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200-173
Originated: Delivered to:9ͲOctͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#11AͲ08 50Ͳ029Ͳ20313Ͳ00 909572342 Kuparuk River Leak Detect Log with ACXField & Processed 13ͲSepͲ24 0 121BͲ20 50Ͳ029Ͳ23164Ͳ00 909462416 Kuparuk River Multi Finger CaliperField & Processed 15ͲAugͲ24 0 131CͲ24 50Ͳ029Ͳ23063Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 25ͲAugͲ24 0 141CͲ24 50Ͳ029Ͳ23063Ͳ00 n/a Kuparuk River Multi Finger CaliperField & Processed 25ͲAugͲ24 0 151CͲ24 50Ͳ029Ͳ23063Ͳ00 ALSL764Ͳ002 Kuparuk River Packer Setting Record FieldͲFinal 15ͲSepͲ24 0 161DͲ32 50Ͳ029Ͳ22982Ͳ00 909582494 Kuparuk River Multi Finger CaliperField & Processed 6ͲSepͲ24 0 171EͲ29 50Ͳ029Ͳ20828Ͳ00 909524908 Kuparuk River Leak Detect Log FieldͲFinal 8ͲSepͲ24 0 181EͲ29 50Ͳ029Ͳ20828Ͳ00 909524908 Kuparuk River Packer Setting Record FieldͲFinal 7ͲSepͲ24 0 191HͲ01 50Ͳ029Ͳ22330Ͳ00 909524903 Kuparuk River Multi Finger CaliperField & Processed 29ͲAugͲ24 0 110 1HͲ01 50Ͳ029Ͳ22330Ͳ00 909593144 Kuparuk River Plug Setting Record FieldͲFinal 23ͲSepͲ24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39678T39679T39680T39680T39680T39681T39682T39682T39683T39683178-040203-115201-248200-173182-154193-00610/21/2024Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.10.21 10:33:37 -08'00'1DͲ3250Ͳ029Ͳ22982Ͳ00 909582494KuparukRiverMultiFingerCaliperField&Processed6ͲSepͲ2401T39681201 248200-173182 154 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 22, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-32 KUPARUK RIV UNIT 1D-32 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 1D-32 50-029-22982-00-00 200-173-0 W SPT 6276 2001730 1569 1625 1625 1625 1625 340 550 540 540 4YRTST P Guy Cook 7/10/2022 Testing completed with a Little Red Services pump truck and calibrated gauges. 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 1D-32 Inspection Date: Tubing OA Packer Depth 620 2400 2350 2340IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220709074109 BBL Pumped:2.1 BBL Returned:2.2 Friday, July 22, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.07.22 16:26:40 -08'00' o_\�t3 • • WELL LOG TRANSMITTAL DATA LOGGED %/14/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. July 15, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (A V ' u x 3 2vi' Resubmit E-Set#25965 RE: Multi Finger Caliper(MFC) 1D-32 Run Date: 6/6/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1D-32 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22982-00 SCANTED .SEp d 3.206 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE 'TRANSMITTAL LEITER TO THE A'T1'ENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 1)/).,4/24.4.5„.4) • 2o0- x`73 11) 259G5 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 17, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 RECEIVEDiq i2°�S .vi.K.BENDER JUN 19 201L RE: Multi Finger Caliper(MFC): 1D-32 Run Date: 6/6/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1D-32 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22982-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. ED Anchorage, Alaska 99518 iCAtitt Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: pe)...40-ft...4) 6 Imag( 'roject Well History File Cover~· ]e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. & 00 - L -V Well History File Identifier Organizing (done) R~CAN \f Color items: ,I Two-Sided o Grayscale items: DIGITAL DATA .,I" Diskettes, No. d.