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Home My WebLink About201-108MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-19 KUPARUK RIV UNIT 3K-19 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 3K-19 50-029-23022-00-00 201-108-0 W SPT 6332 2011080 1583 2675 2675 2675 2675 140 160 160 160 4YRTST P Josh Hunt 5/9/2025 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 3K-19 Inspection Date: Tubing OA Packer Depth 475 2020 1980 1980IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250510093407 BBL Pumped:1.1 BBL Returned:1 Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 14:01:16 -08'00' MEMORANDUM TO: Jim Regg n ", � I Ir6I �-i P.1. S7"�/ upervisor FROM: Austin McLeod Petroleum Inspector Well Name KUPARUK RIV UNIT 3K-19 Insp Num: mitSAM210506071443 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 13, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3K-19 KUPARUK RIV UNIT 3K-19 Ste: Inspector Reviewed By: P.I. Supry.1310— Comm API Well Number 50-029-23022-00-00 Inspector Name: Austin McLeod Permit Number: 201-108-0 Inspection Date: 5/5/2021 Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 6--2 Tubing 4,5 287- - 2875 2875 1783 - IA 550 2000 1970 1970 1.2 - OA 310 -1 470 — 480 480 N Thursday, May 13, 2021 Page I of I Packer Well 3K-19 Type Inj w- TVD PTD 2011080 Type Test s"I Test psi BBL Pumped: 1,BBL Returned: Interval 4vRTST P/F Notes: MITIA Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 6--2 Tubing 4,5 287- - 2875 2875 1783 - IA 550 2000 1970 1970 1.2 - OA 310 -1 470 — 480 480 N Thursday, May 13, 2021 Page I of I • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �� DATE: Tuesday,May 16,2017 P.I.Supervisor j 5,k-C1 ( 7 SUBJECT: Mechanical Integrity Tests 11 j CONOCOPHILLIPS ALASKA INC 3K-19 FROM: Chuck Scheve KUPARUK RIV UNIT 3K-19 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-19 API Well Number 50-029-23022-00-00 Inspector Name: Chuck Scheve Permit Number: 201-108-0 Inspection Date: 5/9/2017 Insp Num: mitCS170511120704 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-19 Type Inj W-TVD 6332 - Tubing 2810 2810 - 2810 • 2810 PTD 2011080 Type Test SPT Test psi 1583 - IA 380 1910 - 1875 - 1870 - BBL Pumped: 1.1 - BBL Returned: 1 - OA 10 90 - 90 - 90 Interval 4YRTST P/F P Notes: SCANNED JUL 1 ,U017 Tuesday,May 16,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg f +17(i DATE: Wednesday,May 15,2013 �61 P.I.Supervisor r l SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-I9 FROM: Bob Noble KUPARUK RIV UNIT 3K-19 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry',FCC-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-19 API Well Number 50-029-23022-00-00 Inspector Name: Bob Noble Permit Number: 201-108-0 Inspection Date: 5/12/2013 Insp Num: mitRCN130513053357 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IA 540 2010 1980 . 1980 Type Inj TVD 25 � 25 25 25 . �I 4YRTST P OA yP psi 2011080 SPT g, 2860 - 2860 r 2860 1 2860 -'; PTD T e Test Test si Isa3 , Interval P/F 'Tubing Notes: %ova FEB 2 (5 2014 Wednesday,May 15,2013 Page 1 of 1 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 23, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 3K -19 Run Date: 8/21/2011 t The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K -19 Digital Data in LAS format, Digital Log Image file / 1 CD Rom 50 -029- 23022 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 23022 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating < ,;,,, , Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: oZ o t. L. J -- AA LI Signed: 9,O ► —10g MEMORANDUM To: Jim Regg l~p„~~ ~~ l j~ P.I. Supervisor `7 FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 20, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-19 KUPARUK RIV UNIT 3K-19 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~-'" Comm Well Name: KUPARUK RIV UNIT 3K-19 Insp Num: mitCS090515163016 Rel Insp Num: API Well Number: 50-029-23022-00-00 Permit Number: 201-108-0 Inspector Name: Chuck Scheve Inspection Date: 5/15/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-19 , ype Inj. W TVD 6332 IA 850 2180 2070 2070 P.T.D 2olloso ypeTest SPT Test psi Isa3 / OA zao 300 300 300 Interval aYxTST p~F P - Tubing 2soo 2aoo zaoo zsoo NOtes: Pretest pressures observed and found stable . Well demonstrated good mechanical integrity. ~/ t ~ ~ p~1j ~ ., i ~ ,~fy' ~:: Wednesday, May 20, 2009 Page 1 of 1 05/30/08 ~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth • Well Job # ~~~~ JU3~ s ~ 2008 Log Description NO. 4732 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, SuitE> 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1F-04 11964615 INJECTION PROFILE +(~ ~ ( 05/26/08 1 1 3F-10 11964609 PRODUCTION PROFILE - ~~ ( jj 05/23/08 1 1 1J-101 11970685 GLS < < 05/23/08 1 1 1J-166 11970681 GLS / '^ 05/20/08 1 1 2N-306 11964608 INJECTION PROFILE / ~./U (-~- 05/22/08 1 1 3K-13 11970688 INJECTION PROFILE ~ 05/26/08 1 1 i B-08A 11970686 INJECTION PROFILE e I ~ j / 05/24/08 1 1 1Y-11 11964613 INJECTION PROFILE It3 - /~8~~ 05/25/08 1 1 3K-19 11964616 INJECTION PROFILE U 05/27/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . ~ ConocoPhillips Alaska . JUL 0 3 2007 & P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 2,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 5GAWNED JUL 0 5 2007 \o~ d.0\-' Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. 4¡~ M.J. Loveland ConocoPhillips Well Integrity Supervisor c.----/. . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft na aal 1C-19 203-054 28" none 28" na 12 6/24/2007 1 C-123 201-084 22" none 22" na 24 7/1/2007 1C-127 201-114 18" none 18" na 12 7/1/2007 1 C-133 201-077 16" none 16" na 8.5 7/1/2007 1 C-190 203-003 27" none 27" na -- g 6/24/2007 vIED.;} DI ;}tI@W¡¡tt¡t:t:W¡W¡ 3K-12 186-165 6" none 6" na 3 6/24/2007 3K-19 201-108 6" none 6" na 3 6/24/2007 3K-20 201-088 4" none 4" na 1 6/24/2007 3K-23 197-097 8" none 8" na 5 6/24/2007 3K-24 198-249 4" none 4" na 1 6/24/2007 3K-25 198-081 6" none 6" na 3 6/24/2007 3K-26 197-077 8" none 8" na 5 6/24/2007 3K-27 197-046 6" none 6" na 3 6/24/2007 3K-31 198-082 8" none 8" na 5 6/24/2007 3K-34 198-077 7" none 7" na 4 6/24/2007 3K-35 197-109 3" none 3" na 2 6/24/2007 Date 7/1/2007 Ç) 11/10/06 Sc~luI1Ibepgep NO. Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 1 3 2006 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 U-LC!- 8DI -10f) Field: Kuparuk Well Job# Log Description Date BL Color CD 1 R·26 11416225 INJECTION PROFILE 10/23106 1 1 R-22A 11416224 PROD PROFILE WID EFT 1 0/22/06 1 2K.28 N/A INJECTION PROFILE 1 0/19/06 1 3G·09 11415642 PROD PROFILE W/DEFT 10/24/06 1 3G~16 11416226 INJECTION PROFILE 10/24/06 1 2P.-427 11415637 INJECTION PROFILE 10/20/06 1 2P-429 11415640 INJECTION PROFILE 10/22/06 1 1J·101 11445123 GLS 11/06/06 1 2~-432 11415644 INJECTION PROFILE 10/26/06 1 3G-09 11415645 PROD PROFILE W/DEFT 10/27/06 1 3K-19 11415648 INJECTION PROFILE 10/30/06 1 2W-12 11445122 PROD PROFILE W/DEFT 11/05/06 1 1R-19A 11416228 INJECTION PROFILE 10/27/06 1 3J·05 1141630 INJECTION PROFILE 10/28/06 1 1 D-04 11445121 PROD PROFILE W/DEFT 11/04/06 1 30-07 11416222 INJECTION PROFILE 10/20/06 1 2N~305 11416223 FLOWING BHP SURVEY 10/31/06 1 3A-12 11445120 GLS 11/03/06 1 2L-311 11415649 FLOWING BHP SURVEY 10/31/06 1 2L.:-313 11445119 FLOWING BHP SURVEY 11/02/06 1 2K.27 11416234 FLOWING BHP SURVEY 11/02/06 1 2L-307 11296734 FLOWING BHP SURVEY 11/04/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . ConocóP'hillips . Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 May 18, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3K-19 (APD # 201-108) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 3K-19. ./ If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, J1,~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS £~,h-· 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 201-1081 . 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23022-00 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 34' 3K-19 8. Property Designation: 10. Field/Pool(s): ADL 25519: ALK 2555 Kuparuk River Field 1 Kuparuk Oil Pool , 11. Present Well Condition Summary: Total Depth measured 12340' feet true vertical 6884' feet Plugs (measured) Effective Depth measured 12122' feet Junk (measured) true vertical 6691' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 161' 161' SURFACE 6622' 7-5/8" 6656' 4157' PRODUCTION 11658' 5-1/2" 11692' 6345' LINER 608' 3-1/2" 12301' 6849' Perforation depth: Measured depth: 11950'-11960',12064'-12080',12092'-12115' true vertical depth: 6544'-6553',6641'-6655',6665'-6685' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 11672' MD. RBDMS BFl MAY 3 Înn~ Packers & SSSV (type & measured depth) no packer Cameo 'OS' nipple @ 518' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: refer to attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation na na 1375 Subsequent to operation na na 1000 / 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oilD GasD WAG 0 GINJD WINJ0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Well Engineer Signature J¡( j,1 Phone Date 5/~Z/80 .. PreDared bv Sh"ron AII.oun-Drak'" 263-4612 b ~ ~.z.~'O' Form 10-404 Revised 04/2004 0 RIG I N A L ~~ "A ~O;~~~ DATE 04/23/06 . . 3K-19 Well Events Summary Summary Pumped 4 stage high pressure breakdown - 480 bbls 55 deg seawater at max rate of 6.25 bpm @ 4000 psi pumped until failure of one of the pumps 160 bbls into 3rd stage. Continued with remainder of 3rd and 4th stage with one pump, only able to get 4.8 bpm @ 3700 psi max rate/pressure. 720 bbls 55 deg SW total was pumped. ConocoPhUlips AI.atPa, Inc.. . KRU 3<-19 31<#19\ <i i< i< ;; i+ ,--.", API: 500292302200 Well TVDe: INJ Anale (cj) TS: 37 dea (cj) 11901 TUBING < SSSV Type: Nipple Orig 7/12/2001 Angle @ TD: 27 deg @ 12340 (0-11672, ComDletion: OD:3.500, j Annular Fluid: Last W/O: Rev Reason: TAG FILL ID:2.992) Reference Log: Ref Log Date: Last UDdate: 4/30/2004 Last Too: 12122 TD: 12340 ftKB SURFACE Last Tag Date: 412212004 Max Hole Angle: 69 deg @ 5814 (0-6656, CaSinaSfthìå ..< OD:7.625, Description Size Top Bottom TVD Wt Grade Thread Wt:29.70) CONDUCTOR 16.000 0 220 220 62.58 H-40 WELDED 'RODUCTlON SURFACE 7.625 0 6656 4157 29.70 L-80 BTCM (0-11692, OD:5.500, PRODUCTION 5.500 0 11692 6345 15.50 L-80 LTCM Wt:15.50) LINER 3.500 11693 12301 6849 9.30 L-80 EUE-8RD iTlibil1C1 1)1[lnl] " LIBING< ......... ....: Size I Top I Bottom I TVD I Wt I Grade 1 Thread 3.500 I 0 I 11672 I 6331 I 9.30 I L-80 I EUE-8RD Ai «< ii Interval TVD Zone Status Ft SPF Date TVDe Comment 11950 - 11960 6544 - 6553 UNITB 10 4 8/25/2001 IPERF 2.5" HSD, DP Gas Lift 12064 - 12080 6641 - 6655 A-3 16 4 8/25/2001 IPERF 2.5" HSD, DP I ndrellDum m y Valve 1 12092 - 12115 6665 - 6685 A-2 23 4 8/25/2001 IPERF 2.5" HSD, DP 11587-11588, GâsEift ODA.725) St MD TVD Man Man Type V Mfr I V Type I V OD I Latch I Port TRO I Date I Vlv Mfr Run Cmnt 1 11587 6271 CAMCO I KBUG-2-9 CAMCO I DMY I 1.0 I BTM I 0.000 0 17/15/20011 Other (I IUes..eauiD... efc;l.IÞw¡:;lþNt <AA .K Depth TVD Type Description ID 518 518 NIP CAMCO 'DS' NIPPLE 2.875 11630 6301 SLEEVE BAKER CMU SLIDING SLEEVE 2.812 11671 6330 LOCATOR 3.000 11672 6331 SEAL BAKER 80-40 GBH-22 SEAL ASSEMBLY 3.000 SLEEVE 11673 6332 NIP BAKER CASNG SEAL RECEPTACLE 80-40 4.000 11630-11631, ODA.500} 11692 6345 XO 2.992 12300 6848 SHOE 2.992 LOCATOR :11671-11672, ODA.500} SEAL :11672-11673, ODA.OOO} NIP :11673-11674, OD:5.000} XO 11692-11693, OD5.690} - - Perf 11950-11960} - - - - - - - - Perf 12D64-12080} - - - - - - - - Perf 12092-12115) - - - - - - e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc 1,. .I.ßl,..l V.lU-\..l "U U 1 V.l ~Iale 01 AlaSKa Alaska Oil and Gas Conservation Commission TO: Jim Regg 17 J J I P.I. Supervisor ',Yf{? q /tf Os DA TE: Wednesday, May 25, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-19 KUPARUK RIV UNIT 3K-19 iO\ v' \011 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv \~ Comm Well Name: KUPARUK RIV UNIT 3K-19 Insp Num: mitCS05052 1I 55003 ReI Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-23022-00-00 Permit Number: 201-108-0 Inspector Name: Chuck Scheve Inspection Date: 5/21/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-19 Type Inj. w TVD 6331 I IA 1000 2130 2130 2130 I P.T. 2011080 TypeTest SPT Test psi 1582.75 lOA 460 620 620 620 I I Interval 4YRTST P/F p Tubing 2750 2750 2750 2750 I Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. SCANNED JUt O? 2,005 Wednesday, May 25,2005 Page I of I ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ðPr ttft Mechanical Integrity Test Emaíl to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; and Jim_Regg@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT I PAD: Kuparuk I KRU/3K DATE: 05121/05 SCANNED MAY 9 ,0. 'JOG!:' OPERATOR REP: Arend 1 Sauvageau - AES ' "" /",10C.,J AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. Well\3K-02 I Type Inj I S I TV.D. 6421 I Tubing I 27501 27501 27501 2750\lnterval 4 P.T.D. 1861020 Type Test P Test psi 1605 Casing 1100 2000 1950 1950 P/F P Notes: OA: 500 1 550 1550 I 550 well3K-04 I Type Inj I S I T.V.D. 6431 I Tubing I 30001 30001 30001 3000 Interval I 4 P.T.D. 1861040 Type Test P Test psi 1608 Casing 1000 2100 2040 2040 P/F P Notes: OA: 250 1 350 I 350 I 350 well3K-05 I Type Inj I S I TV.D. I 6341 I Tubing I 27501 27501 27501 2750lnterval 4 P.T.D. 1861230 Type Test P Test psi 1585 Casing 1400 2100 2070 2070 P/F P Notes: OA: 880 I 940 I 940 I 940 well3K-07 I Type Inj I S I T.V.D. 6565 I Tubing I 29501 29501 29501 29501 Interval I 4 P.T.D. 1861250 Type Test P Test psi 1641 Casing 450 2100 2040 2040 P/F P Notes: OA: 220 1 340 1 340 I 340 well3K-12 I Type Inj I S I Tv.D·1 6644 I Tub~ng I 28501 28501 28501 2850 Interval I 0 P.T.D. 1861650 Type Test P Test psi 1661 Casing 400 2040 2000 1980 P/F P Notes: MIT IA done early to get on pad cycle OA: 200 1 480 1 480 1 480 Well\3K-13 I Type Inj I S I T.V.D·I 6376 I Tub~ng I 28501 28501 28501 2850 Interval 4 P.T.D. 1861360 Type Test P Test psi 1594 Casing 550 2110 2050 2050 P/F P Notes: OA: 400 1 600 I 600 I 600 Well\3K-15 I Type Inj I S I Tv.D·1 6448 I Tub~ng I 28501 28501 28501 2850 I Interval 1 4 P.T.D. 1861380 Type Test P Test psi 1612 Casing 500 2070 2000 1980 P/F P Notes: OA: 300 I 450 I 450 1 450 we1l13K-18 I Type Inj I S I Tv.D·1 6605 I Tubing I 22001 22001 22001 2200 \ Interval I 4 P.T.D. 1861510 Type Test P Test psi 1651 Casing 100 2800 2750 2740 P/F P Notes: OA: 440 I 560 I 560 I 560 well3K-19 I Type Inj I S I T.V.D. 6331 I Tub~ng I 27501 27501 27501 275Ollnterval 4 P.T.D. 2011080 Type Test P T est psi 1583 Casing 1000 2130 2130 2130 P/F P Notes: OA: 460 I 620 I 620 I 620 well3K-25 I Type Inj I N I TV.D. I 6552 I Tub~ng I 27~1 2751 2751 2751'nterval I 4 P.T.D. 1980810 Type Test P Test psi 1638 Casmg 2140 2120 2120 P/F P Notes: OA: 300 I 600 I 600 I 600 Well \3K-26 I Type Inj I S I T.V.D.\ 6656 I Tubing I 27501 27501 27501 2750 I Interval I 4 P.T.D. 1970770 Type Test P T est psi 1664 Casing 900 2180 2160 2160 P/F P Notes: OA: 720 I 780 I 780 I 780 well3K-30 I Type Inj 1 S 1 T.V.D. 6580 I Tubing I 28501 28501 28501 2850 I Interval I 4 P.T.D. 1971130 Type Test P T est psi 1645 Casing 250 2100 2070 2070 P/F P Notes: OA: 200 1 460 I 450 I 450 well3K-31 I Type Inj I S I TVD. 1 6117 I Tubing I 285~1 28501 28501 2850 Intervall 4 P.T.D. 1980820 Type Test P Test psi 1529 Casing 2140 2120 2120 P/F P Notes: OA: 300 I 600 I 600 1 600 well3K-34 I Type Inj I S I TVD. I 6285 I Tub~ng I 28501 28501 28501 2850 I Interval I 4 P.T.D. 1980770 Type Test P T est psi 1571 Casmg 300 2140 2140 2140 P/F P Notes: OA: 400 I 650 I 650 I 650 Test Details: TYPE INJ codes TYPE TEST Codes INTERVAL Codes F = Fresh Water Inj M = Annulus Monitoring I = Initial Test G = Gas Inj P = Standard Pressure Test 4 = Four Year Cycle S = Salt Water Inj R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey Test during Workover D = Differential Temperature Test o = Other (describe In notes) MIT Report Form MIT KRU 3K 05-21-05.xls 5/24/2005 Revised: 05/19/02 ) ConocJP'hillips ) Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 November 23, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3K-19 (APD # 201-108) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 3K-19. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ~.~y Wells Group Team Leader CPAI Drilling and Wells MM/skad SCANNED NOV 2 9 2004 ORIGINAL Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 34' 8. Property Designation: ADL 25519, ALK 2555 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION LINER Perforation depth: ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ;, Abandon D Alter Casing D D RepairWell D Pull Tubing D Operat. ShutdownD Plug Perforations D Perforate New Pool D Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Exploratory D Service 0 Stimulate 0 Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 201..1081 6. API Number: 50-029-23022-00 9. Well Name and Number: 3K-19 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 12340' feet true vertical 6884' feet measured 12122' feet true vertical 6691' feet Length Size MD 161' 16" 161' 6592' 7-5/8" 6656' 11628' 5-1/2" 11692' 608' 3-1/2" 12301' Plugs (measured) Junk (measured) TVD Burst Collapse 161' 4157' 6345' 6849' Measured depth: 11950'-11960', 12064'-12080', 12092'-12115' RBDMs 8FL NOV 2 9 20n4 true vertical depth: 6544'-6553',6641'-6655',6665'-6685' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 11672' MD. Packers & SSSV (type & measured depth) no packer Cameo 'DS' nipple 518' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 11950'-11960', 12064'-12080', 120921.12115' 13. Treatment descriptions including volumes used and final pressure: 681 bbls of slick seawater Representative Daily Average Production or Injection Data Gas-Met Water-Bbl nla 1234 1923 15. Well Class after proposed work: Exploratory D Development D Service 0 16. Well Status after proposed work: oilD GasD WAGD GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Oil-Bbl nla Casinç¡ Pressure Tubinç¡ Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Contact Printed Name Signature WDSPLD Mike Mooney @ 263-4574 Mike Mooney /Í¡.J. )1/ ~ Title Phone Kuparuk Wells Team Leader Date - I }z..1 )04 Prepared bv ~ha!1n ~"sup-Drake 263-4612 n n" 0 ~ ~'_.A L ".: ' "" :j \~ i Submit Original Only Form 1 0-404 Revised 04/2004 ) 3K-19 Well Events Summary ) D~e Summary 11/06/04 POOR BOY HPBD COMPLETED. PUMPED 681 BBLS OF 60 DEGREE SLICK SEAWATER. MAX WHTP 4000 PSI & MAX RATE 9.2 BPM. RETURNED WELL TO PW INJECTION POST BREAKDOWN. [HPBD] TUBING ,0.11672. 00'3 5ÜO. 10'2.992) SURFACE 10-6656. 00:7 625. WI:29701 )ROOUCTlON 10-11692. 00 5.500. WI'15.50) Gas L,ft mdrellOurnrny Valve 1 11587-11588. 00 -I 7251 SLEEVE l1tDÜ,116<1. OOA 5(1('1 LOCA TOR 11n71.11672 . '00.4 ~,O(¡; :3EAL 11672.11673. 