max DEPT FT 108 9151 ROP ~YD FT/H 3.48 420.66 GR MWD API 8.06 524.51 RPX MWD OHMM 0.78 2000 RPS MWD OHMM 0.87 2000 RPM MWD OHMM 0.06 2000 RPD MWD OHMM 1 2000 FET MWD HOUR 0.3061 105.653 First Reading For Entire File .......... 108 Last Reading For Entire File ............. 9151 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 First Mean Nsam Reading 4629.5 18087 108 89.6'?26 18086 108.5 1.04.628 1.7980 108 4.5506'7 10190 4010 4.62634 10190 4010 12.3862 10190 4010 11.4416 101.90 4010 2.5181 10190 4010 Last Reading 91.51 9151 9097.5 9104.5 9104.5 9104.5 9104.5 9104.5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.~ Date of Generation ....... 01/t2/0~ Page 3 3F-21.tapx Ma:<imum Phvsical Record.,65535 Pile T¥~e ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FiLE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. SIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FiLE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTM GR 108.0 2107.0 ROP 108.5 2144.5 $ LOG HEADER DATA DATE LOGGED: 03-JAN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 65.44 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 2145.0 TOP LOG INTERVAL (FT): 108.0 BOTTOM LOG INTERVAL (FT}: 2145.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 43.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB1789HG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: SPUD MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 120.0 MUD PH: 9,6 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 87.8 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Page 4 3F-21.tapx Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 ROP MWD010 FT/H 4 1 68 4 GR MWD010 API 4 1 68 8 Name Service Unit Min Max Mean Nsam DE?T FT 108 2144.5 1126.25 4074 ROP MWD010 FT/H 11.13 420.66 101.561 4073 GR MWDO10 API 8.06 111.78 62.7768 3999 First Reading For Entire File .......... 108 Last Reading For Entire File ........... 2144.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.( Date of Generation ....... 01/12/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Readinc 108 108.5 108 Last Reading 2144.5 2144.5 2107 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... 7ersion Number ........... 1.0.0 Date of Generation ....... 01/12/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.O02 Co~nent Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2107.5 4001.5 ROP 2145.0 4039.5 $ LOG HEADER DATA DATE LOGGED: 05-JAN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 65.44 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4040.0 TOP LOG INTERVAL (FT): 2145.0 BOTTOM LOG INTERVAL (FT): 4040.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 44.C MAXIMUM ANGLE: 2677.~ TOOL STRING (TOP TO BOTTOM) Page 5 VENDOR TOOl, CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3F-21.nam:,: TOOL NUMBE~, PB1V89HG~ 9.875 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 70.C, MUD PH: 9.5 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON 'POOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 5 .0 102.2 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 2107.5 4039.5 3073.5 3865 ROP MWD020 FT/H 3.48 272.87 88.0343 3790 GR MWD020 API 23.12 128.63 79.999 3789 First Reading For Entire File .......... 2107.5 Last Reading For Entire File ........... 4039.5 File Trailer Service name ............. STSLIB.O03 Service Sub Level Name... Version Number ........... 1.0.C Date of Generation ....... 01/12/0- Maximum Physical Record..65538 - File Type ................ LO Next File Name ........... STSLIB.004 First Reading' 2107.5 2].45 2107.5 Last Reading 4039.5 4039.5 4001.5 Page 3F-21.tapx Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4002.0 4347.5 ROP 4040.0 4401.5 $ LOG HEADER DATA DATE LOGGED: 09-JAN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4402.{/ TOP LOG INTERVAL (FT): 4040.0 BOTTOM LOG INTERVAL (FT): 4402.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 51.0 MAiKIMUM ANGLE: 54.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY N/A $ BOREHOLE AND CASING RATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 8.85 MUD VISCOSITY (S): 47.0 MUD PH: 10.0 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.000 64.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.378 77.0 MUD FILTRATE AT MT: 5.200 64.0 MUD CAKE AT MT: 2.800 64.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN;: TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Page ? Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefinec .~bsent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...O 3F-21.tapx Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 i ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 ~ Name Service Unit Min Max Mean Nsam DEPT FT 4002 4401.5 4201.75 800 ROP MWD030 FT/H 12.05 212.94 123.49 724 GR MWD030 API 50.69 155.69 120.999 692 First Reading For Entire File .......... 4002 Last Reading For Entire File ........... 4401.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 First Reading 4002 4040 4002 Last Reading 4401.5 4401.5 4347.5 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level. Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 4010.0 RPD 4010.0 RPM 4010.0 RPS 4010.0 RPX 4010.0 GR 4348.0 ROP 4402.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE STOP DEPTH 5237.5 5237.5 5237.5 5237.5 5237.5 5230.0 5284.0 10-JAN-01 Page 8 SURFACE SOFTWARE VERSION: DO~^~HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): FOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3F-21.~apx Insime 4.3!i Memory 5284.0 4010.0 5284.0 51.3 52.6 TOOL NUMBER N/A N/A 6.750 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 55.0 MUD PH: 10.0 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.600 MUD AT MAX CIRCULATING TERMPERATURE: 1.864 MUD FILTRATE AT MT': 4.000 MUD CAKE AT MT: 2.400 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 62.0 89.1 62.0 62.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD040 FT/H 4 1 68 GR MWD040 API 4 1 68 RPX MWD040 OHMM 4 1 68 RPS MWD040 OHMM 4 1 68 RPM MWD040 OHMM 4 1 68 RPD MWD040 OHMM 4 1 68 FET HWD040 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 4010 5284 ROP MWD040 FT/H 5.33 267.33 Mean Nsam 4647 2549 102.802 1765 Page 9 First Reading 4010 4402 Last Reading 5284 5284 GR MWD040 API 60.14 137.82 RPX ~D040 OHMM 1.53 2000 RPS MWD040 OHMM 1.65 2000 RPM MWD040 OHMM 0.06 2000 RPD MWD040 OHMM 1.73 2000 FET MWD040 HOUR 0.3061 105.653 First Reading For Entire File .......... 4010 Last Reading For Entire File ........... 5284 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 3F-21.tapx 115.368 1765 5.84309 2456 5.8058 2456 37.6931 2456 33.2425 2456 6.84461 2456 4348 4010 4010 4010 4010 4010 523O 5237.5 5237.5 5237.5 5237.5 5237.5 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5~ DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5230.5 9097.5 RPD 5238.0 9104.5 RPM 5238.0 9104.5 RPS 5238.0 9104.5 RPX 5238.0 9104.5 FET 5238.0 9104.5 ROP 5284.5 9151.0 $ LOG HEADER DATA DATE LOGGED: 14-JAN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9151.0 TOP LOG INTERVAL (FT): 5284.0 BOTTOM LOG INTERVAL (FT): 9151.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 50.2 MAXIMUM ANGLE: 58.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY N/A N/A EWR4 $ ELECTROMAG. RESIS. 4 Page 10 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3F-21.tap:,: 6.750 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.60 MUD VISCOSITY (S): 60.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3): 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.200 MUD AT MAX CIRCULATING TERMPERATURE: 1.911 MUD FILTRATE AT MT: 5.100 MUD CAKE AT MT: 2.600 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 ROP MWD050 FT/H 4 i 68 GR MWD050 API 4 1 68 RPX MWD050 OHMM 4 1 68 RPS MWD050 OHMM 4 1 68 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1. 68 FET MWD050 HOUR 4 i 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 60.0 140.0 60.0 60.0 Name Service Unit Min Max DEFT FT 5230.5 9151 ROP MWD050 FT/H 5.06 235.03 GR MWD050 API 40.19 524.51 RPX MWD050 OHMM 0.78 79.05 RPS MWD050 OHMM 0.87 85.58 RPM MWD050 OHMM 0.91 69.64 RPD MWD050 OHMM 1 66.63 FET MWD050 HOUR 0.366 11.0077 Mean 7190.75 78.0525 134.41.3 4.14026 4.25179 4.34984 4.51851. 1.14419 Ns am '7842 7734 7735 7'734 7'734 7734 7734 7734 First Reading For Entire File .......... 5230.5 Last Reading For Entire File ........... 9151 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/07 Page 11 Fi, rs't Reading 5230.5 5284.5 5230.5 5238 5238 5238 5238 5238 Last Reading 915]. 9151 9097.5 9104.5 9104.5 9104.5 9104.5 9104.5 Maximum Physical Record..65535 File T~.~e ................ LO Next File Name ........... STSLIB.007 3F-21. *a ap>t Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/12/07 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/12/07 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 12