- o Other, NofType o Poor Quality Originals: o Other: NOTES: BY: BEVERLY ROBIN VINCENT SHERYk_ ~WINDY "' Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL@WINDY Scanning Preparation ,,~x30= qó BY: BEVERLY ROBIN VINCENT SHERY~INDY .¡ Rescan Needed OVERSIZED (Scannable) o Maps: o Other items scannable by large scanner OVERSIZED (Non-Scannable) o Logs of various kinds o Other DATE: to . ð 'D3f1 ~ , ¡' DATE:b ð D3/s1 I mP + t I = TOTAL PAGES I' 0 DATE b/3 ~ Isl VI1 P Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ) /0 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION:. Y YES _ NO BY: BEVERL~ VINCENT SHERYL MARIA WINDY DATE:0-¡;:é23/\~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: _ YES _ NO BY: BEVERL~ VINCENT SHERYL MARIA WINDY DATE:b....I.3-cB/~b (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (ìm!llfidual piJge IS¡)0(.:il~f /!Itt¿l1firmj .fi,ca¡¡níng comp!m:ød) RESCANNED B'o/: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: Isl Quality Checked (don~') 12/1 O/02Rev3NOTScanned. wpd MEMORANDUM • TO: Jim Regg P.I. Supervisor ' ~ ~(~~ ~~ v FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 D-32 KUPARUK RIV UNIT 1D-32 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv-~L Comm Well Name: KUPARUK RIV UNIT 1D-32 Insp Num: mitRCN100718154221 Rel Insp Num: API Well Number: 50-029-22982-00-00 Permit Number: 200-173-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ID-sz Type Inj. N ' TVD 6276 ~ IA 517 1900 ~ 1865 1860 P.T 2001730 TypeTeSt SPT I TCSt pSl 1900 ~ OA 10 14 14 14 Interval 4YRTST p~ P ~ Tubing 1010 1025 1025 1025 Notes: A~tlr1 ~~~ ~~' 15(cz (~,; < ~, ti- a~. .. Thursday, July 22, 2010 Page 1 of 1 . . ConocJPhillips Alaska RECEIVED AUG 1 3 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 9, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 aôo - \1"3 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibiter, RG2401, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped August 8, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, ~- ConocoPhillips Well Integrity Projects Supervisor ~ SCANNED AUG 1 4lQ07 . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/9/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl Well Name PTO# cement DumDed cement date inhibitor sealant date ft bbls ft Qal 1 0-32 200-173 10" nla nla nla 6.8 8/8/2007 1 0-36 200-130 20" nla nla nla 4.2 8/8/2007 10-37 200-204 20" nla nla nla 4.2 8/812007 1 0-38 200-077 24" nla nla nla 4.2 8/8/2007 1 0-39 200-216 27" nla nla nla 7.6 8/8/2007 1 0-40 200-190 13" nla nla nla 3.4 8/8/2007 10-41 205-188 12" nla nla nla 1.7 8/8/2007 1 0-42 200-164 16" nla nla nla 3.4 8/8/2007 10-131 198-110 6" nla nla nla 2 8/8/2007 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 'v'~ I'-"ë/J/j , / '-/ 3/()'~ DATE: Monday, July 31, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS l\LASKA fNC 10-32 KUPARUK RIV UNIT 10-32 O/\1~ ~O FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv:J5.iZ- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 10-32 Insp Num: mitJCr060730063359 Rei Insp N urn API Well Number 50-029-22982-00-00 Permit Number: 200-173-0 Inspector Name: John Crisp Inspection Date: 7/29/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 10-32 iType Inj. i N I TVD i 6276 IA 400 1870 1840 1830 I ._-t . ~.~_.._.l i --·-r--· P.T. 2001730 iTypeTest I SPT ! Test psi 1569 OA 200 I 230 230 230 ...L......:__._. --~_._--- V / Tubing i 600 590 590 590 Interval 4YRTST PfF P I Notes 1.8 bbl's pumped for test <"'-' ",I,. .r:::r- \... w-i\, '( . 