00 -I 0('(11 NIP 11673-1167-1 , 005 (II)ÜI XO 11692-11693, 005.6901 Perf :11950-11960) Perf :12064-12080) Perf :12092-12115) ") ) 3K-19 KRU ConocoPhillips Alaska, 3K-19 I" ~ i ; ~ ~ Î . ; , , ~. f. ~ ¡, , i~ ~ ~ ~ ~ ì ~ ! , , ~ ! i j h. ~ "It:' I I'r¡¡:: ~ ,~~ I I~ ~ ~ ~ ,1 i; . it j i~.f" ~ ~ ~ ] ~ j t ~ ~ I~ ~ ~ . ~ ,'r- ,,', ~ r",.',,':' .,J lè ' ," , ~ " I I~ ~ ~. ; LJ ¡Ai it 1 ~ ' ' ¡::. , L "i .L--.. API: 500292302200 SSSV Type: Nipple Angle @ TS: 37 deg @ 11901 Angle @ TD: 27 deg @ 12340 Well Type: INJ Orig 7/12/2001 Completion: Last W/O: Ref Log Date: TD: 12340ftKB Max Hole Angle: 69 deg @ 5814 Rev Reason: TAG FILL Last Update: 4/30/2004 Annular Fluid: Reference Log: Last Tag: 12122 Last Tag Date: 4/22/2004 Casing String - ALL STRINGS Description CONDUCTOR SURFACE PRODUCTION LINER Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 11950 - 11960 6544 - 6553 12064 - 12080 6641 - 6655 12092 - 12115 6665 - 6685 Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V 00 Latch Port TRO Date ~ Roo 1 11587 6271 CAMCO KBUG-2-9 CAMCO DMY 1.0 BTM 0.000 0 7/15/2001 Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 518 518 NIP CAMCO 'DS' NIPPLE 11630 6301 SLEEVE BAKER CMU SLIDING SLEEVE 11671 6330 LOCATOR 11672 6331 SEAL 11673 6332 NIP 11692 6345 XO 12300 6848 SHOE Size 16.000 7.625 5.500 3.500 Top Bottom TVD Wt Grade Thread 0 220 220 62.58 H-40 WELDED 0 6656 4157 29.70 L-80 BTCM 0 11692 6345 15.50 L-80 LTCM 11693 12301 6849 9.30 L-80 EUE-8RD TVD Wt I Grade I Thread 6331 9.30 L-80 EUE-8RD Status Ft SPF Date Type Comment 10 4 8/25/2001 IPERF 2.5" HSD, DP 16 4 8/25/2001 IPERF 2.5" HSD. DP 23 4 8/25/2001 IPERF 2.5" HSD. DP Bottom 11672 Zone UNITB A-3 A-2 Vlv Cmnt ID 2.875 2812 3.000 3.000 4.000 2.992 2.992 Description BAKER 80-40 GBH-22 SEAL ASSEMBLY BAKER CASING SEAL RECEPTACLE 80-40 . ! . ':.~ " í Permit to Drill 201'1080 MD 12340 ~' -I-VD DATA SUBMITTAL COMPLIANCE REPORT 713012003 Well Name/No. KUPARUK RIV UNIT 3K-19 6884 ~'~' Completion Dat ~7-~2¢'~2001 . Operator CONOCOPHILLIPS ALASKA INC Completion Statu 1WINJ Current Status IWINJ APl No. 50-029-23022-00-00 UIC Y .__ REQUIRED INFORMATION Mud Log N_._9o Sample N_gq Directional Survey ~ \/~j~._ _ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name Log Log Scale Media (data taken from Logs Portion of Master Well Data Maint) Interval Run OH / Dataset No Start Stop CH Received Number Comments e~f'~ LIS Verification D R D R D R .~Jgi~ional Survey Directional Survey FINAL onal Survey FINAL Directional Survey FINAL MWD ~'onal Survey Gyro FINAL Directional Survey Gyro FINAL Jewelry Log 5 FINAL ~fC~r Flow 5 FINAL Cement Mapping Tool 5 1 Well Cores/Samples Information: Name 1 180 12297 Open 12/28/2001 ---1-0'4~5 FINAL ch 9/7/2001 Directional Survey digital data ch 9/7/2001 Directional Survey Paper copy oh 9/7/2001 Directional Survey MWD digital data oh 9/7/2001 Directional Survey MWD paper copy oh 9/7/2001 Directional Survey Gyro digital data oh 9/7/2001 Directional Survey Gyro paper copy 11500 12128 OH 9/14/2001 11500-12128 BL, Sepia 11800 12100 CH 10/4/2001 11800-12100 BL;~_epia~ 11600 12194 ch 10/26/2001 11600-12194 ~olorPrint~ Interval Start Stop FINAL-----8-:-300- ...... 8505-'"'-~h ......... '1013012001 .............. 8300:8505' BL;Sepia Dataset Sent Received Number Comments ADDITIONAL INFORMATION DATA SUBMITTAL COMPLIANCE REPORT 713012003 Permit to Drill 201'1080 Well Name/No. KUPARUK RIV UNIT 3K-19 Operator CONOCOPHILLIPS ALASKA INC MD 12340 TVD 6884 Well Cored? Y/(~ Chips Received? Analysis Completion Dat 7/212001 Completion Statu 1WINJ Current Status 1WINJ Daily History Received? ~f N Formation Tops ~/N APl No. 50-029-23022-00-00 UIC Y Compliance Reviewed By: Date: 01/17/02 Schlumberger 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 ZP-438 21276 DSI 05/28/01 I 1 2P-438 21276 DSl TVD 05/28/01 I 1 I C-131 STATIC BOTTOM HOLE SURVEY 12/15/01 I 1 1 H-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 WATERFLOW LOG 12/09/0.1 I 1 3K-19 INJECTION PROFILE 12/09/01 I I DATE: RECEIVED JAN 2 5 2002 Please sign and return one copy of this transmittal to Sherrie at the above address or fax ,o (907)561-83~~1~ .~C01T~I'' To~ WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7m Avenue, Suite 100 Anchorage, Alaska December 27 2001 MWD Formation Evaluation Logs 3 K- 19, AK-MM- 11106 1 LDWG formatted Disc with verification listing. API#: 50-029-23022-00 'PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND 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: Signed: ~(~~, ' ~ RECEIVED F~, 2 8 2001 Al~.ska Oi~ & Gas Cons. Commi~ior~ A~c~ora§e 10/25/2001 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1570 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 1F-06 I~.~-I~/,S ~"- PRODUCTION PROFILE 10/12/01 I 1 1Q-10 I~q- lc~ v" · PRODUCTION PROFILE 09/28/01 I 1 1Q-16 ! ~'~--O~"7 v/ ~ PRODUCTION PROFILE 10/01/01 I 1 1R-06 / ~',~-~1 ~. INJECTION PROFILE 09/29/01 I 1 2G-12! ~'c/-/¢~ '"' · INJECTION PROFILE 09/29/01 I 1 2U-03 I ~.~-OO(O ~/'. INJECTION PROFILE 10/04/01 I 1 2Z-15 ~'~5-/O~ v"~ INJECTION PROFILE 10/04/01 I 1 3A'06 / ~ ~-,~,-~ v/ ' INJECTION PROFILE 09/27/01 I 1 3A-07 {~ ~ .'~,-~,~.~ ./e INJECTION PROFILE 09/27/01 I 1 3C-06 / ~'~-,~/ ~,'/' STATIC PRESSURE SURVEY 10/07/01 I 1 3H-09 / ~"7-//~ v/~* INJECTION PROFILE 09/30/01 I 1 3J-03 /~.~../~c/ v/e STATIC PRESSURE SURVEY 10/09/01 I 1 3J-06 ! ~ ~.,=,.~Id v~J STATIC PRESSURE SURVEY 10/08/01 I 1 3J-11 I ~5-,,~5! STATIC PRESSURE SURVEY 10/08/01 I 1 3J-14 /~'~-,_~ v/;'~ STATIC PRESSURE SURVEY 10/09/01 I 1 3J-15 / ~-~ ~ /* STATIC PRESSURE SURVEY 10/08/01 I 1 3J-18 )c;j(~_/~"7 v'~ · STATIC PRESSURE SURVEY 10/07/01 I 1 3K~19~-,-~o I.-/c~ /% INJECTION PROFILE 09/30/01 I 1 3M-19 / ~'?-~,~ ,x"~e STATIC BHP/T 10/11/01 I 1 3M-29 .} ~--00-5 /" ° STATIC BHP/T 10/11/01 I I SIGNED: ~~;lo-'-~~r~ ~.._._.._ ~-- DATE: RECEIVED OCT 50 2001 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank v~aska 0il & Gas Cons. CommissJor, Anchorage 10/16/2001 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1539 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 1L-26A ~15 ~ LEAK DETECTION LOG ~/' 09124/01 1 1 IR-13/~.~-I.~ INJECTION PROFILE ~/' 09/24/01 1 3K-19 ~D/-/~)~ 21351 iSCMT ~' 07117101 1 1D-121 IC)-~-i~l 21403 RST i/~ 09109101 1 1 1 1D-140 ~-~O0-/.'~G 21404 RST V/ 09109101 1 1 1 1 D-140 21379 RST J 08115/01 1 1 1 r L_t L. I VLLJ DATE: OCT 26 2001 *Alaska 0il & Gas Cons. Commission Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank yo~lChorage 10~2~2001 Schlmberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1501 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color 1D-113 I(~'-/")"~ " 21362 RST-SIGMA 08/08101 1Q-03 ! ~bl-¢~ --~ 3 PRODUCTION PROFILE 09118101 1R-~$ l~5-/,' ; ~ INJECTION PROFILE 09/18101 1Y-03 / ~.'.'.'~'C~ )l INJECTION PROFILE 09/t4101 1Y-11 ) ~',..~'-O' t I INJECTION PROFILE 09/~4101 28-12 I~-~O,~ ~' INJECTION PROFILE 08/31101 2W-~0 ~/~¥-J- ~ ~ INJECTION PROFILE 09/05/01 2W-12 j(~L) -~ ~L,I PRODUCTION PROFILE 09113101 2X-03 .]' ~;~---/( )oj INJECTION PROFILE 09/17101 3a-09 ') <:~ j .. lc q PRODUCTION PROFILE 09/~0101 3K-19 <~b)'~ ! t)~' WFL/EST-C/PSPT-A 09/19/01 3M-23 I C~--I~ .'7 PRESSURE SURVEY 09/12/01 OCT 0 4 2001 Alaska 0il & Gas Cons. Coma~e~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) $61-8317. Thank you. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. R. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 September 25, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 3K-19 (201-108) Dear Commissioner Taylor: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kupamk well 3K- 19. If you have any questions regarding this matter, please contact Todd Mushovic at 265-6974. Sincerely, Drilling Engineering Supervisor PAI Drilling CRM/skad Alasl,:a Oii& Gas Cons. Co, remission ORIGINAL ST^TE ^,^S.^ i ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ~] Gas ~! Suspended r"l Abandoned ~1 Service r~l ..... Water Injector Name of Operator ~[.O~..4¥~O~- ' 7. Permit Number 2. Phillips Alaska, Inc. ~ 201-108 3. Address ~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-23022-00 4. Location of well at sudace .- -~'~. ' -'~ '"~ 9. Unit or Lease Name At Top Preducing Interval1447' FSL, 319' FWL, Sec. 35, T13N, R9E, UM (ASP: 529307, 6008441)Ii '~~-i&'t:"' ;.:i ,~. ':' 10. Well NumberKUparuk Rivor Unit 2433' FSL, 1738' FWL, Soc. 25, T13N, R9E, UM (ASP: 535972, 6014736) - 3K-19 At Total Depth {. ~!~" .: i 11. Field and Pool 2523' FSL, 1843' FWL, Sec. 25, T13N, R9E, UM (ASP:536077, 6014826) L,...,-, .,. ,,-'~--,~,,:,.,'-'Z-,~:,~,'L"J. Kuparuk River Field 5. Elevation In feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. Kuparuk River Pool RKB 34 feetJ ADL 25519, ALK 2555 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. J15. Water Depth, If offshore 16. No. of Completions June 23, 2001 July 9, 2001 July 12, 2001J N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey J20. Depth where SSSV set 21. Thickness of Permafrost 12340' MD /6884' TVD 12206' MD /6765' TVD YES [~] No [--'1J Camco Nipple @ 518' 1684' 22. Type Electric or Other Logs Run GR/Res/PWD, SCMT, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD J CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 151.5# X-65 Surface 161' 24" 3 cu yds High Early 7.625" 29.7# L-80 Surface 6656' 9.875" 484 sx AS Lite, 320 sx LiteCRETE 5.5" 15.5# L-80 Surface 11692' 6.75" 190 sx Class G 3.5" 9.3# L-80 11693' 12301' 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" 11672' 11673' CSR 11950' - 11960' MD 6544' - 6552' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12064' - 12080' MD 6641' - 6654' TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12092' - 12115' MD 6665' - 6685' TVD 4 spf 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 Period > 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 oil, gas or water. Submit core chips. ;' ,~'"';~,; ,'~';'~ :~' ,,;.,/~ , ..... , '~', ,," l? '"~"' i""~'~,?., ' '~ i' ~ ~ i; "'"' ~:! ',~,, ?, i ..... N/A ~-,,"~' ..... ,,,e ,,,,: Oil (. ....... Form 10-407 Rev. 7-1-80 Submit in duplicate 29. ~ 30. ~, GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data. all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 11901' 6504' Base Kuparuk C 11948' 6542' Top Kuparuk A 12048' 6627' Base Kuparuk A 12180' 6742' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby ce[,r,r~that the ,~ is/t~ue and correct to the best of my knowledge. Questions? Call Todd Mushovic 265-6974 Signed ~--"'' "~ / ~' ""'" ''"V'"r .~~"~/1 ~~/'/~ / Title Dflllin.q En,qineerln.q Supervisor Date ~ ~/g~'t~ C. a#a / / "/-' ' INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Wateriii'ni~ct, i~r~;~G4"s,~ ~nj.~i.q,n.,~ Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 $'£P 5 2001 Oil & Gas Cons. Cornm,~ssion PHILLIPS ALASKA INC. Page I of 8 Operations Summa Report Legal Well Name: 3K-19 Common Well Name: 3K-19 Spud Date: 6/22/2001 Event Name: ROT- DRILLING Start: 6/20/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 Sub Date From - To Hours Code Code Phase Description of Operations 6/21/2001 04:00 - 12:30 8.50 MOVE MOVE MOBMIR Move Rig from 3G pad to 3K pad( 13 mile move). Had to wait 30 min @ 3K access juction until Nabors 16E Camp moved off pad and cleared access road) 12:30 - 13:00 0.50 MOVE MOVE MOBMIR Con't Rig Move to 3K pad. 13:00 - 00:00 11.00 DRILL RIRD SURFAC ~Set 11" 5m BOPs in Cellar - Spot Rig over 3K-19 - Rig up 21 1/4" Diverter. NOTE: Discussed Diverter discharge location [due north down access rd] w/AOGCC. Opted for, due to safety - egress, & approved by AOGCC, to run diverter line out celler access doors to trhe NW utilizing a 65' run. 6/22/2001 00:00 - 09:00 9.00 DRILL OTHR SURFAC Continue to nu diverter. Ru floor gear for picking up dp. Rig service & cut 48' of drlg line. Move bha components into pipe shed. NOTE: 16" conductor set @ 190'. 09:00 - 10:00 1.00 DRILL PULD SURFAC Pu dp & stand back in derrick. 10:00 - 10:30 0.50 DRILL SFTY SURFAC Pre spud meeting / pjsm w/all service, pad operator & Nortic personnel. 10:30 - 14:30 4.00 DRILL PULD SURFAC Continue to pu dp / set back in derrick. 14:30 - 17:30 3.00 DRILL PULD SURFAC Load in shed & Tally 5" HWDP - P/U same and stand back in derrick 17:30- 20:00 2.50 DRILL PULD SURFAC Load all handling tools in shed - Fuction test Diverter"ok" 20:00 - 20:30 0.50 DRILL SFTY SURFAC Spud Meeting with Crew (Ron Rice) & all Contractors. 20:30 - 23:30 3.00 DRILL PULD SURFAC P/U & M/U 9 7/8" Bit, Mud Motor, MWD & orient tools - P/U std HWDP Tag @ 109' - Fill conductor with H20 - Check circu surface system for leaks-" Knife valve leaked and flow riser" X Aogcc notified of diverter test - no show. X 23:30 - 00:00 0.50 DRILL OTHR ~SURFAC Repair Leaks in surface circu system. 6/23/2001 00:00 - 01:00 1.00 DRILL OTHR SURFAC Continue to repair surface leaks. 01:00 - 02:30 1.50 DRILL DRLG SURFAC Spud in well @ 1245 hrs. Clean out conductor to 190' & drill Ito 206'. 02:30 - 03:00 0.50 DRILL TRIP SURFAC Trip to Id 2 jts hwdp & pu 2 its flex pipe. 03:00 - 05:30 2.50 DRILL DRLG SURFAC Drill - Slid. Used gyro surveys to ck orientation of conductor @ 165' as 4.3 deg / 205 deg az & @ 195' as 4.1 deg / 215 deg az. MWD survey @ 231' = 3.8 deg / 206 deg az. Used surveys 195' [ gyro ] & 231' [ MWD ] to project hole orientation @ td of 2.5 deg / 206 deg az & 6.25' from well 3K-01. 05:30- 06:00 0.50 DRILL TRIP SURFAC Pooh into conductor. 06:00 - 07:30 1.50 WALTON ORDR SURFAC Confir w/PPCO engineering. Service rig. Pooh & download mwd tools. Printed: 7/31/2001 12:34:51 PM PHILLIPS ALASKA INC. Page 2 of:8 Operations Summa Report Legal Well Name: 3K-19 Common Well Name: 3K-19 Spud Date: 6/22/2001 ;Event Name: ROT - DRILLING Start: 6/20/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 Sub Date From - To Hours Code Code Phase Description of Operations 6/23/2001 07:30 - 09:00 1.50 DRILL OTHR SURFAC Lay down mwd tools, reconfigure ako from 1.5 to 2.25 deg. Wells group si 3K-01 w/sssv [1700']. Checked integrity of valve over 45 minutes, initial press = 150 psi, final -- 165 psi. 09:00 - 17:00 8.00 WALTON OTHR SURFAC Wells group bleeding down 3K-01 annuli. Initial 3.5 x 7" annulus pressure = 1200 psi., was down to 150 psi [line pressure] @ 1500 hrs & opened to atmospheric pressure - continue to bleed to zero psi. 7 x 9.625" annulus = zero psi [initial]. @ 1645hrs the 3k-01 well tbg was <100 psi [si w/sssv], 3.7 x 7" annulus = zero psi, & 7 x 9.625" annulus = zero psi. The tbg is si @ the wing valve, swab valve is open w/a cap - gage installed for conteneous monitoring of pressure. 17:00 - 18:00 1.00 DRILL TRIP SURFAC TIH - Tag 291'- Wash & Ream 291' to 295' (4' fill) 18:00 - 21:30 3.50 DRILL DRLG SURFAC Dir Drill & Slide 295' - 367' MD ( Gyro Survey every 30' - Survey depths 259', 289' & 319') 21:30 - 22:30 1.00 DRILL TRIP SURFAC TOH - Change AKO to 1.5 - TIH 22:30 - 00:00 1.50 DRILL DRLG SURFAC Dir Drlg & Slide 367' - 425' MD ( Gyro Survey every 30' - Survey depths 349' & 378'. NOTE: 3K-01 si tbg press = 110 psi @ rpt time. 6/24/2001 00:00 - 12:00 12.00 DRILL DRLG SURFAC Dir drill 425 - 1029'. Taking gyro surveys each 30 down to 729', then went to 90' gyro surveys. Clean of 3K-01 @ 700' & a minimum of 35' & departing from 3K-22 @ 1029'. Rot/up/dwn/wts= 60k/70k/62k lbs. Torque off/on bottom = 2700 / 3200 fi-lbs. Pump press/flow rate = 900-1000psi/10.7bpm. Slide for in¢ & dir cont: Art =1.5, Asr = 5.0 hrs. 12:00 - 12:30 0.50 DRILL SURV SURFAC Run gyro survey, cir hole clean, & pump dry slug. 12:30 - 14:30 2.00 DRILL TRIP SURFAC TOH - Break out bit - no wear will rerun. Re-configure bha [#4] to include mwd tools. X-out savor sub from 4.5" if to 4" HT-38. 14:30 ~ 16:00 1.50 DRILL ITRIP SURFAC P/U & M/U BHA #4- Orient Tools - Upload MWD. 16:00 - 18:00 2.00 DRILL PULD SURFAC C/O Saver Sub to 4" HT38 on TD - Install 4" Bell Guide on. 18:00 - 00:00 6.00 DRILL SURV SURFAC TIH w/BHA #4 -Sperry MWD Madd pass & Surveys @ 504', 534',594', 684', 747', 838', 927', & 957'. (Sperry needed these surveys for the IRF cazsandra corrections). 6/25/2001 00:00 - 01:30 1.50 WALTON OTHR SURFAC Cir - cond spr @ 1117' confer w/sperry Sun Engr on adequecy of ifr surveys. Rih to 1029', no fill. 01:30 - 18:00 16.50 DRILL DRLG SURFAC Dir drlg 1029 -2521' MD (TVD 2295') NOTE: One of two centrafuges in Baroid Mud cleaning unit developed repeated packing off problems resulting in unit being down 50% of time from 0600 to 1700 hrs. Avg fluid processed 3 bpm w/a cut of .2 ppg. Printed: 7/31/2001 12:34:51 PM PHILLIPS ALASKA INC. Page 3 of 8 Operations Summa Report Legal Well Name: 3K-19 Common Well Name: 3K-19 Spud Date: 6/22/2001 Event Name: ROT- DRILLING Start: 6/20/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 Sub Phase Description of Operations Date From-To Hours Code Code 6/25/2001 01:30 - 18:00 16.50 DRILL DRLG SURFAC Ordered out 180 bbl of 8.8 "new" mud for dilution @ 1400 hrs. Centrafuge problem narrowed down to a sizing problem on dischart port @ 1700hrs. Kept "new" mud coming. 18:00 - 20:00 2.00 RIGMNT RGRP SURFAC Actuator on IBOP Top Drive failed. Elecrtrical problem in control wire. Have problems fixed for short term?? Will need other work done at next open opportunity. 20:00 - 00:00 4.00 DRILL DRLG SURFAC ;Dir Drlg & Slide 2521' to 2808'MD (TVD 2466') I Parameters Bha #4: PU/SO ROT weights = 150 / 67 / 80k lbs. Q / P = 11.4bpm / 2000 ps @ current mw = 9.4 ppg Torq off/on = 4 / 5.3k ft-lb __web = 5 - 20k lbs Rpm = 177 slide / 257 rot Ast = 4.1 hrs Art = 2.3 hrs 6/26/2001 00:00 - 02:30 2.50 DRILL DRLG SURFAC Dir drlg / survey 2808 [2466' tvd] - 3001' 02:30 - 03:30 1.00 DRILL CIRC SURFAC Cir bu & sweep hole w/30 bbl hi vis pill @ 8 bpm / 900 psi. 03:30 - 05:30 2.00 DRILL TRIP SURFAC Pooh, work tight spot @ 1867' 05:30 - 09:30 4.00 DRILL TRIP SURFAC Elec problems w/bail extenders, continue to pooh to ck bit & troubleshoot tds. 09:30 - 12:30 3.00 RIGMNT RGRP SURFAC Trouble shoot elec problem on tds bail extenders. Used spair circuits to re-route control signals. 12:30 - 16:30 4.00 DRILL TRIP SURFAC Pu new motor & bit #2, rih. Taged bridge @ 2150' washed through in one pass / work area continue to 2920', numerous minor bridges from 2700', wash down last stand, no clear cut number on fill @ bottom. Circulate bu, recovering a large volume of floculated mud. 16:30 - 00:00 7.50 DRILL DRLG SURFAC Dir Dig & Slide 3001' to 3671' MD (TVD 2951'). Pump wt / hi vis sweeps as needed to maintain clean hole. Mud cleaner van not running due to Iow mud weight. Adding 20 bbl water hr, making approx 10 bph hole volume. Refer to bha pane for current drlg parameters. Low grav oil on shakers since 3080 'tvd. 6/27/2001 00:00 - 09:00 9.00 DRILL DRLG SURFAC Dir Dig & Slide 3671' MD (TVD 2951') - 4500' md. 09:00 - 10:00 1.00 DRILL CIRC SURFAC Relief valve on pump # 2 blew. Reset same. Work pipe / circulate @ 5.6bpm. 10:00- 11:00 1.00 DRILL DRLG SURFAC Dir Drlg 4500'-4565'. Blew pop-offx 2. 11:00-15:30 4.50 DRILL DRLG SURFAC Dir Drlg - survey w/ one pump. 4565=4800', 8.5 bpm /1400 psi. Inspect relief valve - found washed out seat. Replace relief valve. 15:30 - 18:00 2.50 DRILL DRLG SURFAC Dir Drlg - survey 4800 - 5013 MD ( TVD 3497') Printed: 7/31/2001 12:34:51 PM PHILLIPS ALASKA INC. Page 4 of 8 Operations Summa Report Legal Well Name: 3K-19 Common Well Name: 3K-19 Spud Date: 6/22/2001 Event Name: ROT- DRILLING Start: 6/20/2001 End: Contractor Name: Nordic Rig Release: Group: 'Rig Name: Nordic 3 Rig Number: 3 Sub Date From - To Hours Code Code Phase Description of Operations 6/27/2001 18:00 - 19:00 1.00 DRILL ClRC SURFAC Circu & Condition forWiperTrip- Pump 30 bbl Wt/Hi Vis Sweep - Rotate & Recip Pipe at all times -Rotate Max RPM(80/85) to optimize hole cleaning - Pump rate 160 SPM for Max flow rate(AV@4" = 142.5 fpm) 19:00 - 22:00 3.00 DRILL TRIP SURFAC TOH to 3420' Tight & Swab - Pump & back ream 3420' to 2820' 30k overpull. 22:00 - 23:00 1.00 DRILL TRIP SURFAC .TIH to 3420' - Hole clear. 23:00 - 23:30 0.50 DRILL ClRC SURFAC Circu & Condition to clean cutting fern hole - Rotate & Recip Pipe at all times -Rotate Max RPM(80/85) to optimize hole cleaning - Pump rate 170 SPM for Max flow rate(AV@4" = 142.5 fpm). 23:30 - 00:00 0.50 DRILL TRIP SURFAC Con't TOH from 3420'. Bit @ 2795 @ midnight, goinhg for stabs above perma-frost. 6/28/2001 00:00 - 00:30 0.50 DRILL DRLG SURFAC Continue to Pooh from 2795 - 2715'. 00:30 - 02:30 2.00 RIGMNT RGRP SURFAC Repair tds - elec control circuit for pipe gripper. 02:30 - 04:00 1.50 DRILL TRIP SURFAC Continue to pooh 2715 - 1595', above perma frost. No hole problems @ transistion zone to perma frost. 04:00 - 07:00 3.00 DRILL TRIP SURF^C Rih 1595 - 3450'. Tight @ 3450, mu tds & wash - ream 3450 - 3575'. Continue in hole w/standsto 4984'. 07:00 - 08:00 1.00 DRILL CIRC SURFAC Mu tds, break circulation gradually in stages, sweep hole w/hi vis sweep, cir until shakers clean [600 bbl]. wash / ream precautionary to td. 08:00- 12:00 4.00 DRILL DRLG SURFAC Dirdrlg-survey5013to 5401. 12:00 - 00:00 12.00 DRILL DRLG SURFAC Dir Drlg & Slide 5401' to 6356' MD (TVD 4032' ) Pump Wt/Hi Vis Sweeps as needed - Sweeps pumped @ 5455', 5785', 6100' - ECDs range 10.4 to 10.6 - Clean hole calculated @ 10.2 6/29/2001 00:00 - 05:30 5.50; DRILL DRLG SURFAC Dir drlg 6356 - 6664 {4160' h/d}. Sweeping hole w/hi wt/vis pills. 05:30 - 07:30 2.00~ DRILL ClRC SURFAC Cir hole [2x bottoms up] to clean shakers @ 2750 psi / 11.4 bpm. Rot / rec pipe. 07:30 - 14:00 6.50 DRILL TRIP SURFAC Whiper trip to 1080' [xo to bha], pipe count correct. Cai fill = 31 bbl, required 47 bbl. Hole conditions: depth Notes 3560 - 3519' 10 -15k overpull 3450 - 3390' as above 3020' 10k over pull 1890' minor overpull 1820' pulled into area 3x times to 20k over. Pu tds - cir - backream / ream through one time did not see again. Printed: 7/31/2001 12:34:51 PM PHILLIPS ALASKA INC. Page 5 of 8 Operations Summa Report Legal Well Name: 3K-19 !Common Well Name: 3K-19 Spud Date: 6/22/2001 Event Name: ROT- DRILLING Start: 6/20/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 Sub Date From - To Hours Code Code Phase Description of Operations 6/29/2001 07:30- 14:00 6.50 DRILL TRIP SURFAC 1300-1250' 20 koverpull 14:00 - 14:30 0.50 DRILL OTHR SURFAC Clean floor. Install cir swedge in string & cir @ 2 bpm. 14:30 - 16:00 1.50 DRILL OTHR SURFAC Cir- cond @ 2 bpm [1080'] while cutting drlg line. Zero bbl mud loss over this 1.5 hrs. 16:00 - 19:00 3.00 DRILL WIPR SURFAC Rih after Whiper trip out to 1080'. TIH to TD 6664' - Tag BttM - No Fill 19:00 - 00:00 5.00 DRILL CIRC SURFAC Circu BU - Pump Wt/Hi Vis Sweep - Rotate @ Max Rate 80-85 RPMs and Recip pipe at all times - Sweep brought up large amount of debris, Mud Wt out 9.8ppg. Circu clean and repeat Sweep. Sweep #2 had a lesser amount of debris to surface. Circu Clean and Con't to run Baroid Solides unit reducing wt from 9.8 to 9.6ppg 6/30/2001 00:00 - 01:30 1.50 DRILL CIRC SURFAC Complete cir - cond mud to 9.5? ppg. 01:30- 09:30 8.00 CASE OTHR SURFAC Pooh for csg. Break hwdp conn& set back. 09:30- 10:30 1.00 CASE OTHR SURFAC Down load mwd, & lay down same. 10:30 - 13:00 2.50 CASE OTHR Clean - police floor, pu csg tools / fill up tool, prepare to run csg. 13:00- 13:30 0.50 CASE SFTY PJSM 13:30 - 15:30 2.00 CASE RUNC SURFAC Rih w/7. 625" x Btcm x L-80 x 29.7 ppf csg. Run 2 shoe jts, thread loc i shoe track, function ck float equip, run centralizers as per program. 15:30 - 17:00 1.50 CASE RUNC SURFAC Set down @ 631'. Work csg to 20k lbs over, circulate & use csg tongs to rotate pipe. Broke through after 1 hr continued to run csg. Similar hole problems @ 803 & 890'. 17:00 - 00:00 7.00 CASE SURFAC Continue to run csg, csg dragging up to 20k lbs over @ same relative csg collar location. Obstruction / drag gradually decreased to not obserable. Cir/cond mud 1 hr @ 3300'. Seven csg jts off td @ midnight. 7/1/2001 00:00 - 00:30 0.50 CASE RUNC SURFAC Complete running 154 total jts of 7.625" x BTCM x L-80 x 29.7 ppf csg. Land out @ 6656'md [4160' tvd] [td = 6664'] on FMC fluted G5 15.25 x 7. 625" hanger. Ran Port collar @ 1018'. Used 13 centralizers on first 13 jts & one on each collar ofjts 143-152. 00:30 - 05:00 4.50 CEMEN'~ CIRC SURFAC Cir- cond mud @ 6.2 bpm / 560 psi, rec pipe 15'. Initial mud prop = 9.8+ ppg / yp 25 & Pv / 32 Final = 9.5+ ppg / yp 19 & pv / 11 05:00- 08:30 3.50 CEMEN-r DISP SURFAC Dowell cmt'ed 7.625" csg as follows: Pump 5 bbl CW 100 [8.3 ppg]. P. test lines to 3500 psi. Pump 35 bbl CW 100. Drop bottom plug. Pump 50 bbl mud push XL [10.5 ppg], followed by 383 bbl [484 sx] ASLite lead cmt slurry { 10.7 ppg / yield 4.45 ft3 per sx + add} @ 6 bpm / press max / min / avg = 650/200 / 300 psi, then 136 bbl [320 sx] tail LiteCRETE slurry {12.0 ppg /yield 2.4 ft3 per sx + adds} @ 5.3 bpm / press max / min / avg / =700 / 250 / 300 psi. Drop top plug, pump 5 bbl fw of total disp of 301.6 bbl. Hand to rig for displacement. Rig displaced w/additional 296.6 bbl as calculated. Rate - press max / min / avg; 6.25 bpm 1430 / 666 / 1150 psi. Slowed to 3 bpm / 1200 psi 10 bbl before cai plug hit. Bumped plug 1000 psi over @ 2220 psi, held 5 Printed: 7/31/2001 12:34:51 PM PHILLIPS ALASKA INC. Page 6 of 8 Operations Summa Report Legal Well Name: 3K-1 9 Common Well Name: 3K-19 Spud Date: 6/22/2001 Event Name: ROT- DRILLING Start: 6/20/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To Hours Code Sub Phase Description of Operations Code ~7/1/2001 05:00 - 08:30 3.50. CEMEN' DISP SURFAC rain, released press plugs held, recovered < 2 bbl. Full returnes throughout job. Recovered 72 bbl [91 sx] 10.7 ppg cmt to surface. CIP 0812 hrs, top of tail = 4250'. Exss cmt volumes calculated as per program. Aogcc - Notified J Crisp of Bop test in person sent out e-mail. :08:30 - 10:00 1.50 CEMEN'I OTHR SURFAC R/D CMT Head -L/D Ld Jt - Flush Diverter System with fresh water- Clean all CMT circu equip. 10:00 - 12:00 2.00 CEMEN'I OTHR SURFAC Remove Csg Tools w/crane from Rig floor- C/O bails -Remove all excess equip from floor and Csg from pipe shed. 12:00 - 17:30 5.50 CASE NUND SURFAC N/D Diverter System 17:30 - 20:00 2.50 CASE NUND SURFAC N/U FMC Gert V 5K Csg Head per FMC rep (Lee Throm) Orient per well plan - Test Csg head metal seal to 1000 psi "OK" 20:00 - 00:00 4.00 CASE NUND PROD N/U 11" 5K BOPs 7/2/2001 00:00 - 03:30 3.50 WELCTL NUND PROD Con't N/U BOPs. 03:30 - 04:30 1.00 WELCTL BOPE PROD Install test plug & jt in well hd. 04:30 - 12:30 8.00 WELCTL BOPE PROD Test 11" 5K BOPs. The stack had been in Nordic shop for annual inspection. The flanges were shop made up & required further makeup after being set in. Mud cross to double gate bop, mud cross to tbg spool, gray lock connections, blind ram door seals, test port on tbg spool [FMC]I leaked & required tightening. Tthis was accomplished by 0900 hrs. Remainder of the test went extreamly well on actual components w/no failures. H2S / gas alarms checked good. AOGCC rep John H. Crisp witnessed test. 12:30 - 13:00 0.50 WELCTL BOPE PROD Drain BOPs - Pull Test Plug - Install Ware Bushing 13:00 - 16:30 3.50 DRILL PULD PROD L/D 5" HWDP from derrick - Unload out of pipe shed. 16:30 - 22:00 5.50 DRILL PULD PROD Install second 3 1/16" 5K valve on 7 5/8" Ann per PAl procedure - Load & Strap 4" DP, 3 1/2" HWDP & all BHA into pipe shed. ~22:00 - 00:00 2.00 DRILL DRLG PROD Control Cable Not Working properly - Pull old cable off Top Drive **Note** New cable not on location. Nordic said it should be in today (Tuesday 7/3/01 ). Should take about 6-8 hrs to install & check out when it arrives. 7/3/2001 00:00 - 20:00 20.00 DRILL DRLG PROD Tds control cable not on Icc for repairs- Cable arrived on ALaska Ailines fit @ 1:40 PM - Cable arrived @ Rig 4:30 PM - New control cable was installed - @ 9:00PM the Top Drive was fuction tested. All fuction's work properly. PAl rep was present for Test. 20:00 - 00:00 4.00 DRILL PULD PROD P/U BHA #6 - set motor@ 1.5 AKO -Orient Tools - Up Load MWD 7/4/2001 00:00 - 05:00 5.00 DRILL TRIP PROD Continue running in hole w/BHA #6. Test sperry tools. 05:00 - 07:30 2.50 DRILL SFTY PROD PJSM-Hold stripping drills w/both crews. 07:30 - 09:30 2.00 DRILL TRIP PROD RIH-tag cement @ 6562'-stand back 1 std. Rig up for csg. test. Printed: 7/31/2001 12:34:51 PM PHILLIPS ALASKA INC. Page 7 of 8 Operations Summa~ Report Legal Well Name: 3K-19 Common Well Name: 3K-19 Spud Date: 6/22/2001 Event Name: ROT- DRILLING Start: 6/20/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 Date From-To Hours Code Sub Code Phase Description of Operations 7/4/2001 09:30 - 10:00 0.50 DRILL ClRC PROD Circ & reciprocate=work air out of system. 10:00 - 11:00 1.00 DRILL DEQT PROD Test 7 5/8" csg. to 3500# 30 mins. OK. 11:00 - 17:00 6.00 DRILL OTHR PROD Tag cement @ 6562' & drill cement -collar-shoe & 338' new hole to 6694'. 17:00 - 18:30 1.50 DRILL OTHR PROD Displace well w/LSND 8.4# new mud. Rotate & reciprocate. 18:30 - 19:30 1.00 DRILL LOT PROD Perform leak off test to 12.9#. 19:30- 20:00 0.50 DRILL OTHR PROD PWD Baseline test. 20:00 - 00:00 4.00 DRILL DRLG PROD Drlg. & surveys fromm 6694' to 7080'. MD. 7/5/2001 00:00 - 15:00 15.00 DRILL DRLG PROD Drlg. & surveys from 7080' to 8034'. 15:00 - 16:00 1.00 DRILL WIPR PROD Pump sweep & wiper trip to shoe. 16:00 - 16:30 0.50 DRILL OTHR PROD Monitor well & service rig. 16:30- 17:00 0.50 DRILL WIPR PROD Finish wiper trip. 17:00 - 00:00 7.00 DRILL DRLG PROD Drlg. & surveys from 8034' to 8582'. 7/6/2001 00:00 - 13:30 13.50 DRILL DRLG PROD Drlg. & surveys from 8582' to 9473'. 13:30- 14:30 1.00 DRILL CIRC PROD CBU-rotate & reciprocate-survey. 14:30 - 16:30 2.00 DRILL WIPR PROD Wiper trip to 6508'. (no problems-slight drag in several spots) 16:30 - 17:30 1.00 DRILL OTHR PROD Slip & cut drlg. line. 17:30 - 19:00 1.50 DRILL WIPR PROD Finish wiper trip to 9473'. 19:00 - 00:00 5.00 DRILL DRLG PROD Drlg. & surveys from 9473' to 9922'. 7/7/2001 00:00 - 00:00 24.00 DRILL DRLG PROD Drlg. & surveys from 9922' to 11309'. (appears to have topped HRZ @ 11302' MD 6093' TVD) 7/8/2001 00:00 - 00:30 0.50 DRILL DRLG PROD Drlg. from 11309' to 11365'-6127' TVD. 00:30 - 02:30 2.00 DRILL ClRC PROD Circ. & condition well for FIT. 02:30 - 05:30 3.00 DRILL WIPR PROD POH to 6664 MD. For FIT. 05:30 - 06:30 1.00 DRILL FIT PROD Circ. Fill lines-shut annular & perform FIT @ 12# OK. 06:30 - 07:30 1.00 DRILL OTHR :PROD Slip & cut Drlg. Line. 07:30- 10:00 2.50 DRILL WIPR :PROD RIH to 11365'. 10:00 - 00:00 14.00 DRILL DRLG PROD Drlg. & surveys from 11365 to 11886'.MD 6491' TVD. 7/9/2001 00:00 - 15:30 15.50 DRILL DRLG PROD Drlg. & surveys from 11886' to 12340' TD. 6881' TVD. 15:30 - 17:00 1.50 DRILL CIRC PROD Pump sweep & cbu for wiper trip. 17:00 - 00:00 7.00 DRILL WIPR PROD Wiper trip-Hole in good condition. 00:00 - DRILL PROD 7/10/2001 00:00- 00:30 0.50 DRILL WIPR PROD Finish wiper trip. 00:30 - 03:30 3.00 DRILL CIRC PROD Circ, condition hole for 3.5" X 5.5" csg. string. 03:30 - 20:00 16.50 DRILL PULD PROD POH laying down 4" dp & BHA. 20:00 - 00:00 4.00 CASE RUNC PROD PJSM-Rig up & run 19 jts. 3.5" csg. & 5.5" csg. 7/11/2001 00:00 - 02:30 2.50 CASE RUNC PROD Running in hole w/3.5" X 5.5" csg. string to shoe @ 6656'. 02:30 - 05:30 3.00 CASE ClRC PROD Circ. capacity of Csg. & bottoms up @ shoe while rigging up fill up tool-change out saver sub-rig up long bails.-rig down circ. equipment. 05:30 - 06:30 1.00 CASE OTHR PROD PJSM-Service rig. 06:30 - 15:30 9.00 CASE RUNC PROD Finish running csg. to 12303'-Break circ.-Work pipe Pumping 1/2 bpm-tight hole- Slowly bring pump to 2 bpm while working pipe-worked pipe to 12293'-pipe stuck @ 12293'. Work pipe & pump -Returns down to 50%. 15:30- 19:30 4.00 CEMEN'~ PUMP PROD Pump30 bbls. CW100-Test lines to 3500#-Pump50 bbls. Mud push @ 12# followed w/60 bbls. Claas 'G' cement @ 15.8#-Partial returns thru Mud push-after 5 bbls. cement lost complete returns. Pump 2 bbls. water behind cement-drop plug & pump plug down w/mud-bumped plug on calculated strokes-Bleed same-floats held. 19:30 - 00:00 4.50 CASE NUND PROD Drain BOP-Lift BOP-set slips-Cut 5.5" csg.-install packofft -nipple up BOP-test packoff 4000# 10 rains. OK 7/12/2001 00:00 - 07:00 7.00 CMPLTI~ OTHR CMPLTN Load-strap & drift 380 jts. 3.5" tbg. 07:00- 07:30 0.50 CMPLTI~ OTHR CMPLTN Service rig & top drive. Printed: 7/31/2001 12:34:51 PM PHILLIPS ALASKA INC. Page 8 of 8 Operations Summa Report Legal Well Name: 3K-19 Common Well Name: 3K-19 Spud Date: 6/22/2001 Event Name: ROT- DRILLING Start: 6/20/2001 End: 'Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To Hours Code Sub Code Phase Description of Operations 7/12/2001 07:30 - 19:00 11.50 CMPLTN RUNT CMPLTN Run 3.5" completion string-371 jts. & jewelry. 19:00 - 22:30 3.50 CMPLTN ClRC CMPLTN Circ. out heavy mud-tag & test csg. 30 mins. 3500# OK. 22:30- 00:00 1.50 CMPLTN ClRC CMPLTN Displace well to seawater. 7/13/2001 00:00 - 01:00 1.00 CMPLTN ClRC CMPLTN Finish displacing well w/seawater @ top of CSR @ 11672'. '01:00 - 03:00 2.00 CMPLTN DEQT CMPLTN Space out-make up & land tbg. hanger-RILDS-Test tbg. & csg. 3500# OK-Shear DKV @ 3300#. 03:00 - 10:00 7.00 CMPLTN NUND CMPLTN Pull landing jt.-set BPV-n/d bope-n/u tree & test same to 5000# pull bpv. 10:00 - 11:30 1.50 CMPLTN FRZP CMPLTN Freeze protect w/63 bbls. diesel-allow diesel to 'U' tube-set BPV. i (NOTE) hot oil truck pumped 85 bbls. diesel down 5.5" X 7.625" Annulus @ 2 bpm 2400# final pressure. 11:30 - 12:00 0.50 MOVE DMOB DEMOB Pull rig off well 3K-19 & rig down berms-clean cellar & location (Release rig @ 1200 hrs. 07/13/2001. 12:00 - MOVE DEMOB Printed: 7/31/2001 12:34:51 PM Date Comment 3K-19 Event History 07/15/01 07/16/01 07/17/01 08/25/01 PERFORMED A FCO TO 12,193.4' CTMD. WELL FREEZE PROTECTED TO 2200'. [FCO] 2.58" DUMMY PERF GUN TO 12122' WLM. [TAG] OBTAINED SCMT LOG. TAGGED BTM @ 12194'. CBL RAN FROM PBTD @ 12194 TO 11600. SHOWED VERY POOR CEMENT. PERFORATE W/2.5" HSD,DP,4 SPF GUNS, (11950'-11960') (12064'-12080') (12092'-12115'), ALL SHOTS FIRED / RIH W/PBMS ((TAGGED TD @ 12189')) & LOG SBHP/T AND JEWELRY LOG (SBHP = 3164 PSI @ 12150'). POOH, CALL DSO, LEFT WELL SI. RDMO. (NOTE:.TIE-IN F Page 1 of 1 9/5/01 03-Aug-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE SURVEY Re: Distribution of Survey Data for Well 3K-19 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD 'MD 12,340.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) las Cotls. ~1~ i..°~''''~ ~chor~e DEFIN'ITiYF-: Kuparuk River Unit · North Slope, Alaska Kuparuk 3K, Slot 3K-19 3K-19 Job No. AKZZ11106, Surveyed: 11 July, 2001 SURVEY REPORT 6 September, 2001 Your Ref: API-500292302200 sUrface Coordinates: 6008441.34 N, 529306.67 E (70° 26' 02.9044" N, Kelly Bushing: 64. lOft above Mean Sea Level 149°45'39.9138"W) CiRILLING SERVICES A Halliburton Company Survey Ref: svy9587 KuparUk .River Unit Measured Depth (ft) Incl. 861.00 10.000 990.65 2o.130 lO19.65 20.580 1048.20 19.980 1111.40 19.420 1147.32 19.540 1161.54 19.490 1178.44 19.060 1208.28 18.720 1242.03 18.880 Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for 3K-19 Your Ref: API-500292302200 Job No. AKZZ11106, Surveyed: 11 July, 2001 VertiCal Depth (ft) .Local Coordinates Northings Eastings (ft) (ft) 15.000 795.07 859.17 17.98 N 9.78W 15.930 15.530 14.740 16.120 20.740 22.770 24.190 27.020 31.500 920.11 947.29 974.07 1033.58 984.21 1011.39 1038.17 1097.68 1131.54 1144.95 1160.90 1189.13 1221.08 1067.44 1080.85 1096.80 1125.03 1156.98 1303.88 19.610 36.290 1215.38 1279.48 1398.78 21.760 37.340 1304.16 1368.26 1449.39 21.980 38.340 1351.12 1415.22 1495.24 23.140 39.850 1393.47 1457.57 1543.64 25.030 42.170 1437.65 1501.75 1480.42 1527.23 1565.74 1649.50 1729.21 1805.25 1844.09 1880.38 1955.47 2O28.93 2103.78 2179.94 2256;11 2331.00 2402.40 43.410 44.930 45.570 45.870 46.700 47.450 47.300 47.670 48.260 48.4O0 DEFINITI £ North Slope, Alaska Kuparuk 3K 47.840 48.240 47.77O 47.720 47.990 1591.24 27.050 1643.73 -26.740 1686,87 26.810 1782.87 31.640 1879.15 36.550 1975.39 39.040 2025.24 38.590 2071.49 38.040 2167.74 39.410 2262;49 38.920 1544.52 1591.33 1629.84 1713.60 1793.31 1869.35 1908.19 1944.48 2019.57 2093.03 _2167.88 2244.04 2320.21 2395.10 2466.5O 2358.22 38.210 2454.84 37.760 2550.88 37.280 2646.85 40.120 2742.94 43.880 50.39 N 0.72 W 60.10 N 2.01 E 69.66 N 4.60 E 90.19 N 10.26 E 101.55 N 105.96 N 111.08 N 119.79 N 129.27 N 14.05 E 15.81E 18.03 E 22.20 E 27.51E 146.17 N 172.99 N 187.88 N 201.53 N 216.42 N 38.89 E 58.98 E 70.55 E 81.64E 94.61E 231.74 N 248.78 N 262.46 N 295.16 N 332.43 N 108.81 E 125.36 E 139.16 E 172.71 E 211.72 E 372.59 N 393.75 N 413.13 N 453.44 N 493.22 N 254.92 E 277.91 E 299.04 E 343.77 E 388.46 E 533.06 N 572.82 N 611.95 N 652.30 N 695.43 N 432.90 E 477.12 E 520.59 E 565.00 E 612.66 E Global Coordinates Northings Eastings (ft) (ft) 6008459.29 N 529296.82 E 6008491.73N 529305.75 E 6008501.45 N 529308.44 E -6008511.01N 529310.99 E 6008531.57 N 529316.58 E 6008542.94 N 529320.32 E 6008547.36 N 529322.06 E 6008552.49 N 529324.26 E 6008561.21 N 529328.40 E 6008570.71N 529333.68 E 6008587.66 N 529344.98 E 6008614.56 N 529364.97 E 6008629.49 N 529376.48 E 6008643.18 N 529387.52 E 6008658.13 N 529400.43 E 6008673.51 N 529414.57 E 6008690.61N 529431.05 E 6008704.34N 529444.80 E 6008737.18 N 529478.22 E 6008774.60 N 529517.09 E 6008814.93 N 529560.12 E 6008836.18 N 529583.03 E 6008855.64N 529604.09 E 6008896.13 N 529648.65 E 6008936.08 N 529693.19 E 6008976.10 N 529737.47 E 6009016.03N 529781.53 E 6009055.33N 529824.85 E 6009095.85 N 529869.10 E 6009139.17 N 529916.60 E Dogleg Rate (°/100ft) 7.815 1.624 2.310 1.152 4.301 4.782 3.764 3.275 4.3O3 2.811 2.299 0.855 2.828 4.367 4.395 1.437 0.688 5.034 5.122 2.631 0.922 1.288 1.474 0.526 0.826 0.531 0.582 2.959 3.918 Vertical Section 4.83 33.32 41.87 50.20 68.19 78.62 82.89 87.97 96.91 107.22 127.00 159.90 178.47 195.86 215.47 236.28 259.98 279.39 326.22 380.16 439.12 470.37 499.04 559.25 619.09 678.77 738.23 796.72 856.72 921.01 Comment Tie On Point AK-6 BP_IFR-AK 6 September, 2001 - 15:36 Page2of7 DrillQuest 2. 00. 08. 