'ik;.:...i G 0 Monday, July 31,2006 Page 1 of 1 Re: FW: Kuparuk ID-32 Leak Detect Log e e Hi Steve, The paper copy will make it over, but if you can send the electrons that would be appreciated. Tom Mukavitz, Steve J wrote, On 4/13/2006 9:56 AM: Tom, Quite a few of us over here got involved with this one, looks like I was the last. We worked over 1 D-32 in November, 2005 to replace tubing prior to conversion to water injection following a coil tubing side track. Sundry numbers for the workover were 305-298 (1 D-32) and 305-303 (1 D-32L 1). Sharon submitted the 10-404's a few month's back. A caliper log from October, 2004 prior to the sidetrack showed a hole in the 3.5" liner at 13,619' and possibly 3 more holes below this. We ran a leak detection log on April 5, 2006, and per the note below, did not find any fluid leaking from the 3-1/2" liner. Do you need a copy of this log or will you get one through normal channels? I have an electronic copy and can send you one, or get a paper copy if you'd like. Just wanted to give you a heads up. Regards, Steve Mukavitz ConocoPhillips Alaska, Inc. Drilling and Wells Group 907-263-4021 ~jCh~f\~r¿J } 6\ t· -----Original Message----- From: Gober, Howard Sent: Thursday, April 06, 20064:01 PM To: Mukavitz, Steve J Subject: FW: 10-32 LDL Steve, I think you handled this one. Do you know what we promised the state? Do we need to send them a copy of the log? Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907 -263-4220 Office lof2 4/13/2006 10:30 AM Re: FW: Kuparuk ID-32 Leak Detect Log e e 907-240-5515 Cell Howard. Gober@2conocophillips.com -----Original Message----- From: NSK Problem Well Supv Sent: Thursday, April 06, 2006 1:50 PM To: Gober, Howard Subject: FW: 10-32 LDL Howard Do we need to send this to the state? I think I remember that you were the original contact... Please advise MJ -----Orígínal Message----- From: Reilly, Evan M Sent: Thursday, April 06, 20068:23 AM To: CPF1 Prod Engr; NSK Problem Well Supv Subject: 10-32 LDL Please find the log for 10-32 Leak Detection attached to this message. Here's the 24-hour Summary: PERFORM LEAK DETECT LOG WITH WELL ON WATER INJECTION AT 4326 BPD, 2300 PSI WHIP. LOGGED INTERVAL BETWEEN PACKER AND LINER TOP (13,130-13,750 FT) WHILE ON INJECTION AND ONE & THREE-HOUR WARMBACK PASSES AFTER SHUTTING IN . **** NO INDICATION OF LEAKS ****. BOTTOM NOT TAGGED. Evan Reilly Wells Group Cell: (907) 943-1246 Direct: (907) 659-7728 20f2 4/13/2006 10:30 AM Schlumberger NO. 3691 Schfumberger -DCS 2525 Gambell Street, Suite Anchorage, AK 99503-2838 ATTN: Beth ·"~'H,_ } .~~. Company: Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 FEB 22. 2006 v".. ,",vit". ....VIIìIlH:iS¡O\¡ .A.ncrorege Field: Kuparuk Well Color CD Job # Log Description Date BL 1B-17 1'14-045" 11216283 SBHP SURVEY 02/18/06 1 1 E-36 198-.;1t.~ 11216282 SBHP SURVEY 02/18/06 1 3H-07 /B7-07'/ 11217023 LDL 02/11/06 1 3H-07 II ,f, 11166757 STATIC SURVEY 01/20/06 1 2A-09 /ßfo-rnJ 11154126 PRODUCTION PROFILE 02/09/06 1 1A-10 /8/- /úO 11213710 INJECTION PROFILE 02/08/06 1 2M-14 1'1.;)- ()/f):2, 11154127 INJECTION PROFILE 02/10/06 1 1E-05 /Çý)-()5P' 11166747 PRODUCTION PROFILE W/DEFT 12/25/05 1 2H-12 /Pl5-.:)0'J.. 11154128 PRODUCTION PROFILE WIDEFT 02/11/06 1 1C-21 11154131 PRODUCTION PROFILE W/DEFT/GHOST 02/14/06 1 3G-18/q()-/;)¿;;- 11154129 PRODUCTION PROFILE W/DEFT 02/12/06 1 1 E-119 11217025 INJECTION PROFILE 02/13/06 1 2U-13 184-;Jf{p 11166753 PRODUCTION PROFILE 01/14/06 1 1Y-09 /83-~ 11213128 INJECTION PROFILE 02/06/06 1 1 E-1 05 11162832 MEMORY INJECTION PROFILE 01/28/06 1 2C-08 /B':2,-oq~ 11141255 INJECTION PROFILE 01/28/06 1 2C-02 /R7¡-dl3 11213129 INJECTION PROFILE 02/07/06 1 1C-25 IQQ-03/ 11144074 GLS 02/02/06 1 2C-14 1134 - dID 11166759 PRODUCTION PROFILE 01/25/06 1 2C-10 /13-1-:)1+ 11144067 PRODUCTION PROFILE 01/26/06 1 1A-18 ICJo- 5.