005 Sperry-Sun Drilling Services Survey Report for 3K-19 Your Ref: API-500292302200 Job No. AKZZ11106, Surveyed: 11 July, 2001 Kuparuk River Unit Measured Depth m) Incl. Azim. Sub-Sea Depth Vertical Depth (ft) 2840.07 47.400 48.400 2470.29 2534.39 2935.01 50.330 46.660 2532.75 2596.85 3026.91 54.520 45.200 2588.78 2652.88 3127.22 57.360 46.470 2644.95 2709.05 3223.15 59.440 47.170 2695.21 2759.31 3318.95 62.650 47.340 2741.59 2805.69 3415.84 66.770 46.350 2782.97 2847.07 3511.93 66.240 45.670 2821.28 2885.38 3608.47 65.120 45.160 2861.04 2925.14 3703.22 65.250 46.430 2900.80 2964.90 3798.34 65.160 3894.81 65.520 3990.65 64.590 4087.26 67.110 4183.62 67.210 2940.70 2980.95 3021.37 3060.89 3098.30 48.900 48.870 48.910 48.380 47.820 4280.76 65.930 46.800 3136.92 4376.46 67.150 47.720 3175.02 4473.94 67.180 48.420 3212.85 4568.89 66.490 47.730 3250.20_ 4664.34 64.910 47.800 3289.48 3004.80 3045.05 3085.47 3124.99 3162.40 3201.02 3239.12 3276.95 3314.30 3353.58 4759.18 65.130 48.220 3329.53 3393.63 4855.97 66.290 48.530 3369.35 3433.45 4950.22 65.840 48.210 3407.58 3471.68 5046.80 67.120 48.470 3446.12 3510.22 5143.61 66.980 48.440 3483.87 3547.97 5240.32 65.810 47.480 3522.60 3586.70 5333.34 67.560 48.270 3559.41 .3623.51 5428.93 67.170 47.840 3596.20 3660.30 5526.51 66.130 47.340 3634.88 3698.98 5623.10 64.970 46.130 3674.86 3738.96 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 741.71 N 664.43E 6009185.65 N 529968.18 E 790.00 N 717.14 E 6009234.15 N 530020.70 E 840.66 N 769.44E 6009285.02 N 530072.80 E 898.54 N 829.06E 6009343.13 N 530132.19 E 954.45 N 888.64E 6009399.27 N 530191.55 E 1011.33 N 950.19 E 1071.25 N 1014.08 E 1132.45 N 1077.48 E 1194.20 N 1140.13 E 1254.16 N 1201.78 E 1312.31 N 1369.96 N 1427.10 N 1485.34 N 1544.65 N 1605.08 N 1664.65 N 1724.69 N 1783.01 N 1841.48 N 1899.00 N 1957.59 N 2014.82 N 2073.68 N 2132.81 N 2192.15 N 2249.44 N 2308.41N 2368.83 N 2429.09 N 6009456.40 N 530252.88 E 6009516.56 N 530316.53 E 6009578.02 N 530379.69 E 6009640.01 N 530442.10 E 6009700.21 N 530503.51 E 1265.61 E 6009758.61 N 530567.11 E 1331.66E 6009816.52 N 530632.94 E 1397.13 E 6009873.92 N 530698.18 E 1463.29 E 6009932.42 N 530764.12 E 1529.39 E 6009991.99 N 530829.98 E 1594.91 1659.38 1726.22 1791.17 1855.58 1919.47 1985.42 2049.81 2115.97 2182.69 E 6010052.67 N 530895.26 E E 6010112.50 N 530959.50 E E 6010172.79 N 531026.10 E E 6010231.37 N 531090.82 E E 6010290.10 N 531155.00 E 2248.50 2311.86 2377.48 2443.63 2507.66 6010347.88 N 531218.67 E 6010406.72 N 531284.38 E 6010464.20 N 531348.55 E 6010523.32 N 531414.47 E 6010582.71N 531480.96 E E 6010642.30 N 531546.54 E E 6010699.84N 531609.67 E E 6010759.07 N 531675.06E E 6010819.75N 531740.97 E E 6010880.26 N 531804.76 E Dogleg Rate (°/lOOff) 3.637 3.381 4.730 3.019 2.256 3.354 4.351 0.852 1.256 1.224 2.359 0.374 0.971 2.656 0.546 1.632 1.550 0.663 0.987 1.657 0.464 1.234 0.569 1.348 0.147 1.514 2.037 0.582 1.165 1.656 North Slope, Alaska Kuparuk 3K Vertical Section Comment 990.44 1061.93 1134.71 1217.75 1299.44 1383.25 1470.82 1558.90 1646.79 1732.74 1819.08 1906.74 1993.62 2081.76 2170.56 2259.69 2347.47 2437.31 2524.60 2611.59 2697.56 2785.77 2871.91 2960.46 3049.60 3138.22 3223.64 3311.86 3401.45 3489.36 6 September, 2001 - 15:36 Page 3 of 7 DrillQuest 2.00.08.005 Sperry'Sun Drilling Services Survey Report for 3K-19 Your Ref: API-500292302200 Job No. AKZZ11106, Surveyed: 11 July, 2001 Kuparuk River Unit Measured Depth fit) Incl. 5719.60 67.420 5813.83 68.740 5906.93 67.500 6003.41 66.120 6100.16 65.050 6195.88 65.590 6292.63 65.230 6389.09 65.520 6480.95 64.710 6576.66 66.000 46.30O 45.880 44.820 44.56O 46.920 48.070 48.620 47.450 46.230 46.430 Sub-Sea Depth (ft) 3713.80 3748.98 3783.68 3821.67 3861.66 3901.63 3941.89 3982.08 4020.74 4060.65 6600.02 66.260 46,250 4070.10 6695.02 66.040 45.190 4108.52 6729.59 66,170 45.160 4122.52 6836,82 67.190 45.010 4164.97 6933,45 68.250 44.380 4201.60 7030,24 67,240 48.180 7120.10 66.650 49.080 7214.52 66.770 50.020 7310,78 62.900 47.260 7406.58 63.270 46.850 4238.27 4273.46 4310.80 4351.73 4395.09 Vertical Depth (ft) 3777.90 3813.08 3847.78 3885.77 3925.76 3965.73 4005.99 4046.18 4084.84 4124.75 4134.20 4172.62 4186.62 4229.07 4265.70 4302.37 4337.56 4374.90 4415.83 4459.19 7502.08 64.010 46.770 4437.49 4501.59 7595.37 61.590 49.990 4480.14 4544.24 7691.65 62.020 48.850 4525.63 4589,73 7787.81 62,550 48.120 4570.36 4634,46 7883.91 63.030 48.070 4614.30 4678.40 4657.56 4699.18 4740,15 4781.13 4821.11 7980.26 63.610 47.680 8075.38 64.490 47.430 8171.22 64.900 46.670 8268.43 65.230 46.080 8364,56 65,640 50.370 4721.66 ..4763.28 4804.25 4845.23 4885.21 Local Coordinates Global Coordinates Northings - Eastings Northings Eastings (ft) (ft) (ft) (fi) 2490.17 N 2571.39 E 6010941.60 N 531868.26 E 2550.80 N 2634.37 E 6011002.47 N 531931.00 E 2611.51 N 2695,83 E 6011063.42 N 531992.22 E 2674.56 N 2758,20 E 6011126.71 N 532054.34 E 2736.04 N 2821.28 E 6011188.44N 532117.18 E 2794.80 N 2885.40 E 6011247.46 N 532181,07 E 2853.28 N 2951,13 E 6011306,19 N 532246.57 E 2911.91 N 3016,33E 6011365.08 N 532311,54 E 2968.91N 3077.12 E 6011422.31N 532372.10 E 3028.97 N 3140.04E 6011482.63N 532434.78 E 3043.72 N 3155,49 E 6011497.44 N 532450.18 E 3104.38 N 3217,70 E 6011558.34N 532512.15 E 3126.66 N 3240,12 E 6011580.71 N 532534.48 E 3196.19 N 3309.85 E 6011650.51 N 532603.93 E 3259.75 N 3372.73E 6011714.32 N 532666,57 E 3321.65 N 3437.45 E 6011776.47 N 532731.04 E 3376.30 N 3499.50 E 6011831.36 N 532792.88 E 3432.57 N 3565.50 E 6011887.89 N 532858.65 E 3490.09 N 3630.89 E 6011945.67 N 532923.82 E 3548.29 N 3693.42 E 6012004.12 N 532986.12 E 3606.86 N 3755.81 E 6012062.93 N 533048.28 E 3661.97 N 3817.80 E 6012118.28 N 533110.05 E 3717.17 N 3882.25 E 6012173.74N 533174.28 E 3773.60 N 3945.99 E 6012230.41 N 533237.80 E 3630.68 N 4009.59 E 6012287.74N- 533301.18 E 3888.42 N 4073,45 E 6012345.74 N 533364.81 E 3946.15 N 4136.56 E 6012403.71 N 533427,69 E 4005.18 N 4199.98 E 6012462.99N 533490.88 E 4066.00 N 4263.78 E 6012524.06N 533554.45 E 4124.22 N 4328.97 E 6012582.54 N 533619.40 E Dogleg Rate (°/100fi) 2,544 1.461 1.7oo 1.452 2.481 1.229 O.637 1.143 1.493 1.361 1.317 1.o46 0.384 o.96o 1.252 3,780 1.132 0.923 4.785 0.543 0.778 4.o19 1.135 0.869 0.502 0.702 0.955 0.835 0.647 4.081 North Slope, Alaska Kuparuk 3K Vertical Section Comment 3577.61 3664.99 3751.30 3839.85 3927.88 4014.86 4102.83 4190.51 4273.83 4360.79 4382.14 4468.97 4500.55 4598.91 4688.19 4777.71 4860.39 4947.07 5034.16 5119.57 5205.13 5288.08 5372.90 5458.02 5543.48 5629.57 5715.10 5801.73 5889.86 5977.25 6 September, 2001 - 15:36 Page 4 of 7 DrlllQuest 2. 00. 08.005 Sperry-Sun Drilling Services Survey Report for 3K-19 Your Reft API-500292302200 Job No. AKZ~11106, Surveyed: 11 July, 2001 Kuparuk River Unit Measured Depth Incl. 8460.93 65.520 8557.16 65.030 8652.31 65.590 8747.81 66.030 8843.02 65.980 8939.06 66.190 9035.61 66.450 9129.45 66,800 9225.53 66.260 9322.29 67.060 9418.78 651520 9514.46 65.720 9609.70 65.100 9705.40 64.760 9800.75 66.860 49.750 50.090 49.910 49.090 48.750 48.510 47.900 46.930 49.040 47.810 48.160 47.650 47.420 47.010 46.660 9897,15 66.930 46.490 9991.89 66.790 46.550 10087.99 67.040 46.220 10183.79 65.100 47.610 10279.84 65.040 47.230 Sub-Sea Depth 4860.95 4901.20 4940.95 4980,08 5018.80 5057.73 5096.51 5133.74 5172.01 5210.34 5249.14 5288.64 5328.27 5368.82 5407.89 5445.72 5482.95 5520.63 5559.49 5599.97 Vertical Depth 4925.05 4965.30 5005.05 5044.18 5082.90 5121.83 5160.61 5197.84 5236.11 5274.44 5313.24 5352.74 5392.37 5432.92 5471.99 · 5509.82 5547.05 5584.73 5623.59 5664,07 10375.73 65.110 46.770 5640.38 5704.48 10472,35 65.120 47.160 5681.04 5745.14 10568.25 65.640 46.430 5720.99 5785.09 10664.82 66.380 46.020 5760.26 5824.36 10762.42 66.960 45.990 5798,91 5863.01 47.080 47.35O 46.640 47.720 48.200 10857.37 65.850 10953.79 66.650 11051.23 66.650 11146.51 63.660 11243.20 60.190 5836.92 5875.75 5914.37 5954.40 5999.90 5901,02 ' -5939.85 5978.47 6018.50 6064.00 Local Coordinates Northings 4180.55 N 4236.83 N 4292.40 N 4348.98 N 4406.14 N 4464,16 N 4523,09 N 4581,38 N 4640.37 N 4699.32 N 4758.45 N 4816.87 N 4875.34 N 4934.22 N 4993.72 N 5054.67 N 5114.62 N 5175.60 N 5235.41N 5294.35 N 5353.65 N 5413.47 N 5473.15 N 5534.19 N 5596.44 N 5656.30 N 5716.25 N 5777.26 N 5836.03 N 5893.15 N Eastings 4396.25 E 4463.13 E 4529.35 E 4595.59 E 4661.16 E 4727.04 4792.96 4856.38 4921.86 4988.31 5053.95 5118.61 5182.50 5246.12 5309.55 5373.95 5437.16 5501.17 5565.11 5629.24 5692.84 5756.91 5820.45 5884.16 5948.63 6011.78 6076.55 6141.97 6205.37 6268.72 Global Coordinates Northings (ft) ~6012639.14 N 6012695.68 N 6012751.51 N 6012808.34 N 6012865.76 N 6012924.04 N 6012983.23 N 6013041.76 N 6013101.01 N 6013160.22 N 6013219.61 N 6013278.29 N 6013337.01 N 6013396.13 N 6013455.88 N 6013517.09 N 6013577.28 N 6013638.51N 6013698.58 N 6013757.76N 6013817.32 N 6013877.39 N 6013937.32 N 6013998.61 N 6014061.11 N Eastings (ft) 533686.46 E 533753.12 E 533819.12 E 533885.14 E 533950.48 E 534016.14 E 534081.83 E 534145.02 E 534210.26 E 534276.48 E 534341.88 E 534406.32 E 534469.97 E 534533.36 E 534596.56 E 534660.72 E 534723.70 E 534787.46 E 534851.17 E 534915.07 E 534978.43 E 535042.26 E 535105.57 E 535169.04 E 535233.27 E 6014121.22 N 6014181.42 N 6014242.69 N 6014301.71 N 6014359.08 N 535296.18 E 535360.71E 535425.89 E 535489.07 E 535552.19 E Dogleg Rate (°/lOOff) 0,599 0.602 0.613 0.909 0,330 0.316 0,638 1.020 2.091 1,430 1.630 0,529 0,687 0.526 2.228 0.178 0.159 0.409 2.421 0.364 0.441 0.366 0.879 0,859 0,595 1.573 0.868 0.669 3.302 3.615 North Slope, Alaska Kuparuk 3K Vertical Section Comment 6064.93 6152.28 6238.67 6325.74 6412.71 65O0.49 6588.91 6675.05 6763.17 6852.00 6940.35 7027.49 7114.10 7200.78 7287.74 7376.38 7463.48 7551.86 7639.40 7726.50 7813.45 7901.09 7988.26 8076.45 8166.03 8253.02 8341.27 8430.72 8517.16 8602.46 6 September, 2001 - 15:36 Page 5 of 7 DrlllQt/est 2.00,08,005 Sperry-Sun Drilling Services Survey Report for 3K-19 Your Ref: API-500292302200 Job No. AKZZ11106, Surveyed: 11 July, 2001 Kuparuk River Unit Measured Sub-Sea Depth. Incl. Azim. Depth (ft) (ft) 11337.79 55.750 47.850 6050.05 11432.97 52.100 48.130 6106.09 11527:04 48.290 49.570 6166.30 11624.20 45.810 49.470 6232.50 11719.92 42.630 46.530 6301.09 Local Coordinates Global Coordinates Eastings Northings Eastings . (ft) (fi) (ft) Vertical Depth Northings ' (ft) (ft) 6114.15 5946.77 N 6170.19 5998.25 N 6230.40 6045.81 N 6296.60 6091.97 N 6365.19 6136.59 N 6437.37 6179.92 N 6512.48 6219.54 N 6594.19 6255.55 N 6675.82 6286.28 N 6759.82 6316.33 N 6835.40 6342.27 N 6883.80 6358.18 N 6328.33 E 6385.47 E 6439.86 E 6493.95 E 6543.58 E 6014412.93 N 535611.58 E 6014464.63N 535668.53 E 6014512.41N 535722.73E 6014558.78 N 535776.64 E 6014603.59 N 535826.08 E 11816.03 40.010 47.350 6373.27 6589.93 E 6014647.10 N 535872.27 E 11911.65 36.440 48.610 6448.38 6633.86 E 6014686,89 N 535916.04 E 12010.22 31.510 49.760 6530.09 6675.51 E 6014723.07 N 535957.55 E 12104.45 28.410 48.640 6611.72 6711.14 E 6014753,94 N 535993.06 E 12200.13 28.810 49.390 6695.72 6745.72 E 6014784.12 N 536027,53 E 6776.22E' 6014810.18 N 536057.92 E 6795.10 E 6014826.17 N 536076.73 E 12285.66 27.020 . 49.860 6771.30 12340.00 27.020 49.860 6819.70 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 64.4' MSL. Northings and Eastings are relative to 1447' FSL & 319' FWL. Magnetic Declination at Surface 'is 26,115° (22-Jun-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1447' FSL & 319' FWL and calculated along an Azimuth of 47,796° (True). Based upon Minimum CurvatUre type calculations, at a Measured Depth of 12340,00ft,, The Bottom Hole Displacement is 9305.90ft., in the Direction of 46.902° (True), Dogleg Rate (°/lOOft) North Slope, Alaska Kuparuk 3K Vertical Section Comment 4.704 8682.63 3.842 8759.55 4.217 8831.78 2.554 8902.86 3.952 8969.60 2.784 9033.04 3.821 9092.19 5.044 9147.24 3.343 9194.28 0.562 9240.08 2.109 9280.10 0.000 9304.77 Projected Survey 6 September, 2001 - 15:36 Page 6 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 3K-19 Your Reh APFSO0292302200 Job No. AKZZ11106, Surveyed: 11 July, 2001 Kuparuk River Unit North Slope, Alaska Kuparuk 3K Comments Measured Depth (ft) 861.00 12340.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 859.17 17.98 N 9.78 W 6883.80 6358.18 N 6795.10 E Comment Tie On Point Projected Survey Survey tool program for 3K-19 From To Measured Vertical Measured Depth Depth Depth (fi) (ft) ' (ft). Vertical Depth (ft) 0.00 0.00 861.00 859.17 861.00 859.17 12340.00 6883.80 Survey Tool Description Tolerable Gyro (3K-19 Gyro) AK-6 BP_IFR-AK (3K-19) 6 September, 2001 - 15:36 Page 7 of 7 DrlllQuest 2.00.08.005 o,,Ool- I 0 ~ 03-Aug-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3K-19 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD 'MD 12,340.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED SEP 0 7 2001 Alaska Oil & Gas Cons. Commission Anchorage ~r Kuparuk River Unit North Slope, Alaska Kuparuk 3K, Slot 3K-19 3K-19 MWD Job No. AKMM11106, Surveyed: 11 July, 2001 SURVEY REPORT 6 September, 2001 Your Reft API-500292302200 Surface Coordinates: 6008441.34 N, 529306.67 E (70° 26' 02.9044" N, Kelly Bushing: 64. lOft above Mean Sea Level 149° 45' 39.9138" W) ORI L. LI Nl~i S~RVIC~5 A Halliburton Company Survey Ref: svy9588 Sperry-Sun Drilling Services Survey Report for 3K-19 MWD Your Reft API-500292302200 Job No. AKMM11106, Surveyed: 11 July, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 861.00 10.000 15.000 795.07 859.17 990.65 20.130 15.860 920.11 984.21 1019.65 20.580 15.480 947.29 1011.39 1048.20 19.980 14,630 974.07 1038.17 1111.40 19.420 16.140 1033.58 1097.68 1147.32 19.540 20.660 1067.44 1131.54 1161.54 19.490 22.610 1080.84 1144.94 1178.44 19.060 24.040 1096.80 1160.90 1208.28 18.720 26.960 1125.03 1189.13 1242.03 18.880 31.450 1156.98 1221.08 1303.88 19.610 35.950 1215.38 1279.48 1398.70 21.760 37.040 1304.08 1368.18 1449.39 21.980 38.110 1351.12 1415.22 1495.24 23.140 39.310 1393.46 1457.56 1543.64 25.030 41.720 1437.65 1501.75 1591.24 27.050 43.080 1480.42 1544.52 1643.73 26.740 44.570 1527.23 1591.33 1686.87 26.810 45.270 1565.74 1629.84 1782.87 31.640 45.650 1649.50 1713.60 1879.15 36.550 46.550 1729.21 1793.31 1975.39 39.040 47.360 1805.25 1869.35 2025.54 38.590 47.250 1844.33 1908.43 2071.49 38.040 47.490 1880.38 1944.48 2167.74 39.410 48.140 1955.47 2019.57 2262.49 38.920 48.350 2028.93 2093.03 2358.22 38.210 47.780 2103.78 2167.88 2454.84 37.760 48.120 2179.93 2244.03 2550.88 37.280 47.630 2256.11 2320.21 2646.85 40.120 47.560 2331.00 2395.10 2742.94 43.880 47.870 2402.39 2466.49 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (fi) (fi) (ft) (ft) 17.98 N 9.78 W 6008459.29 N 529296.82 E 50.40 N 0.75 W 6008491.74 N 529305.72 E 60.11 N 1.97 E 6008501.46 N 529308.41 E 69.67 N 4,55 E 6008511.03 N 529310.94 E 90.21 N 10,19 E 6008531,59 N 529316.51 E 101,57 N 13.97 E 6008542.96 N 529320.24 E 105.98 N 15.72 E 6008547.38 N 529321.98 E 111.11 N 17.93 E 6008552.52 N 529324.17 E 119.82 N 22,09 E 6008561.25 N '529328.29 E 129.31N 27.39 E 6008570.76 N 529333.55 E 146.25 N 38.71 E 6008587.74 N 529344.80 E 173.16 N 58.64E 6008614.73 N 529364.63 E 188.13 N 70,15 E 6008629.74 N 529376.08 E 201.85 N 81,16 E 6008643.51 N 529387.03 E 216.85 N 94.00E 6008658.56 N 529399,81E 232.28 N 108.09E 6008674.04 N 529413.85 E 249.41 N 124.53 E 6008691.23 N 529430.22 E 263,17 N 138.25 E 6008705.05 N 529443.89 E 296.02 N 171.66 E 6008738.04 N 529477.17 E 333.42 N 210.56 E 6008775.58 N 529515.91 E 373.66 N 253.66 E 6008815.99 N 529558.86 E 394.98 N 276.77E 6008837.40 N 529581.88 E 414.27 N 297.73E 6008856.78 N 529602.77 E 454.70 N 342.34E 6008897.38 N 529647.22 E 494.55 N 386.98 E 6008937.41 N 529691.71 E 534.43 N 431.38E 6008977.46 N 529735.95 E 574.26 N 475.54 E 6009017.46 N 529779.95 E 613.49 N 518.92E 6009056.87 N 529823.17 E 653.95 N 563.22E 6009097.50 N 529867.32 E 697.20 N 610,78 E 6009140.93 N 529914.71 E Dogleg Rate (°/lOOff) 7.815 1.617 2.341 1.197 4.209 4.594 3.778 3.366 4.312 2.672 2.303 0.898 2.722 4.401 4.425 1.413 0.749 5.035 5.126 2.638 0.908 1.240 1.485 0.536 O.829 0.514 0.589 2.960 3.919 North Slope, Alaska Kuparuk 3K Vertical Section Comment 5.23 Tie On Point 34.06 MWD Magnetic 42.70 51.13 69.34 79.89 84.19 89.31 98.32 108.69 128.55 161.52 180.16 197.58 217.22 238.05 261.77 281.19 328.04 381.99 440.96 472.40 500.88 561.08 620.90 680.56 740,01 798.48 858.47 922.75 6 September, 2001 - 15:37 Page 2 of 7 DrillQuest Z00.08.005 Sperry-Sun Drilling Services Survey Report for 3K-19 MWD Your Ref: API-500292302200 Job No. AKMM11106, Surveyed: 11 July, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2840.07 47.400 48.600 2470.29 2534.39 2935.01 50.330 46.440 2532.74 2596.84 3026.91 54.520 44,880 2588.78 2652.88 3127.22 57.360 46.000 2644.95 2709.05 3223.15 59.440 46.580 2695.21 2759.31 3318.95 62.650 47.010 2741.59 2805.69 3415.84 66.770 46,130 2782.97 2847.07 3511.93 66.240 45.520 2821.28 2885.38 3608.47 65.120 44.840 2861.04 2925.14 3703.22 65.250 46.150 2900.80 2964.90 3798.34 65.160 48.830 2940.70 3004.80 3894.81 65.520 48.800 2980.95 3045.05 3990.65 64.590 48.680 3021.37 3085.47 4087.26 67.110 48.070 3060.89 3124.99 4183.62 67.210 47.560 3098.30 3162.40 4280.76 65.930 46.160 3136.92 3201.02 4376.46 67.150 47.150 3175.02 3239.12 4473.94 67.180 48.050 3212.85 3276.95 4568.89 66.490 47.260 3250.20 3314.30 4664.34 64.910 47.310 3289.48 3353.58 4759.18 65.130 4855.97 66.290 4950.22 65.840 5046.80 67.120 5143.61 66.980 3329.53 3369.35 3407.59 3446.13 3483.88 47.930 48.340 48.130 47.63O 47.670 3393.63 3433.45 3471.69 3510.23 3547.98 5240.32 65.810 46.990 3522.60 3586.70 5333.34 67.560 47.540 3559.42 3623.52 5428.93 67.170 47.040 3596.20 3660.30 5526.51 66.130 46.830 3634.88 3698.98 5623.10 64.970 45.480 3674.86 3738.96 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (fi) (ft) (ft) 743.44N 662.58 E 6009187.38 N 529966.32 E 791.74 N 715.28 E -6009235.88 N 530018.84 E 842.65 N 767.34E 6009287.00 N 530070.70 E 900.94 N 826.56 E 6009345.52 N 530129.68 E 957.40 N 885.62E 6009402.21N 530188.52 E 1014.77 N 946.71 E 6009459.82 N 530249.39 E 1074.99 N 1010.31 E 6009520.29 N 530312.75 E 1136.40 N 1073.51 E 6009581.95 N 530375.71 E 1198.41N 1135.92 E 6009644.20 N 530437.87 E 1258.69 N 1197.25 E 6009704.72 N 530498.96 E 1317.03 N 1260.90 E 6009763.32 N 530562.38 E 1374.76 N 1326.88 E 6009821.31 N 530628.13 E 1432.07 N 1392.20 E 6009878.87 N 530693.23 E 1490.63 N 1458.09 E 6009937.68 N 530758.89 E 1550.26 N 1523.89 E 6009997.58 N 530824.46 E 1611.20 N 1588.93 E 6010058.77 N 530889.25 E 1671.45 N 1652.77E 6010119.27 N 530952.86 E 1732.03 N 1719.11E 6010180.11N 531018.96 E 1790.83 N 1783.63E 6010239.16 N 531083.25 E 1649.84N 1847.55 E 6010298.42 N 531146.93 E 1907.79 N 1911.05 E 6010356.62 N 531210.21E 1966.66 N 1976.75 E 6010415.75 N 531275.68 E 2024.04 N 2041.00E 6010473.38 N 531339.71 E 2083.43 N 2106.69 E 6010533.03 N 531405.16 E 2143.49 N 2172.57 E 6010593.35 N 531470.80 E 2203.55 N 2237.73E 6010653.66 N 531535.72 E 2261.51 N 2300.47 E 6010711.87 N 531598.24 E 2321.35 N 2365.30 E 6010771.97 N 531662.83 E 2382.53 N 2430.75 E 6010833.40 N 531728.04 E 2443.43 N 2494.17 E 6010894.55 N 531791.22 E Dogleg Rate (°/100ft) 3.664 3.530 4.753 2.978 2.229 3.374 4.331 0.802 1.326 1.262 2.559 0.374 O.977 2.671 O.499 1.867 1.589 0.851 1.055 1.656 0.636 1,259 0.519 1.408 0.150 1.371 1.958 0.632 1.084 1.750 North Slope, Alaska Kuparuk 3K Vertical Section Comment 992.15 1063.63 1136.44 1219.51 1301.21 1385.02 1472.61 1560.72 1648.66 1734.65 1820.98 1908.59 1995.43 2083.53 2172.32 2261.44 2349.23 2439.06 2526.34 2613.32 2699.28 2787.47 2873.58 2962.11 3051.25 3139.86 3225.27 3313.49 3403.08 3491.00 6 September, 2001 - 15:37 Page 3 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 3K-19 MWD Your Reh API-500292302200 Job No. AKMM11108, Surveyed: 11 July, 2001 Kuparuk River Unit Measured Depth Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 5719.60 67.420 45.800 3713.81 3777.91 5813.83 68.740 45.620 3748.98 3813.08 5906.93 67.500 44.520 3783.68 3847.78 6003.41 66.120 44.330 3821.67 3885.77 6100.16 65.050 46.780 3861.66 3925.76 6195.88 65.590 47.640 3901.63 3965.73 6292.63 65.230 47.780 3941.89 4005.99 6389.09 65.520 47.140 3982.09 4046.19 6480.95 64.710 45.670 4020.74 4084.84 6576.66 66.000 45.900 4060.65 4124.75 6600.02 66.260 45.650 4070.10 4134.20 6695.02 66.040 45.140 4108.52 4172.62 6729.59 66.170 44.920 4122.52 4186.62 6836.82 67.190 44.870 4164.97 4229.07 6933.45 68.250 44.230 4201.60 4265.70 7030.24 67.240 48.040 4238.27 4302.37 7120.10 66.650 49.050 4273.46 4337.56 7214.52 66.770 50.300 4310.80 4374.90 7310.78 62.900 47.360 4351.73 4415.83 7406.58 63.270 46.790 4395.09 4459.19 7502.08 64.010 46.500 4437.50 4501.60 7595.37 61.590 49.810 4480.15 4544.25 7691.65 62.020 48.470 4525.64 4589.74 7787.81 62.550 47.730 4570.36 4634.46 7883.91 63.030 47.580 4614.30 4678.40 7980.26 63.610 47.490 4657.56 4721.66 8075.38 64.490 47.350 4699.19 4763.29 8171.22 64.900 46.670 4740.15 4804.25 8268.43 65.230 45.870 4781.13 4845.23 8364.56 65.640 50.200 4821.11 4885.21 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (fi) (ft) (ft) (ft) 2505.15 N 2557.29 E 6010956.52 N 531854.10 E 2566.19 N 2619.86E 6011017.81 N 531916.43 E 2627.20 N 2681.03E 6011079.06 N 531977.35 E 2690.54 N 2743.10 E 6011142.63 N 532039.18 E 2752.22 N 2805.98 E 6011204.57 N 532101.82 E 2811.31 N 2869.81 E 6011263.90 N 532165.41 E 2870.50 N 2934.89 E 6011323.35 N 532230.26 E 2929.79 N 2999.50 E 6011382.89 N 532294.63 E 2987.25 N 3059,85E 6011440.59 N 532354.76 E 3047.91 N 3122.20 E 6011501.49 N 532416.87 E 3062.81 N 3137.51 E 6011516.45 N 532432.12 E 3123.82 N 3199,37 E 6011577.71 N 532493.74 E 3146.16 N 3221.73E 6011600.13 N 532516.01 E 3215,91 N 3291.23E 6011670.16 N 532585.24 E 3279.64 N 3353,95 E 6011734.13 N 532647.71 E 3341.70 N 3418.52 E 6011796.45 N 532712.03 E 3396.44 N 3480.48 E 6011851.43 N 532773.78 E 3452.56 N 3546.60 E 6011907.81 N 532839.68 E 3509.87 N 3612,18 E 6011965.37 N 532905.04 E 3568.05 N 3674,73 E 6012023.80 N 532967.36 E 3626.79 N 3736.