~ 11144070 PRODUCTION PROFILE 01/29/06 1 2C-01 /8!;-()ß?¡ 11213709 INJECTION PROFILE 02/07/06 1 1 D-32 t)()()-J 1A 11141252 LEAK DETECTION LOG 01/25/06 1 2C-12 IB4-~ 11141260 PRODUCTION PROFILE 02/02/06 1 2C-15 184 - ~6~ 11141254 PRODUCTION PROFILE 01/27/06 1 1 J -1 54 NIA PRODUCTION LOG WITRACTOR 02/05/06 1 1 E-1 04 11217024 INJECTION PROFILE 02/12/06 1 02/21/06 e e Please sign and return one copy of this transmittal to Beth at the above address or fax to·(907) 561-8317. Thank you. .~~ MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg .~, Z(I1(C(, P.I. Supervisor Ñ'{1 DATE: Monday, February 06, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 10-32 KUPARUK RIV UNIT 10-32 Src: Inspector ~ùoJn3 Reviewed By: ---:.,0 a P.I. Suprv~ Comm FROM: Lou Grimaldi Petroleum Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 10-32 API Well Number 50-029-22982-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG060205110435 Permit Number: 200-173-0 Inspection Date: 2/5/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 10-32 !Type Inj. ! W I TVD 6276 ! IA 860 1800 1780 1780 I I P T I 2001730 TypeTest ¡ SPT ¡ Test psi 1569 I OA 740 840 830 830 ì ~~ Interval INITAL P/F P Tubing 1960 1960 1965 1965 I ~------ Notes Initial Post-startup test. Passed, no problems. Monday, February 06, 2006 Page I of I ) ) John Peirce Engineering Technician Drilling & Wells ConocóP'hiIIi ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6471 January 12, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED JAN 1 7 2006 Alaska Oil & Gas Cons. Commission Anchorage Subject: Report of Sundry Well Operations for 1 D-32 /1 D-32L 1 Dear Commissioner: JOO" 113 ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 1 D-32 I 1 D-32L 1. If you have any questions regarding this matter, please contact me at 265-6471. Sincerely, Ii tg.r./ --.-.....) - ,.) / / ,-----"-;:::: . " ,'tf .(;,~. ...ot._ 2-_.___ ? > r- __. ... ,Il--~..--==:::..-=:::. // J. Péirce I Engineering Technician CPAI Drilling and Wells - hIìoUb,\\lIt"':P""j H\ N .~ 8 '¿OGG ~L.",~,,,,,r,·~'~11 ' \,H-\ ' ..,. ~ JWP Iskad ) RECEIVED ') JAN 1 7 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. COfTITIission REPORT OF SUNDRY WELL OPERATIONS Anchorage D Time Extension D Re-enter Suspended Well D 1. Operations Performed: Abandon D Alter Casing D Repair Well 0 Pull Tubing 0 Operat. ShutdownD Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development D Stratigraphic D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 34' 8. Property Designation: ADL 28248 1 25650, ALK 591 11. Present Well Condition Summary: Total Depth measured 14138' feet true vertical 6679' feet Effective Depth measured 13761 ' feet true vertical 6512' feet Casing Length Size MD Structural CONDUCTOR 117' 20" 117' SURF CASING 8902' 9-5/8" 9006' PROD CASING 13220' 7" 13324' LINER 953' 3-1/2" 14136' WINDOW TO L 1 10' 3-1/2" 13836' Perforation depth: Measured depth: 13814'-13824',13870'-13880',13904'-13944' true vertical depth: 6535'-6540', 6559'-6564', 6574'-6592' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 13255' MD. Packers & SSSV (type & measured depth) Baker 5x7" ZXP liner pkr @ 13190' Landing Nipple @ 501' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Stimulate D Waiver D Other Exploratory D o 5. Permit to Drill Number: 200-173 1 305-298 6. API Number: 50-029-22982-00 Service 9. Well Name and Number: 1 0-32 10, Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 117' 4577' 6330' 6679' 6541' RBDMS 8Ft" JAN 1 '1 2006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation SI Subsequent to operation SI 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAGD GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Printed Name Signature John Peirce @ 265-6471 John Peirce ~. ~.~~:~~~ /' -..- .£--.-" fOJíR1,IG'INÀt Title Phone Wells Group Tech. Z6S -c:'47/ Date I-I Z '-()(Ó Prepared bv Sharon Allsup-Drake 263-4612 Form 10-404 Revised 04/2004 Submit Original Only ) ) 2.00 MOVE DMOB MOVE Prep to move off 1 D-39. 4.00 MOVE MOVE MOVE PEAK trucks on loc. to assist with move. Begin moving rig modslspotting up on 1 D-32. Lay rig mats I herculite. 6.50 MOVE MOVE MOVE Backing rig mods over well and rigging up 2.50 MOVE MOVE MOVE Stand up derrick and secure. State witness of upcoming BOPE test waived by John Spaulding in previous conversation 11/22/05. 3.00 WELCTL NUND DECOMP Except rig @ 15:00 hrs on 11/23/05, start ND well head. OA=330 psi, IA = 0 psi, Tubing = 0 psi. Pictures of tree alignment in well folder. 0.50 WELCTL NUND DECOMP NU BOP stack 1.50 WELCTL EQRP DECOMP Tree ND; BPV is leaking (spout of fluid coming through BPV I blanking plug). Remove blanking plug, troubleshoot BPV; fluid leaking past poppet. FMC Rep on location, ensure BPV is set and poppet is seated. Leaking has stopped; discuss and cont. with NU of stack. NOTE: This time (1.5 hrs) REMOVED from BOPE testing time due to complications with BPV, etc. (delays incurred at no fault of NABORS equipment I personnel). Continue NU of BOPE. Continue to NU BOPE. Begin testing of BOPE, 250/3000 psi. RU landing joint pull old completion free with 11 OK up wt. string wt is 82K, pull hanger to the floor circulate bottoms up 350 bbls Circulate bottoms up 350 bbls 9.6 brine taking returns to pits. Rig up and pump kill down the OA 100 bbls 9.6 ppg 2 bpm @ 1740 psi, monitor OA pressure. POOH with old completion laying down sideways Tower meeting pad is very congested with other well work. Continue to POOH with old completion Continue pulling old completion, laying down pipe, Rig 1" hose from OA to kill tanks and bleed off annulus from 850 psi. Fluid at surface, bled to o psi (bled approx. 2 bbls). Shut back in and monitor. OA=200 psi. Bleed off again to 70 psi, shut back in to monitor. Continue to pull out of hole with old completion. Tower meeting Continue to pull out of hole with old completion Continue to pull out of hole with old completion OA bled down to 20 psi monitor Pull and change 9 5/8" x 7" pack-offs. Pack-offs tested to 5000 psi held Load Pipe shed with remainder of new completion 165 jts. strap and drift. Pipe tally is complete. Prep to run new 3-1/2" completion. Finished freeze protecting OA with 100 bbls diesel. Pumped 2 bpm @ 1750 psi Begin running new completion. Tower meeting, continued. Running in the hole with new 3.5" completion. Tower meeting, run in the hole. With 419 joints of 3.5 L-80 8rd tubing, 6 Pup joints 4 from Camco, 1 from Baker, l' on Hanger and one to space out, 1 New GLM with 1" Dummy Valve and 1 new DS nipples from Camco, 1 Baker CMU sliding Sleeve in the closed position, 1 New seal assembly from Baker, New well head, and Hanger. 