~5 E 6012082.79 N 533029.34 E 3682.15 N 3798,73E 6012138,39 N 533090.90 E 3737.86 N 3862,90 E 6012194,15 N 533154.86 E 3794,51 N 3926,26 E 6012251,25 N 533217.99 E 3852.08 N 3989.43 E 6012309.07 N 533280.93 E 3910.21 N 4052.94 E 6012367.44 N 533344.21 E 3968,08 N 4115.92 E 6012425.56 N 533406.96 E 4027.16 N 4179.29 E 6012484,89 N 533470.11 E 4088.09 N 4242.99E 6012546.07 N 533533.56 E 4146.53 N 4307,98 E 6012604.76 N 533598.32 E Dogleg Rate (°/100ft) 2.557 1.412 1.725 1.442 2.557 0.992 O.395 0.674 1.698 1.365 1.482 O.543 0.693 0,952 1.257 3.789 1.225 1.223 4.878 0.656 0.821 4.085 1.305 0.876 0.518 0.608 0.935 0.771 0.820 4.119 North Slope, Alaska Kuparuk 3K Vertical Section Comment 3579.27 3666.67 3753.03 3841.65 3929.72 4016.69 4104.65 4192.33 4275.65 4362.63 4383.99 4470.86 4502.45 4600.88 4690.23 4779.78 4862.42 4949.02 5036.05 5121.47 5207.04 5289.96 5374.74 5459.84 5545.29 5631.37 5716.89 5803.53 5891.68 5979.05 6 September, 2001 - 15:37 Page 4 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 3K-19 MWD Your Ref: AP1-$00292302200 Job No. AKMM11106, Surveyed: 11 July, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (fi) Vertical Depth (ft) 8460.93 65.520 49.490 4860.96 4925.06 8557.16 65.030 49.830 4901.20 4965.30 8652.31 65.590 49.920 4940.95 5005.05 8747.81 66.030 49.410 4980.08 5044,18 8843.02 65.980 48.870 5018.80 5082.90 8939.06 66.190 48.440 5057.73 5121.83 9035.61 66.450 47.890 5096.51 5160.61 9129.45 66.800 46.690 5133.74 5197.84 9225.53 66.260 48.630 5172.01 5236.11 9322.29 67.060 47.410 5210.35 5274.45 9418.78 65.520 48.040 5249.15 5313.25 9514.46 65.720 47.460 5288.64 5352.74 9609.70 65.100 47.300 5328.27 5392.37 9705.40 64.760 46.790 5368.82 5432.92 9800.75 66.860 46.460 5407.89 5471.99 9897.15 66.930 46.270 5445.72 5509.82 9991.89 66.790 46.420 5482.95 5547.05 10087.99 67.040 46.030 5520.63 5584.73 10183.79 65.100 47.440 5559.49 5623.59 10279.84 65.040 47.130 5599.98 5664.08 10375.73 65.110 46.550 5640.39 5704.49 10472.35 65.120 46.820 5681.05 5745.15 10568.25 65.640 46.040 5721.00 5785.10 10664.82 66.380 45.840 5760.26 5824.36 10762.42 66.960 46.040 5798.91 5863.01 10857.37 65.850 46.960 5836.92 5901.02 10953.79 66.650 47.240 5875.75 5939.85 11051.23 66.650 46.490 5914.37 5978.47 11146.51 63.660 47.550 5954.40 6018.50 11243.20 60.190 48.130 5999.90 6064.00 Local Coordinates Global Coordinates Northlngs Eastings Northings Eastings (fi) (ft) (ft) (ft) 4203.11 N 4375.04E 6012661.61 N 533665.17 E 4259.70 N d4d1.67 E 6012718.45 N 533731.57 E 4315.41 N 4507.77E 6012774.43 N 533797.45 E 4371.79 N 4574.18 E 6012831.07 N 533863.63 E 4428.70 N 4639.96E 6012888.24 N 533929.19 E 4486.70 N 4705.87 E 6012946.49 N 533994.88 E 4545.67 N 4771.75E 6013005.72 N 534060.52 E 4604.10 N 4835.04E 6013064.40 N 534123.59 E 4663.45 N 4900.18 E 6013124.01 N 534188.49 E 4722.88 N 4966.22 E 6013183.69 N 534254.29 E 4782,31 N 5031,58 E 6013243,38 N 534319.42 E 4840.90 N 5096.09 E 6013302,23 N 534383.70 E 4899,54 N 5159,82 E 6013361.12 N 534447.20 E 4958,61 N 5223,26 E 6013420,44 N 534510.41 E 5018.34 N 5286.48 E 6013480,41 N 534573.39 E 5079,53 N 5350.65 E 6013541.85 N 534637.32 E 5139,67 N .5413,68 E 6013602,24 N 534700.12 E 5200,83N 5477,51E 6013663.65 N 534763.71E 5260,84N 5541,27 E 6013723,92 N 534827.23 E 5319.93 N 5605,26 E 6013783,25 N 534890.99 E 5379.41 N 5668,70 E 6013842,98 N 534954.19 E 5439.54 N 5732,47 E 6013903,36 N 535017.72 E 5499.63 N 5795.63 E 6013963.70 N 535080.65 E 5560,98 N 5859,03 E 6014025,30 N 535143.81 E 5623,31 N 5923,44E 6014087.88 N 535207.97 E 5683.20 N 5986.55 E 6014148.02 N 535270.84 E 5743,28 N 6051,20 E 6014208,35 N 535335.26 E 5804,44 N 6116.48 E 6014269.77 N 535400.30 E 5863,39 N 6179,72E 6014328,96 N 535463.30 E 5920,64 N 6242,95 E 6014386,47 N 535526.30 E Dogleg Rate (°/100ft) 0.682 0.602 0.595 0.671 0.521 0.464 0.587 1.232 1.935 1.423 1.704 0.590 0.669 0.599 2.225 0.195 0.207 O.455 2.431 0.299 0.553 0.254 0.917 0.789 0.623 1.468 0.871 0.707 3.296 3.628 North Slope, Alaska Kuparuk 3K Vertical Section Comment 6066.66 6153.95 6240.26 6327.26 6414.16 6501.90 6590.29 6676.42 6764.53 6853.34 6941.67 7028.80 7115.39 7202.08 7289.05 7377.71 7464.83 7553.23 7640.79 7727.89 7814.84 79O2.49 7989.67 8077.89 8167.51 8254.52 8342.77 8432.22 8518.67 8603.95 6 September, 2001 - 15:37 Page $ of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 3K-19 MWD Your Ref: API-500292302200 Job No. AKMM11106, Surveyed: 11 July, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 11337.79 55.750 47.260 6050.05 6114.15 5974.59 N 6302.25 E 6014440.65 N 535585.39 E 11432.97 52.100 47.610 6106.09 6170.19 6026.62 N 6358.89 E 6014492.90 N 535641.83 E 11527.04 48.290 49.040 6166.30 6230.40 6074.68 N 6412.84 E 6014541.17 N 535695.59 E 11624.20 45.810 48.830 6232.50 6296.60 6121.39 N 6466.46 E 6014588.09 N 535749.03 E 11719.92 42.630 46.540 6301.09 6365.19 6166.30 N 6515.83 E 6014633.19 N 535798.23 E 11816.03 40.010 47.180 6373.27 6437.37 6209.69 N 6562.13 E 6014676.76 N 535844.35 E 11911.65 36.440 48.550 6448.38 6512.48 6249.39 N 6605.97 E 6014716.64 N 535888.04 E 12010.22 31.510 49,530 6530.10 6594.20 6265.51 N 6647.54 E 6014752.92 N 535929.46 E 12104.45 28.410 48.260 6611.72 6675.82 6316.43 N 6663.01 E 6014783.98 N 535964.81 E 12200.13 28.810 49.150 6695.72 6759.82 6346.66 N 6717.43 E 6014814.35 N 535999.11 E 12285.66 27.020 49.760 6771.30 6835.40 6372.69 N 6747.85 E 6014840.50 N 536029.43 E 12340.00 27.020 49.760 6819.71 6883.81 6388.64 N 6766.70 E 6014856.52 N 536048.21 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 64.4' MSL. Northings and Eastings are relative to 1447' FSL & 319' FWL. Magnetic Declination at Surface is 26.115° (22-Jun-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1447' FSL & 319' FWL and calculated along an Azimuth of 46.646° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12340,00ft., The Bottom Hole Displacement is 9306.07ft., in the Direction of 46.646° (True). Dogleg Rate (°/100fi) 4.758 3.846 4.215 2.557 3.717 2.761 3.837 5.032 3.358 0.611 2.119 0.000 North Slope, Alaska Kuparuk 3K Vertical Section Comment 8684.11 8761.02 8833.24 8904.29 8971.02 9034.47 9093.61 9148.63 9195.64 9241.43 9281.42 9306.07 Projected Survey 6 September, 2001 - 15:37 Page 6 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 3K- 19 MWD Your Ref: API-500292302200 Job No. AKMM11106, Surveyed: 11 July, 2001 Kuparuk River Unit North Slope, Alaska Kuparuk 3K Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 861.00 859.17 17.98 N 9.78 W 12340.00 6883.81 6388.64 N 6766.70 E Comment Tie On Point Projected Survey Survey tool program for 3K-19 MWD From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 990.65 984.21 990.65 984.21 12340.00 6883.81 Survey Tool Description Tolerable Gyro (3K-19 Gyro) MWD Magnetic (3K-19 MWD) 6 September, 2001 - 15:37 Page 7 of 7 DrillQuest 2.00.08.005 8/29/2001 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1408 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 1Q-09 )~,,L//-/C~c~ INJECTION PROFILE 08/21/0'1 2B-08 ~,~'L//.--~¢.~ INJECTION PROFILE 08/:20/01 2C-04 )(~r--~'~c~ INJECTION PROFILE 08/18/01 2M-21 ~G~/"'/'c~,~ PRODUCTION PROFILE 08/23/01. 3A-15 ~ ~;~-',;;~' ~ INJECTION PROFILE 08/24/01 3K-19 ,-./~0/.-- /~ JEWELRY LOG (PSP PRESS/TEMP) 08/25/01 3M-24 -/c/~_/?~ SeEP LOG (PRESS/TEMP) 08/21/01 SEP14 ?_001 Alaska 0il & Gas Cons. Commission Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank~l~l~0~e 03-Aug-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE SURVEY Re: Distribution of Survey Data for Well 3K-19 Gyro 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 'MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECENED SEP 0 7 ?.001 Ataska Oil & Gas Cons. C.,omm'~ssio~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Pedorate _X Other 1. Type of request: 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 3829' FNL, 4959' FEL, Sec. 35, T13N, R9E, UM At top of productive interval At effective depth At total depth 2755' FNL, 3435' FEL, Sec. 25, T13N, R9E , UM 5. Type of Well: Development _ Exploratory __ Stratigraphic _ Service_X (asp's 529307, 6008441) (asp's 536077, 6014826) 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3K-19 9. Permit number / approval number 201-108 10. APl number 50-029-23022 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 130' Surface 6628' Production 11664' 608' Size 16" 7-5/8" 5.5" x 3.5" 12340 6884 12206 6765 feet Plugs (measured) feet feet Junk (measured) feet Cemented 3 cu yds High Early 484 sx AS Lite, 320 sx LiteCRETE 190 sx Class G Measured Depth 158' 6656' 11692' 12301' True vertical Depth 158' 6664' 6345' 6849' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) None None 3.5", 9.3#, L-80 @ 11673' No packer Camco Nipple @ 518' MD. RECEIVED AUG 15 2001 Alaska 0il & 6as Cons, Commission Anchorage 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation August 13, 2001 16. If proposal was verbally approved Name of approver Date approved Oil _ Gas __ Service X Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedMichael Mooney ~ )~, ,,).~ Title: Wells Team Leader FOR COMMISSION USE ONLY Questions? Call Tyler Senden 265-6909 Prepared by Sharon AIIsu~-~rake 263-4612 Conditions of approval: Notify Commission so representative may witness I Approval no~)/ Plug integrity __ BOP Test __ Location clearance _ "" · Mechanical Integrity Test _~ Subsequent form re ired 10-~,,,~r~ Approved by order of th~ c0~j_s~J0n ..;~jGk~CAL SIG,~=~~,~ commissioner Date ,.~ I G! NAI_. 3K-19 Procedures Due to the uncertainty of the cement quality, as shown on the attached cement log, Phillips has agreed to complete the well according to the following plan. Perforate the three intervals: · B3 Sands 11950- 11960 MD · A3 Sands 12064- 12080 MD · A2 Sands 12092- 12115 MD Establish injection into the well. Well will be injected into for 2-3 weeks at a flow rate not to exceed 1000 bwpd. During water injection both inner annulus (IA) and outer annulus (OA) pressures will be monitored. 3. Run Water Flow Log (WFL) to determine if there is any upward flow behind pipe (above the top perfs). 4. Review WFL with AOGCC. If upward flow is detected above the top perfs (B3), determine an appropriate remedial fix. 5. After 3-4 months of injection, run another WFL to confirm that injection is staying within the desired intervals. 3K-19 Injector Proposed Completion Schematic Slimhole Base Case- 3-1/2" Completion String PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 16" 62.6# @ +/- 194' MD Depths are based on Nabom 16E RKB Surface csg. 7-5/8" 29.7# L-80 BTCM +/- 7282' MD / 4160' TVD Intermediate csg. 5-1/2" 15.5~ L-80 BTCM +/- 11,600' MD ! 6449' TVD Future Perforations Production csg 3-1/2" 9.3# L-80 EUE8RD 12,065' MD / 6856' TVD 3-1/2" FMC Gen 5 Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Camco 'DS' nipple wi 2.875" No-Go Profile. 3-1/2" x 6' L-80 handling pups installed above and below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" x 1'" Camco 'KBG-2-9' mandrel wi DCK-3 shear valve and latch (Max. OD 4.725", ID 2.90'% IBT box x box, pinned for 3000 psi shear (casing to tubing differential), 3-1/2" x 6' L-80 EUE8RD box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 'CMU' sliding sleeve w/2.81" Camco 'D' profile, EUE8RD box x pin. 3-1/2" x 6' L-80 EUE8RD handling pup installed above I jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 80-40 GBH-22 casing seal assembly w/15' stroke, 3-1/2" L-80 EUE8RD box up, 3-1/2" x 6' L-80 EUE8RD handling pup installed on top Baker Casing Seal Receptacle, 80-40, 5-1/2"BTCM x 3-1/2" EUE8P, D Baker 5" OD x 4" ID 17' Seal Bore Extension CSR set at +/- 180' above top perforation TJM, 5/9/01 Well: Date: From: ...H...a.i...H_.U..rn_.t.../...M...a...r!..e...L...M..~..C..o...n..n...e!! .................. Capital or Expense: .....C..a.p!.t..a! ....................................... Wells (2) Phone/Page ~6..5-~9..-~.7~.8.7..1~./~"~P..g~r.~6...5~.9..-~.7~`~.~.~.~3.~.2..~8' .................... Property Code/AFC: .... ..2..3..o._.D.S...3.~6...K..L..../...,.A...K,0..1....8..3.' .......... DS Lead DSE: .....R:...T.y!e..r..S...e.n..de..n.. ............................................. Estimated Cost*: ....1...2...0...0...0. .... NOB: ...2..0.0. ......... ATO-370 *cost does not include price of pump Proc Bk General Well Work Request Form .... .3..K..;.1...9 .......... Type (Inj/Prod): ...I,.N.J' ......... Budget Category: .....D..r.i!!!.n.~I ................................... Distribution .... _A._u..~l~.U..S.t...1. ,.1_:...2..~.0_.1' ...................................................... Job Scope: .._.D..r.!,!!!,n..~l..S...up.p..o. ~.-..C...a.p..!!,.a. ! ............. PE Supv. DSE Wells Supv. CPF Supv. Primary Objective: Perforate well. Rationale: New well- initial perfs. General: Min ID: 2.812" @ 11630 (SS BAKER CMU) ****Max Hole angle 67° @10762' ***** 7/15/2001 CTU FCO'd well; left 2200' diesel cap. 7/16/2001 Slickline drifted TBG w/2.58" x 20' dummy gun to 12122' WLM (tag depth) 7/17/2001 Eline logged SCMT. Tagged BTM @ 12194' ELM. SCMT indicated bad cement. done at a later date to check for out of zone injection. A WFL will be Procedure: Eline: Note: Use gun-gamma ray string on the first run and tie into Sperry-sun MWD log dated 21-Jul-01 to 1 l-Jul-01. Obtain a jewelry log from 12200' MD to 11580' (above GLM). Do not tie into CBL dated 17-July-2001 as there is a depth descrepency. Perforate the following intervals w/2.5" HSD DP, 4 SPF, 60-120° Phasing. 11950-11960' MD (10') B3 Sand 12064-12080' MD (16') A3 Sand 12092-12115' MD (23') A2 Sand TUBING DETAIL 3-1/2" Slim Hole Completion WELL: 3K-19 KRU DATE: 07/12/2001 PILLIPSAlaska, Inc. ! OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS NORDIC RT TO LDS 26.05 FMC GEN 'V' Tubing Hanger w/Pup (Hanger .80' PUP 2.52'.} 3.22 26.05 Jt# 371 3-1/2" 9.3# L-80 EUE 8rd-Mod tbg 4.5" OD 2,992" ID 31.01 29.27 3-1/2" 9.3# L-80 EUE 8rd-Mod SPACE OUT PUP's(~10.13 & 4.00 ~) 14.13 60.28 Jt.357-370 3-1/2" 9,3# L-80 EUE 8rd-Mod tbg 4.5" OD 2.992" ID 438,09 74.41 PUP 3-1/2" 9,3# L-80 EUE 8rd-Mod pup 4,5" OD 2,992" ID 6,01 512.50 Nipple 3.5"X 2.875"" Camco "DS" nipple OD 3.837" ID 2.875" 1.60 518.51 PUP 3-1/2" 9,3# L-80 EUE 8rd-Mod pup 4,5" OD 2,992" ID 6.09 520.11 jt#3-356 3-1/2" 9.3# L-80 EUE 8rd-Mod tbcj 4,5" OD 2,992" ID 11055.41 526.20 PUP 3-1/2" 9,3# L-80 EUE 8rd-Mod pup 4,5" OD 2,992" ID 5.54 11581.61 GLM 3-1/2" X !" Camco KBG-2-9 w! DCK-3 Shear Valve 4.725"OD 2.9" ID 6.63 11587.15 PUP 3-1/2" 9,3# L-80 EUE 8rd-Mod XO pup 4,5" OD 2.992"' ID 5,68 11593,78 Jr.# 2 3-1/2" 9,3# L-80 EUE 8rd-Mod tbg 4.5" OD 2,992" ID 30,99 11599,46 SS 'Baker Sliding Sleeve 'CMU' 2.812" 'DS' Camco Profile 3.91 11630.45 it# I 3-1/2" 9.3# L-80 EUE 8rd-Mod tbg 4.5" OD 2.992" ID 30,99 11634,36 PUP 3-1/2" 9,3# L-80 EUE 8rd-Mod pup 4,5" OD 2.992" ID 6.08 11665,35 Baker No-Go Sub 4.5" OD 3" ID .83 11671.43 SA Baker 80-40 GBH-22 Seal assembly OD 4" ID 3" (16.67' in CSR] 11672.26 LANDED 1.00' FROM FULLY INSERTED 1.00 11672,26 TOP OF CSR 11673.26 Remarks: String Weights with Blocks:125K# up, 40K# Dh. 23K# Blocks, Ran 371 oints of tubing, Drifted tubing & hanger with 2.860" plastic rabbit. Used Arctic Grade APl Modified No Lead threa compound on all connections, Tubing is non-coated, All tubing Is new Nordic Rig #3 Drilling Supervisoc M,C. HElM CASING DETAIL 5-1/2" X 3-1/2" Casing Description KRU 3K-19 ARCO Alaska, Inc. DATE: 07/11/2001 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS NORDIC RT TO CSG. Flange. 28.15 I 28."i 5 28.15 28.15 28.15 28.15 jt 101-375 5-1/2" 15.5#, L-80, BTC-Mod csg 11633.47 28.15 PUP 5-1/2" Baker Crossover & pup 6.00" OD, 4.937'" ID 11.64 11661.62 11673.26 CSR BAKER Csg. Seal Receptacle 80-40 5" OD 4" ID 19.45' 19.45 11673.26 XO 5" X 3 1/2" XO 5.69" OD 2.992" ID .57 11692.71 PUP 3-1/2",9.3#, L-80, Eue 8 rd Mod Pup 10.10 11693.28 Jt's#4-19 3-1/2", 9.3#, L-80, Eue 8 rd Mod Tbg 502.99 11703.38 3-1/2" Weatherford landing collar @ top of ~t. #3 12194.97 12206.37 it's #3 3-1/2", 9.3#, L-80, Eue 8 rd Mod Tbg 31.60 12206.37 3-1/2" Weatherford Float collar Eue 8rd box x pin 1,17 12237.97 .. it's ~1 & 2 3-1/2", 9.3#, L-80, Eue 8 rd Mod Tbg 60.75 12239.14 3-1/2" Weatherford Float shoe Eue 8rd box. 1.23 12299.89 SHOE Depth 12301.12 DRILLED DEPTH 12340.00 12340.00 , , , Centralizers 3-1/2" Run one 3-1/2" Steel Straight Blade centralizer per Jts. 1 THRU 19. , , Centralizers 5-1/2" Run 5-1/2"' Bowspring Centralizers 1 per/it for 500" above CSR Jts. 1 thru 12. Run 1- 5 1/2" centering ~luide Per Jt. From 365 Thru 375. Remarks: String Weights with Blocks: 180K# Up, 75K# Dn, 20K# Blocks, Ran 294 total joints of casing Drifted casing, & hanger with 2.867" For 3.5" & 4.825" For 5.5" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Tubing is non-cot Nordic Rig #3 Drilling Supervisor: M,C. HElM 07/27/01 11:03 FAX 006 Schlumberger ·"Wmll 3K 19 Reid County Rig Name NORDIC 3 Offshore Zone Drilling Fluid ~/pe Service Line I Cementing Ma~ Allovmd Tubing Pressure 0 psi · Service Instm&tiens Drilled For Oil Well Class Job Type Cementing Service Report I Loc~tion psgM) l I i j Stlt/ovincs AK . [ S~rvice Via Land I Well Type Old [ Workover Max. Denr, ity [ Plastic Viscosi~ 0 lb/gall 0 cp i Cem Interm Casing Max. Niowed Ami, Pressure i WellHead CmlnecGon 0 psi :I: Treatment # 14271 Variable & Product Cost: $14,970.53 GKA Fixed Cost: $17,128,00 Casing/Tubing Sacured [] 'l I:~weg LocMion I Job ~ Prudhoe Bay. AK 7111101 DeviM, on Jei, siz. I W,#MO I WelII~/D o '.lsi. j o~l 0 psi 0 °F 0 'F } 0 psi/It · . , · . · · ' · ....=..' :4. .....i., ....... ' .~.- · :' .L.'. :...:..: .. [.. ';.'- .~t' .... :.': ..: :' ~:..::.:.. :,'i:: ..... .'!.!.':'i ':' ::. ¥' ,".: ::..!~asmg~tr!l~r::':i'~":.-':':':' ~ .:. O~pth. It Size, in I W.ight. IklftI G,ade I Thread J · ~2~35 3.5 I 9.3 I [ ' ~: ~i./!L:,:.:. 'c:.: i:: i: :?::.:':::!.:L'i. ':"~':?:.:/:T~!i~b/DHiI'.] ,ipe~;~. ::.~..: ?"~: ~:. "0,~;~h'. '"'~ .... %~i;' .~'h~,--i ..... '~ .... " / I ',,. I I 1 o ~ o , o I [ ! ! O I 0 0 I 0 Off ~ I 0 0 f 0 o I o o i o o I..Ift Pmsmum: psi 1 Hale V~uma Circulaled pdar to CemmnUngL~.. i Pipe Rotatedi--] Pip RidpmcatedE~ ] $1~e Oepth: 0 ft I To,,t Type: Treat ~ Displacement [ F acker Type Packer D.pth Casing 0 bbl Tubing VoL Casing VoL [ /mnular VoL OpenHole Vol 0 bbl 153 bblI 0 bbl 0 bbl Casing Tools I Squeeze Job Shoe Type: Float 'I sq,~.eze i na. ~enlraliz~m: 0 ?Op ~k4gs: 1 IBotlom Plugs: e~ntHeadTyp: Double " ~ S~geToM~: 0fl I ?~lPipSke: 0in *~""'~ I~''"" ~°"''°": ' ~"~-..0.: I ~'""T'.':' 7/11/01 5:00 I 7/11/01 5:~ , 7/11/01 19:30 ' ::::~sl:~'" .-: -' "::"-='".'"'"-' · '..~' ". .' '" '.~..':'-,"~ =:. ~.'....'.'..:.=, =~~:.~'. ' ..... ' ....... ' .. ' : .......... "~. .~ ..t .'~.:.':')~.'? '::[::':.j:.~.:~:::';E,.L-.::.'=:~]; :'::":.=~.'~.":~":?:L;i:~::'?=:L':'~':: ....... . k .... ?"~J~:: :¥- F.:.'~L'::;. :-- ?..=.? ;.. . ; ;?:.: '.-':~ ........... :'L'..; .:~.:::~..~;:5~': ...... ": '" r:''~.'r':' , .... =,. J ~, '. ": .... :: ';~ ,.~,-'::.'/ ,c ..... :t ;, .,:, :v . =.::.'~' ,,.;,'t ,-'.: ".'j ':.'; ~ ,., .: ,:, ..,,, ..= r~,., .... :,~:,~ ..... :..:, ......... r;,:,,..:.. 4-..:.: .....,....,,. ~.:~{CM~ ~s.s[o I ~ o i 6~ 12soo{ a I ........................ . ,i i , ' .j::' ': '..: :.jj:~ .: .. rj]:{':..'... ! ':. :'~' ~:. :.'~ ": .' ).':' ".; :{ .:.;: :'.:: '~{: :':' ~* ':'~ ':,.:~ ': . :.'": ~'~"i T ':(: ~.'.':: :: :' P. Ost.~o~':Summ'a~ ~.". :.= .h' ...... =....:. '. ::;..: ~. '~ ': .,. :: ". ::' · ¥?. ~* ~ ,* ~.;.:' ~.:::;: :: .. ¥.{ j:j ~'~ ~.: :' ~: ~:~'~;>~;~ ,?~:;-{ .. ,'' ' '. ....... . ".*'"'.~ .. ,'*"'*. ' : ....... ' ..... """", '*', "*."' ~"'~".." .*'..:..'-,'"u::*[h'. .... .:.**.' ..... .. ','*' .' ..'.:.... ,,':'.:.- ~ .'..:*".. · . '>:.'." .'>'~.' .':. :' := : L.:.L'[.:.:: '"'.;'~:*:':}~,:F-'. - Average Pu~Rates, bpm { Volume of Flu~ Injured, bbl j Stu~ N2 Mud Maximin Rate To~ Slu~ -~' 3 2700 J A¥9, N2 Pe~ent Customer or Aulhorized Representative Dink Hiem !, ,. ° I o i . 67_q o i ~o Treating Pressure Summary, psi' j . Breakdown Flukl Final Avera9e llump Plug to ~a~ o ] 2o~ Io I o I J o I De~ Slu~ Vd~e Di~bc~nt -i Mh Wat~ Te~ ~ ~ C.~t ~mulat~ lo ~d~i' V~u~ ~ ~ 63 bbl 0 I0 0 lb/gat 0 bbl Michael Harris I 'D CirculatianLest Job Completud Jut 12,2001 WRb"3 v3.0-SR Page 1 of 1 Legal Well Name: 3K-19 Spud Date: 6/22/2001 Common Well Name: 3K-19 Report #: 3 Report Date: 7/3/2001 Event Name: ROT- DRILLING Start: 6/20/2001 End: · /:;?~?"...'. '::i!('i:ii'~":i:?~i??::i '":... :'":'"'.: Cemen't. Job 'T. yp~ Primai;y ".'=:' :. ' · !. · .;. '..' .. :... .. , . '........" . .. ,' ~:: . "' Hole Size: 6.750 (in) TMD Set: 12,293 (ft) Date Set: 7/11/2001 Csg Type: Intermediate Casing/Lin Csg Size: 5.500 (in.) Cmtd. Csg: OPEN HOLE Hole Size: SQ TMD: (fi) SQ Date: SQ Type: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Hams ..... Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: SQ TMD: SQ Date: Cmtd. Csg: Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Stuck prior cmt Rot Time Start: 15:30 Time End: 19:30 RPM: Init Torque: (E-lb0 Avg Torque: (E-lbo Max Torque: (E-lb0 Rec Time Start: 06:30 Time End: 10:30 SPM: Stroke Length: 15.0 (ft) Drag Up: (lbs) Drag Down: (lbs) Type: Cement Liner Volume Excess %: 75.00 Maas. From: Time Cim Prior To Cementing: 3.00 .Mud Circ Rate: 84 (gpm) Mud Circ Press: 800 (psi) Start Mix Cmt: 15:30 Start Slurry Displ: 15:30 Start Displ: 16:30 End Pumping: 19:30 End Pamp Date: 7/11/2001 Top Plug: Y Bottom Plug: N Disp Avg Rate: 3.00 (bbl/min) Disp Max Rate: 3.00 (bbl/min) Bump Plug: Y Press Prior: 1,200 (psi) Press Bumped: 2,500 (psi) Press Held: 2 (min) Float Held: Y Returns: No Returns Total Mud Lost: 200.00 (bbl) Cmt Vol to Surf: (bbl) 'Ann Flow After: N Mixing Method: Batch Density Meas By: Type: Glycol Enhanced Density: 10.1 (ppg) Visc: 60 (s/qt) Bottom Hole Circulating Temperature: (°F) Displacement Fluid Type: Mud PV/YP: 21 (cp)/20 (Ib/100ft2) Gels 10 sec: 6 (Ibll00fff) Gels 10 min: 7 (Ib/100ft2) Bottom Hole Static Temperature: (°F) Density: 10.1 (ppg) Volume: 259.00(bbl) Type: Volume Excess %: Meas. From: Time Circ Pdor To Cementing: Mud Circ Rate: (gpm) Mud Circ Press: (psi) Start Mix Cmt: : Start Slurry Displ: : Start Displ: : End Pumping: : End Pump Date: Top Plug: Bottom Plug: Disp Avg Rate: (bbl/min) Disp Max Rate: (bbl/min) Bump Plug: Press Prior: (psi) Press Bumped: (psi) Press Held: (min) Float Held: .Mud Data' ., , Returns: Total Mud Lost: Cmt Vol to Surf: Ann Flow After: Mixing Method: Density Meas By: (bbl) (bbl) Type: Density: (ppg)Visc: (s/qt) Bottom Hole Circulating Temperature: (°F) Displacement Fluid Type: PV/YP: (cp)l (Ib/100fff) Gels 10 sec: (Ib/100ft2) Gels 10 min: (Ib/100fff) Bottom Hole Static Temperature: (°F) Density: (ppg) Volume: (bbl) Printed: 8/1/2001 10:40:04 AM Legal Well Name: 3K-19 Common Well Name: 3K-19 Event Name: ROT - DRILLING · . .. i. ' , · · ~' :" ~,., '" ' Spud Date: 6/22/2001 Report #: 3 Report Date: 7/3/2001 Start: 6/20/2001 End: ..... :' ":',. .... ': . · '"' ..... ...... """ ~"~'?!:' :~':"~tage"N6';!2 ' :'~" ' :'.' ......." Slurry""' ': :' ............ No: 1 Slurry Data Fluid Type: FLUSH Slum/Interval: 12,293.00 (ff)'o: Water Source: Lake water Test Data Thickening Time: Free Water. (%) Fluid Loss: (cc) Fluid Loss Pressure: ("F) Description: CWl00 Class: G Purpose: PRIMARY (ft) Cmt Vol: 60.0 (bbl) Density: 15.80 (ppg) Yield: (fP/sk) Mix Water: (bbl) Slurry Vol: 190 (sk) Water Vol: (bbl) Other Vol:'() Foam Job: N Temperature: (°F) TemPerature: (°F) Temperature: (°F) Time Temp Pressure Compressive Strength 1: (°F) (psi) Compressive Strength 2: (°F) (psi) Type: Volume Excess %: Meas. From: Time Circ Prior To Cementing: Mud Circ Rate: (gpm) Mud Circ Press: (psi) · · .... '...:; · .: .. 4. Start Mix Cmt: : Start Slurry Displ: : Start Displ: : End Pumping: : End Pump Date: Top Plug: N Bottom Plug: N Disp Avg Rate: (bbl/min) Disp Max Rate: (bbl/min) Bump Plug: N Press Prior: (psi) Press Bumped: (psi) Press Held: (rain) Float Held: N ~ Retums: :Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: Mixing Method: Density Meas By:. Type: Density: (ppg)Visc: (s/qt) Bottom Hole Circulating Temperature: Displacement Fluid Type: (°F) PV/YP: (cp)/(Ib/10OfF) Gels 10 sec: (Ib/100ff2) Gels 10 min: (Ibll00fF) Bottom Hole Static Temperature: (°F) Density: (ppg) Volume: (bbl) ':., CaSing' Test Press: (psi) For: (min) Cement Found between Shoe and Collar:. ' .Shoe:.TeSt ' .'... IPressure: (ppge) IOpen Hole: (ft) Before Test: ":' ..' · ~..: Liner ¥°pTeSt,;.'i':':'?-:.' I Liner Lap: Pos Test: (ppge) Tool: NOg Test: (ppge) Tool: Hrs Before Test: Cement Found on Tool: · Log/Survey Evaluation · CBL Run: ,Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Interpretation summa~~.''' · · . . . ... .'. · ; · Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Printed: 811120(11 10:40:04 AM Legal Well Name: 3K-19 Spud Date: 6/22/2001 Common Well Name: 3K-19 Report ~ 3 Report Date: 7/3/2001 Event Name: ROT- DRILLING Start: 6/20/2001 End: Pumped 30 bbls. CW100-Test lines to 3500#=pump 50 bbls. mud push @ 12# followed wi 60 bbls. Class 'G' cement @ 15.8fl=:partial retums thru mud push=A~er 5 bbls. cement pumped=lost complete returns. Finish pumping cement followed w/2 bbl. water & displacedw/ mud-bumped plug on calculated strokes=bleed same=floats held. ( Pipe was stuck @ 12293'.) Printed: 8/1/2001 10:40:04 AM AI,ASKA OIL AND GAS CONSERVATION COPl~IISSION TONY KNOWLES, GOVERNOR 333 W. Tm AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 James Trantham Drilling Engineer Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re: Kupanak River Unit 3K-19 Phillips Alaska, Inc. Permit No: 201-108 Sur Loc: 1447' FSL, 319' FWL, Sec. 35, T13N, R9E, UM Btmhole Loc. 2518' FNL, 1814' FEL, Sec 25, T13N, R9E, UM Dear Mr. Trantham: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Our records indicate that at this time there are no approved disposal annuli available on 3K pad, therefore disposal of waste fluids generated from this drilling operation must be in an approved Class I Or Class II well as appropriate. 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 Kupmark River Unit 3K-19 Permit to Drill No. 201-108 Page 2 of 2 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 ~tlay of June 2001 jjc/Enclosures CC.' Department ofFish & Game, Habitat Section w/o encl. Departmem of Environmental Conservation w/o encl. i o. ms PERMIT TO DRILL 20 AAC 25.005 la. Type of work:. Drill I~l Redrill I~l I ,b. Type of well. Exploratory D Stratigraphic Test i'-'l Development Oil r"l Re-entry D Deepen DI 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 34 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 AD L 25519 ALK 2555 Kuparuk River Pool 4. Location of well at sur/ace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 1447' FSL, 319' FWL, Sec. 35, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 2427' FSL, 1716' FWL, Sec. 25, T13N, RgE, UM 3K-19 #59 52 180 At total depth 9. Approximate spud date Amount 2518' FSL, 1814' FWL, Sec. 25, T13N, R9E, UM June 15, 2001 $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) 2763' @ TD feetI 3K-01 13.7' @ 500' feet 2560 12065' MD / 6856' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 300 MD Maximum hole angle 62.4° Maximum surface 2614 psig At total depth (TVD) 3351 psig 18. Casing program Setting Depth size Specifications Top Bottom Quant~ of Cement Hole Casing Weight Grade Coupling Len~h MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 127' 34' 34' 161' 161' 3 cu yds High Early 9.875" 7.625" 29.7# L-80 BTC-Mod 7248' 34' 34' 7282' 4160' 540 sx AS3 Lite, 310 sx LiteCrete 6.75" 5.5" 15.5# L-80 BTCM 11566' 34' 34' 11600' 6449' 200 sx Class G GasBIok 6.75" 3.5" 9.3# L-80 EUE 8rd 465' 11600' 6449' 12065' 6856' 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 Production ,.:'.'.:: 0 ": ?.0 0'I Perforation depth: measured tree vertical 20. Attachments rang fee ~ Proper~ P~at I--I BOP Sketch I--I Diverter Sketch I--I Dri,ing program D,,,ng f, id program E] T,mevsdepth p~ot r"l.efract,on ana,ys~s I--i Sea, ed report E] 20 A^C 2S.0S0 requ,rements I--I 21. I hereby ce~ :ify that the foregoing is true and correct to the best of my knowledge Questions? Call ToddMushovic 265-697, Signed , I~ ,~t~"~~.~LE3(k"~';~ ~'~ Title: Drilling EngineeringSuporvisor Date 3 [ ~ '~'*-'~ames Tranthan PretJared bv ShaT15n AIIsu~-Dral(~ Commission Use Onl) Perm, Number APl number , Approval date ~'_ /~?///...~ j ISee cover letter .~o? -./o <~ s0- o ~. ?_ 2. 3'~ z. z_i /~,,,/(?,/~/ Ifor other requirements Conditions of approval Samples required E~ Yes ~ No Mud log required ! / [-~ Yes J~ No Hydrogen sulfidemeasures ,~ Yes r=l No Directional surveyrequired .~ Yes r'l No Required working pressure for BOPE E~2M; r~ 3M; r'l 5M; D 1oM;r-1 ~. .... "' ::/:,G i ORIGINAL SIGNED BY '" byorderof .... Approved by D Taylor Seamour~it. commissioner the commission Date , Form 10-401 Rev. 12/1/85 · ORIGiiVAL Submit in triplicate (¢' AI~ .... 'at/on for Permit to Drill, Well 3K-19 Revision No.1 Saved: 31-May-01 Permit It- Kuparuk 3K-19 Application for Permit to Dr/Il Document MaxWell I~10 x i ~ iz ~ Well Table of Contents . ! m . . . . al . 10. 11. 12. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ........................................................................................................ 2 Location Summary ................................................................................................... 2 Requirements of 20 AAC 25. 005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25. 050(b) ........................................................................................................ 2 Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AA C 25. 005(c)(3) ................................................................................................... 3 Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25. 005 (c)(5) .................................................................................................. 3 Casing and Cementing Program ............................................................................. 4 Requirements of 20 AAC 25. 005(c)(6) ................................................................................................... 4 Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25. 005(c)(7) ................................................................................................... 4 Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25. 005(c)(8) ................................................................................................... 4 Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25. 005 (c)(9) .................................................................................................. 5 Seismic Analysis ...................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 Evidence of Bonding ................................................................................................ 5 Requirements of 20 AAC 25. 005 (c)(12) ................................................................................................ 5 Permit It, doc Page I of 6 Al?' ":at/on for Permit to Drill, Well 3K-19 ~ Revision No.1 Saved: 31-May-O1 13. 14. 15. Proposed Drilling Program ...................................................................................... 5 Requirements of 20 AAC 25. 005 (c)(13) ................................................................................................ 5 Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 3 Drilling Hazards Summary ............................................................................................... 6 Attachment 4 Cement Loads and CemCADE Summary. ...................................................................... 6 Attachment 7 Well Schematic ................................................................................................................ 6 . . Well Name Requirements of 20 AAC 25.005 (f) Eac?J we// must be identified by a unique name designated by the operator and a unique API number as'5igned by the ~mmis~ion under 20 AAC 25.040{b). For a we// w/th rnultip/e well b/~/Tches; each brahe must sYmi/atJy be identified by a unique name and API number by adding a suffix to the name dc~lnated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submibed will be designated as 3K-[9. Location Summary Requirements of 20 AA C 25. 005(c)(2) An application ((pr' a Permit to Drill must be accoml)an/ed by each of tt~e 5ollowing item.% e,~ept for an item a/ready on file with the (;on'm'~Lcsion and ident/~ed in the application: (2) a p/at identifyhLq the property and ~he p/'operty~ owners and (A)the co¢'dinates ¢ the proposed local/on ol* the well at the surR~¢~, at the top of ead~ o~/ecdve fo/Treat/on, arc at total ciepth, referenced t~ governmental section/ine~; (¢) the e~ordinates of the proposed location of the we// ar the surfi¢c~% ref~,ren~z~d to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Od~,an/c and Atmospheric Adminisb'aEon; (C) the proposed depth of'the wetl at the top of eaO objective tbrmation mTd at total Location at Surface 1447' FSL, 319' FWL, NG$ Coordinates Northings: 6,008.441.34 East/ngs: 529,306.67 Sec 35~ T13N¢ R9E, UM RKBElevati°n1 Pa d E/e va tion 64.4' AMSL 34.1' AMSL Location at Top of 2427' FSL, 1716' FWL, Sec 25, T13N, R9E, UM Productive Interval (Kuparuk "A" Sand) NE$ Coordinates Measured Depthz RKB: 11~771 Northings: 6,014,730 East/ngs: 535,950 Tota/ Vertical Depth~ RKB: 6594 Tota/ Vert/ca/ Depth¢ SS: 6530 Location at Total Depth 2518' FSL¢ 1814' FWL~ Sec 25¢ T13N~ R9E~ UM NGS Coordinates Measured Depth~ RKB : 12~065 Northings: 6,014,821.95 Eastings: 536,047.19 Tota/ VerticalDepth~ RKB: 6856 Tota/ Vert/ca/ Depth~ $$: 6792 and (D) other' information required by 20 AAC 25;050(19); Requirements of 20 AA C 25. 050(b) Ifa well is to be intengional/y deviated, ihe application fora Permit to Dr///(Fom'] .ZO-40./) mus't Permit It. doc Page 2 of 6 ,,, Ap*"-at/on for Permit to Drill, Well 3K-19 l, '{ Revision No.1 Saved: 31-May-01 3m m Bm (]) include a p/a~, drawn to a suitable sca/e, showing the pat/? of the proposed wetlbore, /hduding ail adjacent wetlbores w/thin 200 feet of any portion of the proposed we/I; Please see Attachment 1: Directional Plan and (2) for ail wells within 200 feet of the proposed wellbore (A) list the/lames of the operator~ of those we/Is, to the extent that t/lose names are known or discoverable in public records, and show that each named operator Ilas been furnished a copy of tile appli£ation by certified mai/; or (B) state that the applicant ~'~ the only at~e£ted owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Dr/Il must be accompanied by each of the fo/Iow/nE iten?~, except for an item a/ready on file ~ith the commi&~ion and identified in the application: (3) a diagram and description of tile blowout prevent/on equipment (BOPE) as required by 20 AAC 25.05~ 20 AAC 2~.03~; or 20 AAC 25.057, as appticabl~;' Refer to documents on File Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An a~li£ation fbr a Permit to Dr/Il mu. et be accompanied by each of the lb/lowing item~ except for an item already on file with the commia%¢ion and identified fi~ the app/ication: (4) information on drilling hazar~. /)~c/uding (A) t/)e max/mum downho/e pressure that may be en(:ountere~ crit~?ria used to det~?rmine it; and max/mum poten~a/.s'urface pres.sTzre based on a methane ¢'ad/ent; The expected reservoir pressure in the Kuparuk sands in the 3K-19 area is expected to be 3300 psi, 0.50 psi/fi. This pressure was extrapolated from offset wells. The maximum potential surface pressure (IvlPSP) based on the expected reservoir pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the Kuparuk formation is 2614 psi, calculated thusly: MPSP =(6702 fi)(0.50 - 0.11 psi/fi) =2614 psi (Bp data on potent/al gas zone~;' The well bore is not expected to penetrate any gas zones. and (C) data concerning potent/a/cause.~~ of'hole problems such as abnomTa//y geo..pfes.~ured strata, lost circulation zones, and zone~ that have a propensity tbr d/~erent/;?/ Please see A~achment 2: Drilling Hazards Summed. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25. 005 (c)(5) An ~pp//caEon for a Permit ~o Dd// must be accompanied by each OF the ~o//owkLq it~m~ except tbr an ilem a/ready on file w/th the comm/~:sYon and identified in the application: (~7 a de~cdpEon OF the procedure eot cz~nduc¢/f~g format/on/ntegr/iy tsst.~; as req~ed under 20 ~C A formation integriW test will be performed in accordance with the LOT / F~T procedure that Phillips Alaska has on file with the Commission. ORIG Permit It. doc Page 3 of 6 i A "'"ration for Permit to Drill, Well 3K-19 ' Revision No.1 Saved: 31-May-01 6. Casing and Cementing Program Requirements of 20 AAC 25. 005(c)(6) An application for a Permit to Pffll must be accompanied by each of the following items~ except for an item a/ready on file with the commission and identified in the application: (d) a complete proposed casing and cen?enting program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program Hole Top Btm Csg/'l'bg Size Weight Length MD/TVD MD/-rVD OD (in) (in) (Ib/ft) Grade Connection (ft) (fl) (ft) Cement Program 16 24 62.5 H-40 Welded 160 Surface 161 / 161 Cemented from surface 7-5/8 9-7/8 29.7 L-80 BTCM 7248 Surface 7282 / 4160 See Attachment 5-1/2 x 6-3/4 15.5 & L-80 BTCM & 11,600 Surface / 12065 / 6856 See 3-1/2 9.3 EUE & 465 11,565.9 Attachment See also Attachment 3: Cement Loads and CemCADE Summary. 7. Diverter System Information Requirements of 20 AAC 25. 005(c)(7) An application fbr a Permit to Drill must be accompanied by each of the fo/lowing items, except tbr an item a/ready 0/7 file with the cofllmission and identified in the app/i~ti[xr (7) a diagram and de_~ripfion of the diverter system as required by 20 AAC 25',035; un/ess this requirement is waived by the commist~on under 20 AAC 25. 035(h)(2); Please refer to documents on file with the Commission for Nordic Rig 3. Drilling Fluid Program Requirements of 20 AAC 25. 005(c)(8) An application/bt' a Permit to Drill must be accompanied by eac?z of'the fbl/owirLq item.% except tbr an/tern a/ready on file w/th the comnTission and identified in the a~licalion: (~) a drilling fluid p~Tram, including a diagram and description of the WHN~q fluid ~stem, as requited by 20 AAC 25,033; Drilling will be done with a bentonite slurry having the following properties over the listed intervals: Interval Density Funnel Yield Point Plastic 10 sec Gel 10 min Gel (ppg) Viscosity (cP) Viscostiy Strength Strength (seconds) (lb/lO0 sf) (lb/lO0 sf) (lb/lO0 sf) Surface Hole Surface to 500' 8.5 - 9.0 150 - 200 50 -70 40 - 60 15 - 30 8 - 15 500' to Base of Permafrost 8.6 - 9.4 100 - 150 Final 9.4 - 9.6 60 - 150 25 - 50 20 - 40 15 - 40 4 - 6 Production hole Tnitial section 8.6 - 9.0 35 - 45 8 -12 5 - 10 3 - 6 8 - 15 Intermediate section 10.5 45 - 55 15 - 25 20 - 25 6 - 10 <5 Pay-Zone 10.5 50 - 65 15 - 25 25 - 35 4 - 7 8 - 10 (Tau 0) (HTHP) Please refer to documents of file with the Commission for Nordic Rig 3. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Permit It. doc Page 4 of 6 'i, A "-at/on for Permit to Drill, Well 3K-19 Revision No.1 Saved: 31-May-01 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to DHII must be accompanied by each of the fo/lowing items, except for an item a/ready on fi/e w/th the commission and identified in E~e ap~licaflbn: (~) for an ezplorato~ or ¢tfatigraphic test wel~ a tabulation setting out tf~e depth~ required by Not applicable: Application is not for an explorato~ or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Per,flit to Dr/Ii must be accompanied by each of the fo//owing items; except for an item a/ready on file with the commiss?on and identified in the application: (10) for an explorato~ or stratigraphic test wel~ a seismic refrac?ion or reflec?ion analysis as re~7uired by 20 ~C 2~ 061(a); Not applicable: Application is not for an explorato~ or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application fbr a Permit to Dr/Il must be accompanied by each of the th/lowing item~ except tbr an item already on file with the commission and identified in the applicati~x~: (lZ) ~r a well drilled from an of[shore platfom; mobile bottom..founded structur~, jack-up rLg, or floafifLg drillifLq vesse~ an analy.¢is of s~abed conditions' as required by 20 AAC 25;057(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application fbr a Permit to Dr/II must be accompanied by ead~ of'the tbllowirLq itern.$ except tbr an/tern a/ready on fife with the c'ornnTission and identified in the application: (12) evidence showing that the requirements of 20 ~C 25,025 {Bond/nE}have been meC Evidence of bonding for Phillips Alaska, [nc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25. 005 (c)(13) An application tbr a Permit to DH/I must be accompanied by each of the fo/lowing item,s except fbr an item already on file witl7 the commission and identified/i~ the application: The proposed drilling program is listed below. Please refer as well to A~achment ~, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16" conductor. Weld landing ring on conductor. 2. MIRU Nordic Rig 3. Install diverter and function test same, 3. Spud and directionally drill 9-7/8" hole to desired targets through West Sak interval. Run MWD/LWD/PWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Circulate and condition hole to run casing. POOH. 5. Run and cement 7-5/8' 29.7# L-80 BTCM casing string to surface. Displace cement with mud and perform stage job or top job if required. 6. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test to 5,000 psi. 7. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. Permit It. doc Page 5 of 6 A~."~, 'ation for Permit to Drill, Well 3K-19 Revision No.1 Saved: 31-May-01 8. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 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 Fl-I- or LOT EMW). 9. Directionally drill 6-3/4" hole to K1 marker (11360' MD) according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. Perform second LOT to evaluate long string option. If LOT is adequate to long string, drill to well total depth (12065' MD), run 5-1/2" 15.5# by 3-1/2" 9.3 L-80 BTCM/EUE casing to surface and cement, and continue with step #15. 10. If LOT is inadequate to Iongstring than drill 6-3/4" hole to a TD of 11,600' MD, run 5-1/2" 15.5# L-80 BTCM casing to surface and cement. 11. Nipple up BOP stack and pressure test to 5,000 psi. 12. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 13. Drill 4-3/4' hole to well total depth (+/- 12065' IVlD) according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH 14. Run and cement 3-1/2" 9.3# L-80 SHLT liner and Baker ZXP/Flexlock hanger/packer assembly. Set packer +/- 150' above intermediate casing shoe to provide appropriate liner lap. 15, Run and land 3-1/2" tubing with gas lift completiom. 16. Pull landing joint. ]:nstall BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Tnstall test plug. Pressure test production tree. Pull test plug. Secure well. 17. Freeze protect well. Set BPV. Release rig and turn well over to production. 18. Clean location and RDMO in preparation for coiled tubing cleanout and perforating, 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) At7 app/icafio/7 £or a Permit.' to Dr/Ii mu.¢tc be accompa/~ied by ea£h of'the £ollowi/Lg ite/n.% e~?ept' for a/~ #/em a/ready on file with the con?n~/:ssio/~ and identified i/~ the application: (.Z d) a genera/description of how the operator plans to dispose of drill~?~z mud and ~zzttings' and a state, men~ o? whether opera,or intends to request author/zation under 20 A,4C 25~ 080 for an annular d/sposal operation in the Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 3K pad, or by hauling the fluids to a KRU Class ]3: disposal well. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. Phillips Alaska intends to request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary. Attachment 4 Well Schematic. ORIG Permit It. doc Page 6 of 6 i=iV~,.,Printed:SI-May-01 3K-19 Injector~rr PHIILLIPS Alaska, Inc. Proposed Completion Schematic ^ Subsidiary of PHILLIPS PETROLEUM COMPANY Slimhole Base Case - 3-1/2" Completion String 16" 62.6# @ +/-194' MD Depths are based on Nabors 16E RKB Surface csg. 7-5/8" 29.7# L-80 BTCM +/- 7282' MD / 4160' TVD Intermediate csg. 5-1/2" 15.5# L-80 BTCM +/- 11,600' MD / 6449' TVD Future Perforations Production csg 3-1/2" 9.3# L-80 EUE8RD 12,065' MD / 6856' TVD 3-1/2" FMC Gen 5 Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUESRD Tubing to Surface 3-1/2" Camco 'DS' nipple w/2.875" No-Go Profile. 3-1/2" x 6' L-80 handling pups installed above and below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" x 1" Camco 'KBG-2-9' mandrel w/DCK-3 shear valve and latch (Max. OD 4.725", ID 2.90"), IBT box x box, pinned for 3000 psi shear (casing to tubing differential), 3-1/2" x 6' L-80 EUE8RD box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 'CMU' sliding sleeve w/2.81" Camco 'D' profile, EUE8RD box x pin. 3-1/2" x 6' L-80 EUESRD handling pup installed above 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 80-40 GBH-22 casing seal assembly w/15' stroke, 3-1/2" L-80 EUE8RD box up, 3-1/2" x 6' L-80 EUE8RD handling pup installed on top Baker Casing Seal Receptacle, 80-40, 5-1/2"BTCM x 3-1/2" EUE8RD Baker 5" OD x 4" ID 17' Seal Bore Extension CSR set at +/- 180' above top perforation 3K-19 Drilling 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 / 7-5/8" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Careful well planning and surveying, adherence to anti-collision policy Gravel and sand Low Elevated mud viscosity from spud; Hi dens sloughing sweeps. Shaker/Trough Ball Mill Low Controlled ROP Overflow Shoe Fracture/Lost Moderate Reduced pump rates, and lightweight tail Returns during cement cement job 6-3/4" Hole / 5-1/2 & 3-1/2" Casinq Interval Event Risk Level Mitigation Strategy Shale' Stability in HRZ Moderate Control with higher MW and proper drilling practices. Hole cleaning in long, Moderate Good drilling practices. high angle tangent High ECD and High Pumping and rotating out on all trips to swabbing if higher MW reduce swab and barite sag potential. is required Shale stability across K- High Control with higher MW and proper drilling 1 interval practices. 3K- 19 Drilling Hazards Summary. doc prepared by Todd Mushovic 5/9/01 O£1 ItViIL Page I of I Schiumberger Rig: Nabors 16E Location: Kuparuk Client: Phillips Alaska, Inc. Revision Date: 5/22/01 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com < TOCat Surface Previous Osg. < 16", 62.6~ casing at 120' rvD < Base of Permafrost at 1,851' IVD (1,638' 'rVD) < Top of Tail at 4,990' IVD < Top of West Sak at 5,790' IVD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 7,282' IVD (4,162' TVD) Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems (Volumes are based on 250% excess in the permafrost and 45% excess below the permafrost. Top of tail slurry is designed to be 800' above West Sak formation. Lead Slurry (Minimum thickening time: 240 min.) ASLite @ 10.7 PP~I, Class G + 50%D124, 9%D44, 0.4%D46, 30%D53, 1.5%S1, 1.5%D79 - 4.44 ft'?sk 0.9513 ft3/ft x (120') x 1.00 (no excess) = 0.2148 ft3/ft x (1851' - 120') x 3.50 (250% excess) = 0.2148 ft3/ft x (4990' - 1851 ') x 1.45 (45% excess) = 114.2 ft3 + 1301.4 ft3+ 977.7 ft3 = 2393.3 ft3/4.44 ft3/sk = Round up to 540 sks 114.2 ft3 1301.4 ft3 977.7 ft3 2393.3 ft3 539 sks Have 170 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry (Minimum thickening, time: 170 min.) LiteCRETE @ 12.0 ppg - 2.40 ft°/sk 0.2148 ft3/ft x (7282'- 4990') x 1.45 (45% excess) = 0.2578 ft3/ft x 80' (Shoe Joint) = 713.9 ft3 + 20.6 ft3 = 734.5 ft3/2.40 ft3/sk = Round up to 310 sks 713.9 ft3 20.6 ft3 734.5 ft3 306 sks BHST -- 93°F, Estimated BHCT - 87°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate Volume Stage Stage Time Cumulative Time (bpm) ibbl), , (min) (min), , CW100 6 40 6.7 6.7 Drop Bottom Plug 3.0 9.7 MudPUSH XL 6 50 8.3 18.0 Lead Slurry 6 427 71.2 89.2 Tail Slurry 6 133 22.2 111.4 Drop Top Plug 3.0 114.4 Displacement 6 311 51.8 166.2 Bump Plug 3 20 6.7 172.9 MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* XL, Pv = 17-20, Ty = 20-25 Centralizers: Recommend 1 per joint from 4790' MD to TD for proper cement placement. *Mark of SchIumber§er ORIGINAL Schlumberger Rig: Nabors 16E Location: Kuparuk (EBA) Client: Phillips Alaska, Inc. Revision Date: 5/22/01 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@ slb.com < Base of Permafrost at 1,851' r~L)(1,638' ~VL)) Previous Csg. < 7 5/8", 29.7# casing at 7,282' IVD < 5 1/2", 15.5# casing in 6 3/4" OH < TOC at 10,724' t~) < Top of Kuparuk D at 11,524' IVD < X-over at 11,600' IVE) < Top of A3/l'arget at 11,773' r VD < 4 1/2", 12.6# casing in 6 3/4" OH TD at 12,067' IVD (6,861' TVD) Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems (Volumes are based on 75% excess. Top of tail slurry is designed to be 800' above the top of Kuparuk D formation. Tail Slurry (minimum thickening time 150 min.) GasBLOK w/Class G + 3% D53, 2 gps D600, 0.15 gps D135, 0.12% D800, 0.2% D047, 0.6% D065, per lab testing @ 15.8 ppg, 1.2 ft3/sk 0.0835 ft3/ft x 876' x 1.75 (75% excess) = 0.1817 ft3/ft x (12067'- 11600') x 1.75 (75% excess) = 0.0854 ft3/ft x 80' (Shoe Joint) = 73.1 ft3 + 148.5 ft3 + 6.8 ft3 = 228.4 ft3/1.2 ft3/sk = Round up to 200 sks 73.1 ft3 148.5 ft3 6.8 ft3 228.4 ft3 190.3 sks BHST = 157°F, Estimated BHCT = 133°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate Volume Stage Stage Time Cumulative Time (bpm) (bbl), , (min) imin), , CW 100 6 40 6.7 6.7 Drop Bottom Plug 3.0 9.7 MudPUSH XL 6 50 8.3 18.0 Tail Slurry 6 43 7.2 25.2 Drop Top Plug 3.0 28.2 Displacement 6 262 43.7 71.9 Bump Plug 3 20 6.7 78.6 MUD REMOVAL Recommended Mud Properties: 10.4 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* XL, Pv = 19-22, Ty = 22-29 Centralizers: Recommend 1 per joint from 10524' MD to TD for proper cement placement. 'Hark of SchTumber§er 2400 - Phillips Alaska, North S~ope, Allaska 3K Pad 3K 19 Well: 3K-19 Ref Global Coordinates: 6008441 34 N, 52930667 E Ref Structure: I2.60 N, 054 E Ref Geographical Coordinates: 70° 26' 027862" N, 149° 45' 399463" W (1447' FSL & 319' FWL, Sec 35-T13N-R9E) RKB Etevat~oa: 64 40ft above Mean Sea Level North Referer~ce: True North Units: Feet ~ T T I ~ ~ T 1 T 1200 2400 3600 4800 6000 7200 8400 9600 sca~e: ~ir~c~ ~- ~2oo¢~ Sectior! Azimuth; 46796° (True ,Norlh) Eastings ? 1_2~o 2400 L :~o 4800 ~ (',,o o o J 7200 ;,.~o~o Current Well Properties Well: 3K4 9 Horkont~ Coordinates: Ref Gbb81 C~dinabs:6008441 3,4 N. 52930667 ] T F ! 1200 2400 3600 4800 6000 Scale: linch = 1200ft 7200 - 6000 - 3600 1200 Phillips Alaska, Kupamk River UDit 3K Pad 3K-19 Reference is Due Nor!h Sperry-Sun Anticollision Report i KUparUk:River unit RefereneeSite: Kuparuk 3K Pad Date.; 5/31t2001 Tinie:. 01:18:17. ' Page: 1 C0~Ordinate(NE)Reference: Well: Plan: 3K-19, True North Vertical (TVD) Reference: 3K~19 64.4. Db: SYbase GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 64.40 to 12064.90 ft Scan Method: Tray Cylinder North Maximum Radius: 1400.05 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/3112001 Validated: No Version: 4 Planned From To Survey Toolcode Tool Name ft ft 64.40 800.00 Planned: 3K-19 wp02 V1 CB-GYRO-SS Camera based gyro single shots 800.00 12064.90 Planned: 3K-19 wp02 Vl MWD+IFR-AK-SCC MWD+IFR AK SCC Sperry Casing Points :!/;' :':~/:~': :?i~i~i~::,!.;i:,::!!~::!i:i: ,:? .' ::':.i.!~:~i::':,~/i :.i::~:i::~:~i.~' i~:i:.:.';i':, :. i: :~ :.! .::: ~ :~ :i;:::: !:~: ::!! i,':; ~:i i' ~::.: i: ::: :: .i: '~ ~:; :: :~: ::i i::~: ?:: i~:..!: ~. ~:! :~::.:i:.:~:,;:.:'~'~:': ~i~:: i.~ !/~!~. i. ~:i i;/i~ '=.i~ ~ ~= ~i~i~i !!/~.=i/~, i' i~. i ~= ;i ~i~ ! ?.i?i?~ '=.~.i':i~ i~'. ~i ~'=;~,=, :i~.~ {~'i::'"'"'"it'" ................... ........ ~t i', ............. ' ............... 'i'/~ ' ' ' ~F2-8-2~6' ',;i.:i"~- -'7.-~-g~-7'~ ':~7~;; 112067.00 0.00 5.500 6.750 5-1/2" / Summary Site Well Wcllpath MD 3'Il) l)istanee Area Deviation Warning ft ft ft ft ft Kuparuk 3K Pad 3K-01 3K-01 V0 499.30 500.00 13.65 8.50 5.16 Pass: Major Risk Kuparuk 3K Pad 3K-02 3K-02 V0 399.11 400.00 37.64 6.73 30.91 Pass: Major Risk Kuparuk 3K Pad 3K-03 3K-03 V0 398.51 400.00 62.27 6.58 55.70 Pass: Major Risk Kuparuk 3K Pad 3K-04 3K-04 V0 397.92 400.00 85.50 6.92 78.59 Pass: Major Risk Kuparuk 3K Pad 3K-05 3K-05 V0 300.00 300.00 113.35 5.22 108.12 Pass: Major Risk Kuparuk 3K Pad 3K-06 3K-06 V0 396.80 400.00 137.72 6.60 131.13 Pass: Major Risk Kuparuk 3K Pad 3K-07 3K-07 V0 396.32 400.00 162.42 6.47 155.95 Pass: Major Risk Kuparuk 3K Pad 3K-08 3K-08 V0 395.61 400.00 188,74 6.81 181.94 Pass: Major Risk Kuparuk 3K Pad 3K-09 3K-09 V0 395.14 400.00 213.16 6.78 206.39 Pass: Major Risk Kuparuk 3K Pad 3K-09A 3K-09A V0 395.16 400.00 211.23 6.58 204.66 Pass: Major Risk Kuparuk 3K Pad 3K-20 Plan 3K-20 V11 Plan: 3 498.81 500.00 26.61 10.40 16.22 Pass: Major Risk Kuparuk 3K Pad 3K-22 3K-22 V2 978.87 1000.00 57.42 18.49 41.94 Pass: Major Risk Kuparuk 3K Pad 3K-22A 3K-22A V1 978.87 1000.00 57.42 18.49 41.94 Pass: Major Risk Kuparuk 3K Pad 3K-23 3K-23 V2 397.70 400.00 99.08 7.11 91.98 Pass: Major Risk Kuparuk 3K Pad 3K-24 3K-24 V7 1364.50 1400,00 137.00 33.95 104.25 Pass: Major Risk Kuparuk 3K Pad 3K-25 3K-25 V1 396.43 400.00 151.69 6.83 144.86 Pass: Major Risk Kuparuk 3K Pad 3K-26 3K-26 V1 395.94 400.00 174.58 7.21 167.37 Pass: Major Risk Kuparuk 3K Pad 3K-27 3K-27 V2 299.98 300.00 199.70 5.39 194.30 Pass: Major Risk ORIGINAL PHILLIP'. Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 May 31, 2001 Ms. Camille Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: KRU 3Kol 9 Surface Location: Target Location: Bottom Hole Location: 1447' FSL, 319' FWL, Sec. 35, T13N, R9E 2427' FSL, 1716' FWL, Sec. 25, T13N, R9E 2518' FSL, 1814' FWL, Sec. 25, T13N, R9E Dear Ms Commissioner: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 3K-19. The well will be drilled and completed using Nordic 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 3K, or hauled to an approved Prudhoe Bay or GKA Class II disposal well. 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 Longdon, Geologist 263-4506 If you have any questions or require further information, please contact Todd Mushovic at (907) 265-6974 or James Trantham at (907) 265-6434. Sincerely, ,lames Trantham Drilling Engineering Supervisor RECEIVED 0 'i 200t Afaska Oi~ & 6~s Cons. Commission Anchorage ORIGII XAL. American Express® Cash Advance Draft 137 Issued by Integrated Payment System, Inc. Englewood, Colorado NOT VALID FOR AMOUNT OVER $ 1000 Payable at NorWest Bank of Grand Junction - Downtown, N~ /'~,,,,/SHAROI~//~f~, LS~DR~ Grand Junctk~n. Colorado ~,~.~f PERIOD ENDING ~',d'~ ~.. ' :.?:,:,".. .. ., Annular log ~,1 [KRU ~_~N-329 JSUN j98-067 j5/0/98 5/14/98 I yY IY IN i 7/27/991 1091from AAI report submitted 2/26/99 ~ 1K-R-U - i;~N~-331 .... ~N~ i98-117 9/11/98 P~,{- KRu-'2N:33~ ...... ~§L~N--~200-O797,17,00 _~/~15/~) I !~ IN I ]contingent on 10-403, in we, file i I i I I il 0-407 (~L300-187) submitted 7/17/2000 w/LOT & cmt'g info :~,'1- IKI~U 'I2N~3~- ..... S~N-~-204 10/19/98 11/25/98 i ty . i f i 254951from PPCO 10/13/2000quartedyrepod ~ IY iY IY 10/5/99! 306391from AAI report submitted 2/26/99 AAI" i~R-u ~ !2N~7/, ..... ]S~-- {~8-122 16/19/98 17/17/98 I I IY IN tN I icontingent on 10403, not in well file as of 9/20/00 ~,1- - KRU !2N-341 -- -lSUN ~8-103 17/6/98 ~ tY i I i 341501fm: PPCO 10/13/2000 quarterly report, ddlling notes indicate 2N-341 in communication with 2N-347 /~.A~'' tt<I~jI~N/34; .... ~S_uU._~- ~3"5/18/98 ]5,14/98 ' '! Y ~ INY '[ 7/27/99'i 31808 Csg~ettera~~r~va~~nt~2N~328~2~~329~2N-343~~njectedv~~umew~c~m~~~rptdated7/27~99~~a~~edpr~d~cmL /u~,,- iKRU 2~1-34~- -- ~ 17'18'98 8/23/98 ! I I ~5~bb~scrntt~surtace~n~br~aching~v~~umefr~mPPC~1~~13/2~~~quarted~r~~~rt~dd~~~ngn~~es ] ........ /- {----- 16/16/00 i7/21/00 ! I 31640iindicate2N-341 in communication with 2N-347 PA CRU 2N-347 ~ SUN ~200-O63 , ~A~ iKRU I?~-34~- .... ~ON~ i200-111 I !srr I I i I I ! lw/request annular at later date. Srras349A, no lO-403 in well file as of 9/20/O0 P~I ' ~CRu' ~5~-~34~9A - -- §U~-!~-00-139 i I ! I i I j LOT @ shoe to 11.86, 2nd LOT for annular to 10.72, Sundry approval #300-278 PAl- 'i KRU -~2~-41-7 .... ~N_~ I I I I i I I l w/request approval after well ddlled. PAl i~,RU 12p-42-9 ........ ~U1~-~01-102 I I ~ w/request approval after well ddlled. 15Al ~ JKRU 2P-447 ISUN 201-104 II I I I I I afferwellddlled. 6/4/95 ' , ~ iw/request approval after well ddlled. ~,~-- li<~-u-12~-5~ .... l~fb 195-0~3 N/A I i I I i i w/requestapprova , I !N yY I i 5/1/951 91369 from AAI report submitted 2/26/99 /~,1 - I<RU ]2¥-:~2 .... ~[~-D -- ~95-049 i 10/20195 N/A i Ii1~ iN [I Ii 8/1/95i! 11100001 from AANever utilizedrep°rt submitted 2/26/99 · ' - ~T~-- 95~02110/20/95 N/A i tN IN I I 0 Neverufilized ' O! Never utilized ~,~ IKRU i2T-36 ~1 -I~RLI i2T-~'~ --- PT_D_ ~5-101 19/26/95 N/A A~I [K~U 12T:38 .... PTD 195-112 9/27/95 N/A , I IN IN ' I ~.~ - -IKR~I- I~V-I'~ - --- PT~ 197-008 NIA iY IN IN I I 0 contingent on data submission; cancelled permit AAI- KRU 2X-17 PTD ~95, -171 '4/16/96 N/A IN IY, iN, 1/17/96i 495 from AAI report submitted 2/26/99 AAI '-- KRU- 2X-{8- --- ~P~ [95-160 5/9/96 N/A , ~ iN ~ tN 1/17/961 25079 fromAA reportsubmtted2/26/99 ~.AI- - ~KR'~ ~,:~J .... |~'1:D~--95-175 3/22/96 N/A il~ i I I 01Neverutilized ~,AI KRU~ 2~_~2_~- ~i~-~I~D-- 1-94-14714/3/95 N/A ~, Y I 2/1/95 108071from AAI report submitted 2/26/99 AAI' KRU 3A-17 ISUN 196-132 10/29/96 8/30/96 I [Y I 12/16/96 13320 contingent on10-403, data in ~ell file; fmm AAI report submitted 2/26/99 .............. r. ..... 3 10/31/96 N/A I iY IN IN I i 01contingent on 10-403, top job to 550' AAI krU 3A-18 ' P~T~__j~-13 A~i - ~RU- ~fi-l~ iSU'-"N 196-102 8/7/96 6/25/96 I !Y IY iY I 10/29/961 153941c°ntingent°n10-403,datainvellfile;fr°mAAIrepodsubmittad2/26/99 i I I I i will request at completion of ddlling operations ' ~ ' 64731 contingent on 10-403, data in v. ell file; from AAI report submitted 2/26/99 ~,AI ,KRU-13~-2(~-~'-. ~A-I- ' ~I~-U 3F-21 /SUN 200-203 AAI- - IKRU 13~G-~3 ~-_~'_~_~0N~-- !96-122 8/29196 8/5/96 ! I IY iY Y i 11181981 ~,1~'~'1- -JKRUiK-R-U -1~-9Z~39-26 .... ISuN~Pl' P-T-D~ i 96'118199-07518/8/9818/19/99 !N/AN/A ! i! !!N tNi ' 10/28/96 0 !contingent on 10-403 w/CQL or LOT; took kick, suspended well.i ~ -,~l~l.j I:3H/:~ .... ~D_~ 96-015 5/9/96 I i N !Y IY . 27117 lfrom AN report submitted 2/26/99; also 30201 bbls into 2M-33 & t 5428 bbls into 3M-27 AAI- "~K_-Ru I3H-~ ..... _~.~--196-018 2/15/96 N/A I i N {N I I i 01p&a&s/tas3H-28A AA~- ' ~,~U- 3-H-28A ...... ~T~ - 96-037 5/8/96 N/A I i IN IN i I ! 01Never utilized ' . iY IN I I ! 01contingent on 10-403, did remedial cmt job, 43/4" wastes to 1C-11 ~,AI' KRu :~- 1-7 ..... IPT~ 96-146 12/21/96 Eld i i IY tN i I i 01 contingent on 10-403 w/CQL or LOT A~,I - - -~RU--]3J-18 ~TD 196-147 !12/14/96 :N/A Y ~1 ] ~Ru- -] 3-J--~ ~ [~U_N f96-148 i 11~2~96 110/3/9~ I I IY IY 1/14/971 21235 Ifrom AAI report submitted 2/26/99 15Al ' i KRU ~-I~-~ 9 -' - S0~ ~201-108 I I i t i , I I I plan to eventually request approval for annular disposal - info not submitted w/pta application PAl - k~U 3-~-~ 0--- l~- j201-088 '7/15/97 I i I N ! i ,i 0 i plansundrytO eventuallYappmval #request398-327,appmva112/21/98for annular disposal- info not submitted w/pta application AA~ .... KI~U- 1~3~-2-3 - ~-15~D- I97-097 12/21/98 I ! iY !N I I Sundry -~ - ' ..... ~-..-:~-- - -- I N I I i approval #399-040, 3/18199 ~A~ 1KRU 13K-24 iSUN [98-249 ~1/30/99 3/18/99 I ~ , ~,i -[~<rU ]~K~2~- ~-~UN ,I98-081 15/25/98 1/20/99 I i IN , IN i ! 43021Sundry approval # 399-001,1/20/99 total fm1999 Q1report, dated 419/99 ~, [~.~-~3~:2~-- r.T~---~7-077 7/22/97 N/A ' i iY ; IY I 4/9/99i 340701~mAA, reportsubm~tted2/2~/99,4/9/99 AAI- ~l~tJ 3~--- iP~ 197-046 5/8/97 N/A I " iY iY ! 7/18/971 37273iconlingentondatasabmittal, contactedAOGCCw' .... ded:fr .... port submitted 2/26/99 ~J~,l ' I KRLJ "31~--~0 .... ~--'97-113 '7/27/97 , i ' 'i 'i~ i ]not requested as of 6/8/01 /~Ai ..... I~-~U- ~.~'~ ...... ISUN ~-082 6/8/98 Eld i i Inotrequestedas°f6/8/01 ' ' I y i 8/7/97 i 33480 i confingent on data submittal - in veil file; from AAI report submitted 2/26/99 A~i ' /KI~U- '3-K-3~ ...... 1~----i97-076 5/29/97 ! iy yN ISundry approval #98-132, dated 5/28/98 AAI "-IKI~U ~-3~, .... ~_"~_---198-077 6/17/98 5/28/98 , N I A.~I- [KR~ ~-- IPTD/97-1097/21/97 N/A i i [1'~ IN I 0 inot requested as of 6/8/01 AAI KR-U i31~-- -' --~)~)5-21415/12/96 NIA I i YN i 10/29/961 154281from AAI report submitted 2/26/99 ~Ai ,KRU- 3M-29 .... I~T~T~-00515/3/96 N/A I , !N ~ i i 0!Neverufilized AAI t KRU 30-20 I PTD 97-04514/12/97 I N/A I I i Y Iy I 6/23/971 11905 Icontingent on data submittal - in veil file; from AAI report submitted 2/26/99 AAI [KRU 139-22 IPTD 195-18612/8/96 N/A i i IN YN ! 1/23/97i 63451from AAI reports submitted 2/26/99, 4/9/99 AAI ~KRU t3R-26 jPTD [95-187 12/4/96 N/A { i IN i i 01Neverutilized Pal IEXPL IAtla~#~ ...... I~U_N--- i20~1~4 i [ I i~ ' I !requestedw/ptd BPx II~BU- /~-33 ....... ~1~ 93-018 111/5/93 N/A I i iN Y 12/14/981 39741From BPXA Annular lnjection Data Entry Screen; from a-36 BPx "!PBU 1§-~6 ...... --~P'~1~--o65 16/4/96 NIA ! i iN ~/ ! i 0 Never utilized AAI IEXPL Ii~u-ffi~hea~-'i----~)- [95-063 i12/16/95 12/12/95 I 1 IN ! 9/5/96i 11148 Annular injection summer of1996, Approval by BEW AAi ' ICRU~IC-D~O~ ...... ~UN 199-04616/28/99 3/12/99 i i iN IN IN ly [ 5221 lfrom AA110/13/2000 report; auth. expired Page 3 TIcANSMITAL LETTER CHECK LIKI CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME CHECK 1 CHECK WHAT APPLIES STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR D/ISPOSAL ( ¥~)NO ANNULAR DISPOSAL ( } YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS ( .,,) YES+ SPACING EXCEPTION "CLUE'* The permit is for a new wellbore segment of existing well , Permit No, .~ APl No. . Production should continue to be reported as a function of the original AP1 number stated above. In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested... Annular Disposal of drilling wastes will not be approved... Annular Disposal of drilling Wastes will not be approved... Please note that an disposal of fluids generated... Enclosed is the approved application for permit to drill the above referenced well. The Permit is approved' subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates WELL PERMIT CHECKLIST FIELD & POOL COMPANY ,/2/, ~/, ~ ~. WELL NAME ~_~'~-/? INiT CLASS/ .x"~,' ,/~<¢,,-? ' ' ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs...' ........ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to '%~.~ ~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable.. ; .............. GEOLOGY 30. Permit can be issued w/o hydroge~ sulfide measures ..... Y N / PROGRAM: exp dev ,,,~ redrll serv Gl [,~L AREA ~? _r-.) UNIT# wellbore seg ann. disposal para req ON/OFF SHORE 31. Data presented on potential overpressure zones ....... Y N// 32. Seismic analysis of shallow gas zones .......... . . . Y/4~I /:¢'¢~/'-7 · ~.~,/~A ,T~_~ 33. Seabed condition survey (if off-shore).... ......... /'Y N . ,~R /' 34. Contact name/phone for Weekly progress reports [exploratory one] Y _N , ' · ,-/ -////"'. · ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well'used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAc 25.252 or 20 AAC 25.412. Y N 31<:.-. Pao- - i~,m GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ' WM Comments/Instructions: I§ Z .--i -I- c:\msoffice\wordian\diana\checklist (rev. 11/01fl00) 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 o! the file under APPENDIXi .. No 'special'effort has been made to chronologically organize this category of information. 3k-19.tapx Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Dec 27 16:09:55 2001 Reel Header Service name ............. LISTPE Date ..................... 01/12/27 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/12/27 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Cormment Record TAPE HEADER Kuparuk MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-II106 M. HANIK R. BOWIE 3K-19 500292302200 Phillips Alaska, Inc. Sperry Sun 26-DEC-01 MWD RUN 2 MWD RUN 3 AK-MM-Ii106 AK-MM-ii106 M. HANIK R. MCNEILL R. BOWIE R. BOWIE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION {FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 4 AK-MM-ii106 A. WEAVER D. HEIM MWD RUN 99 AK-MM-Ii106 R. MCNEILL R. BOWIE 35 13N 9E 1447 319 64.10 64.10 34.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 190.0 6.750 7.625 6656.0 iST STRING 2ND STRING 3RD STRING PRODUCTION STRING Page 1 RECEIVED 2 8 2001 Alaska Oit & Gas Co~s. CommJssior~ REMARKS: 3k-19.tapx 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4).DATA IN THE INTERVAL 300'MD 300'TVD TO 1029'MD, 1020'TVD WERE ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS PERFORMED WHILE RUNNING IN THE HOLE FOR MWD RUN 2. THIS DATA IS PRESENTED FILLS IN AN UNLOGGED INTERVAL AND IS PRESENTED IN THE MERGED DATA SETS. 3. PDC STATUS OF MWD DATA IS PENDING. 4. VERTICAL RESISTIVITY INVERSION (VRI) DATA IS PRESENTED AS A DEEP PHASE ENHANCED (RDVR) CURVE IN MWD MERGED DATA, AND AS 4 ENHANCED CURVES AND 4 MODELED CURVES IN THE FINAL RAW MWD FILE (MWD 099). 5. MWD RUNS 1-3 REPRESENT WELL 3K-19 WITH API#: 50-029-23022-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12340'MD, 6884'TVD. SROP = SGRC = SEXP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SMOOTHED GAMMA RAY COMBINED. SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. RDVR = INVERSION-DERIVED DEEP PHASE RESISTIVITY (ENHANCED). MEXP = FORWARD-MODELED EXTRA SHALLOW PHASE RESISTIVITY. MESP = FORWARD-MODELED SHALLOW PHASE RESISTIVITY. MEMP = FORWARD-MODELED MEDIUM PHASE RESISTIVITY. MEDP = FORWARD-MODELED DEEP PHASE RESISTIVITY. VEXP = INVERSION-DERIVED EXTRA SHALLOW PHASE RESISTIVITY (ENHANCED). VESP = INVERSION-DERIVED SHALLOW PHASE RESISTIVITY (ENHANCED). VEMP = INVERSION-DERIVED MEDIUM PHASE RESISTIVITY (ENHANCED). VEDP = INVERSION-DERIVED DEEP PHASE RESISTIVITY (ENHANCED). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Page 2 3k-19.tapx Date of Generation ....... 01/12/27 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 ROP FET RPD RPM RPS RPX GR RDVR $ START DEPTH 180.0 180 0 180 0 180 0 180 0 180 0 180 0 4775.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: STOP DEPTH 12342.0 12306.0 12306.0 12306.0 12306.0 12306.0 12297.5 6025.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 180.0 300.0 2 300.0 3002.0 3 3002.0 6666.0 4 6666.0 12340.0 99 4775.0 6025.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 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 MWD FT/H 4 1 68 4 2 GR 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 1 68 28 8 RDVR MWD OHMM 4 1 68 32 9 Name Service Unit Min Max DEPT FT 180 12342 ROP MWD FT/H 0 1891.84 GR MWD API 8.59 517.69 RPX MWD OHMM 0.32 309.71 RPS MWD OHMM 0.13 2000 First Mean Nsam Reading 6261 24325 180 150.913 24195 180 95.2339 24236 180 11.1327 24201 180 15.5123 24201 180 Page 3 Last Reading 12342 12342 12297.5 12306 12306 RPM MWD OHMM 0.06 2000 RPD MWD OHMM 0.02 2000 FET MWD HOUR 0.12 135.26 RDVR MWD OHF~4 1.066 212.799 First Reading For Entire File .......... 180 Last Reading For Entire File ........... 12342 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 3k-19.tapx 28.1887 24201 36.7886 24201 2.34664 24253 10.0043 2501 180 180 180 4775 12306 12306 12306 6025 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 180.0 255 5 ROP 180 0 299 5 GR 180 0 260 0 RPS 180 0 255 5 RPD 180 0 255 5 FET 180 0 255 5 RPX 180 0 255 5 $ LOG HEADER DATA DATE LOGGED: 23-JUN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 300.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .3 MAXIMUM ANGLE: 4.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02036HWRG6 PB02036HWRG6 EWR4 $ ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 190.0 Page 4 3k-19.tapx BOREHOLE CONDITIONS MUD TYPE: Spud MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 180.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 1400 FLUID LOSS (C3) : 10.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.750 MUD AT MAX CIRCULATING TERMPERATURE: 2.170 MUD FILTRATE AT MT: 3.400 MUD CAKE AT MT: 3.450 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD010 FT/H 4 1 68 GR MWD010 API 4 1 68 RPX MWD010 OHMM 4 1 68 RPS MWD010 OHMM 4 1 68 RPM MWD010 OHMM 4 1 68 RPD MWD010 OHMM 4 1 68 FET MWD010 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 68.0 88.0 68.0 68.0 Name Service Unit DEPT FT ROP MWD010 FT/H GR MWD010 API RPX MWD010 OHMM RPS MWD010 OHMM RPM MWD010 OHMM RPD MWD010 OHMM FET MWD010 HOUR Min 180 6 97 21 32 1 45 1 85 2 71 3 O4 0 46 Max 299.5 585.59 54.84 19.91 35.74 2000 2000 1.81 First Reading For Entire File .......... 180 Last Reading For Entire File ........... 299.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Mean Nsam Reading 239.75 240 180 173.551 240 180 35.6576 161 180 8.54724 152 180 12.4695 152 180 47.2376 152 180 199.352 152 180 1.45678 152 180 Page 5 Last Reading 299.5 299.5 260 255.5 255.5 255.5 255.5 255.5 3k-19.tapx Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 230.0 2956 0 RPM 256 0 2956 0 RPS 256 0 2956 0 RPD 256 0 2956 0 FET 256 0 2956 0 GR 260 5 2961 0 ROP 300 0 3001 5 $ # LOG HEADER DATA DATE LOGGED: 26-JUN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3001.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 18.7 MAXIMUM ANGLE: 50.3 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02036HWRG6 EWR4 ELECTROMAG. RESIS. 4 PB02036HWRG6 $ # 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): 161.0 MUD PH: 9.8 MUD CHLORIDES (PPM): 900 FLUID LOSS (C3): 11.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.700 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.099 92.0 MUD FILTRATE AT MT: 3.300 70.0 MUD CAKE AT MT: 3.400 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): Page 6 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 3k-19.tapx Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 R?D MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR Min 230 0 8 59 1 05 1 05 0 97 0 68 0 13 Max 3001.5 1891.84 130.65 143.84 1795.14 2000 2000 38.59 Mean 1615.75 198.376 62.1996 25.0707 40.7701 85.5565 109.261 5.47154 First Reading For Entire File .......... 230 Last Reading For Entire File ........... 3001.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Nur~ber ........... 1.0.0 Date of Generation ....... 01/12/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Nsam 5544 5404 5402 5453 5401 5401 5401 5401 First Reading 230 30O 260.5 230 256 256 256 256 Last Reading 3001.5 3001.5 2961 2956 2956 2956 2956 2956 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/27 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 Page 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: START DEPTH 2956.5 2956.5 2956.5 2956.5 2956.5 2961.5 3002.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): STOP DEPTH 6619.5 6619.5 6619.5 6619.5 6619.5 6623.5 6666.0 3k-19.tapx 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 29-JUN-01 Insite 66.16 Memory 6664.0 9.0 68.7 TOOL NUMBER PB02036HWRG6 PB02036HWRG6 9.875 Spud 9.30 93.0 8.7 6OO 5.8 Name Service order Units Size Nsam Rep Code Offset Channel Page 8 2.700 72.0 1.837 109.0 6.100 72.0 2.600 72.0 DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMS4 4 1 68 FET MWD030 HOUR 4 1 68 3k-19.tapx 0 4 8 12 16 20 24 28 Name Service Unit Min Max DE?T FT 2956.5 6666 ROP MWD030 FT/H 0 596.51 GR MWD030 API 25.16 131.09 RPX MWD030 OHMM 1.25 250.06 RPS MWD030 OHMM 1.16 2000 RPM MWD030 OHMM 0.9 2000 RPD MWD030 OHMM 1.01 2000 FET MWD030 HOUR 0.12 15.05 First Reading For Entire File .......... 2956.5 Last Reading For Entire File ........... 6666 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Mean 4811.25 159.6 81.0148 12.5265 15.3771 20.8649 25.6523 0.921029 Nsam 7420 7329 7325 7327 7327 7327 7327 7327 First Reading 2956.5 3002 2961.5 2956.5 2956.5 2956.5 2956.5 2956.5 Last Reading 6666 6666 6623.5 6619.5 6619.5 6619.5 6619.5 6619.5 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/27 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 FET GR RPX RPS RPD RPM ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): START DEPTH STOP DEPTH 6620.0 12306.0 6624.0 12297.5 6646.0 12306.0 6646.0 12306.0 6646.0 12306.0 6646.0 12306.0 6666.5 12342.0 09-JUL-01 Insite 66.16 Memory Page 9 TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 3k-19.tapx 12340.0 27.0 67.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01993HAGR4 EWR4 ELECTROMAG. RESIS. 4 PB01993HAGR4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.750 6656.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 60.0 MUD PH: .1 MUD CHLORIDES (PPM): 350 FLUID LOSS (C3) : 2.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3.450 MUD AT MAX CIRCULATING TERMPERATURE: 1.741 MUD FILTRATE AT MT: 4.500 MUD CAKE AT MT: 3.000 70.0 145.4 70.0 70.0 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 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 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 MWD040 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 6620 12342 ROP MWD040 FT/H 0 539.55 GR MWD040 API 37.32 517.69 RPX MWD040 OHMM 0.32 309.71 RPS MWD040 OHMM 0.13 509.22 RPM MWD040 OHMM 0.06 2000 First Mean Nsam Reading 9481 11445 6620 121.9 11222 6666.5 120.983 11348 6624 3.54244 11321 6646 3.59061 11321 6646 5.30413 11321 6646 Page 10 Last Reading 12342 12342 12297.5 12306 12306 12306 RPD MWD040 OHMM 0.02 2000 FET MWD040 HOUR 0.12 135.26 First Reading For Entire File .......... 6620 Last Reading For Entire File ........... 12342 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 3k-19.tapx 7.23843 11321 1.79297 11373 6646 6620 12306 12306 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Nunlber ........... 1.0.0 Date of Generation ....... 01/12/27 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: 99 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH VEDP 4775.0 6025.0 VEMP 4775 0 6025 0 VESP 4775 0 6025 0 VEXP 4775 0 6025 0 MEDP 4775 0 6025 0 MEMP 4775 0 6025 0 MESP 4775 0 6025 0 MEXP 4775 0 6025 0 $ LOG HEADER DATA DATE LOGGED: 29-JUN-01 SOFTWARE SURFACE SOFTWARE VERSION: VRI DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Processed TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: Page 11 MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ 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 3k-19.tapx Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 MEXP MWD099 OHMM 4 1 68 4 2 MESP MWD099 OHMM 4 1 68 8 3 MEMP MWD099 OHMM 4 1 68 12 4 MEDP MWD099 OHMM 4 1 68 16 5 VEXP MWD099 OHMM 4 1 68 20 6 VESP MWD099 OHMM 4 1 68 24 7 VEMP MWD099 OHMM 4 1 68 28 8 VEDP MWD099 OHMM 4 1 68 32 9 Name Service Unit Min DEPT FT 4775 MEXP MWD099 OHMM 1.737 MESP MWD099 OHMM 1.782 MEMP MWD099 OHMM 1.647 MEDP MWD099 OHMM 2.271 VEXP MWD099 OHMM 1.15 VESP MWD099 OHMM 1.104 VEMP MWD099 OHMM 0.822 VEDP MWD099 OHMM 1.066 Max 6025 85 684 78 902 77 204 70 209 156 739 183 719 189 161 212 799 First Reading For Entire File .......... 4775 Last Reading For Entire File ........... 6025 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Mean 5400 7.94247 8.167 8.55386 9.02042 8.42086 8.71555 9.19365 10.0043 Nsam 2501 2501 2501 2501 2501 2501 2501 2501 2501 First Reading 4775 4775 4775 4775 4775 4775 4775 4775 4775 Last Reading 6025 6025 6025 6025 6025 6025 6025 6025 6025 Page 12 3k-19.tapx Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/12/27 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 01/12/27 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 13