70K up wt and 31 K down wt prior to landing tubing, space out with 2.05' pup one full joint and hanger with pup. Pull out of seals to circulate inhibited brine into the IA. 4.50 CMPL TN CIRC CMPL TN Load 220 bbls brine on vac truck with Inhibitor and circulate inhibited 9.6 Brine down tubing up lA, top of inhibitor @ 5000' RKB in lA, 4.5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-32 1 0-32 WORKOVER/RECOMP Nabors 3S .·paté: From..; To Hours CodE! ðo~e Phasé 11/23/2005 00:00 - 02:00 02:00 - 06:00 06:00 - 12:30 12:30 - 15:00 15:00 - 18:00 18:00 - 18:30 18:30 - 20:00 20:00 - 00:00 4.00 WELCTL NUND DECOMP 11/24/2005 00:00 - 02:00 2.00 WELCTL NUND DECOMP 02:00 - 06:00 4.00 WELCTL BOPE DECOMP 06:00 - 08:30 2.50 FISH PULL DECOMP 08:30 - 10:30 2.00 WELCTL CIRC DECOMP 10:30 - 18:00 7.50 WELLSR PULD DECOMP 18:00 - 00:00 6.00 WELLSR PULD DECOMP 11/25/2005 00:00 - 03:00 3.00 WELLSR PULD DECOMP 03:00 - 04:00 1.00 WELLSR PULD DECOMP 04:00 - 06:00 2.00 WELLSR PULD DECOMP 06:00 - 08:00 2.00 WELLSR PULD DECOMP 08:00 - 11 :30 3.50 WELLSR PLGM DECOMP 11:30-19:00 7.50 WELLSR PULD CMPL TN 19:00 - 20:30 1.50 CMPL TN RUNT CMPL TN 20:30 - 00:00 3.50 CMPL TNI RUNT CMPL TN 11/26/2005 00:00 - 06:00 6.00 CMPL TNi RUNT CMPL TN I I I i 06:00 - 13:00 I 7.00, CMPL TN; RUNT CMPL TN ·13:00 - 17:30 Start: 11/23/2005 Rig Release: 11/27/2005 Rig Number: Spud Date: 11/9/2000 End: 11/27/2005 Group: Printed: 1/6/2006 10: 11: 12 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/26/2005 13:00 - 17:30 17:30 - 18:30 18:30 - 21 :00 21 :00 - 22:30 22:30 - 00:00 11/27/2005 00:00 - 06:00 06:00 - 11 :00 11 :00 - 1 0-32 1 0-32 WORKOVER/RECOMP Start: 11/23/2005 Rig Release: 11/27/2005 Rig Number: Spud Date: 11/9/2000 End: 11/27/2005 Group: Nabors 3S . ... .. ... Sub· HÖursCodê Côde 4.50 CMPL TN CIRC CMPL TN bpm @ 460 psi 1.00 CMPL TN SOHO CMPL TN Discrepancy on numbers used for Nabors 3S RKB during spaceout. Appears to be 4' off. Pull back out of hole and break out 2' spaceout pup and replace with 6' 2.50 CMPL TN SOHO CMPL TN Make up completion/hanger and attempt to land. Tag up 5' high. Make up head pin and kick in charge pump while stroking seals into SBE; see pressure increase. Continue RIH, stack out approx. 5' high using pressure spike as seals entered SBE as guide. 1.50 CMPL TN SOHO CMPL TN Discuss options with Baker Rep and Baker Ops Supvr. Pull space-out pup out of completion. RBIH while circulating, see press increase as seals enter SBE. Travel in hole 10.5' further and land. Set depth places bottom of seal assembly at 13,250' RKB. Call WIO Engineer to discuss. Note: Should have seen 16' of stroke once seals were seen entering SBE rather than 10.5'; tubing landed 5' high. 1.50 CMPL TN DEQT CMPL TN Open IA casing valve. Pressure test tubing to 2500 psi; hold for 30 mins and chart (good test). Bleed off tubing to 1500 psi, pressure up on IA to 2500 psi. Hold for 30 mins and chart. Good test. Bleed tbg and csg press to 0 psi. 6.00 WELLSR NUND CMPL TN Set BPV, change out rams for next well. Begin nippling down stack. 5.00 WELLSR NUND CMPL TN NU tree and test to 5000 psi. Release Rig @ 11 :00 AM 11/27. Prep to move rig. WELLSR CMPL TN Printed: 1/6/2006 10: 11: 12 AM ) ) 1 D-32 /1 D-32L 1 Well Events Summary DATE Summary Pre Rig Work 11/6/05 PULL 2.81" CA-2 BLANKING PLUG AND PRONG @ 13173' RKB, DRIFT W/2.70" CENT, SHOCK AND GAUGES TO TD @ 13778' RKB, MAKE TWO STATIC STOPS 13470' MD (30 MIN ) 13227' MD (15 MIN). IN PROGRESS. 11/7/05 BRUSH & FLUSH TO 2.75" XN NIPPLE @ 13268' RKB, GET CALL TO GO TO RIG JOB. IN PROGRESS. 11/8/05 SET 3-1/2" XXN PLUG @ 13268' RKB. IN PROGRESS. 11/9/05 SET 2.70" AVA CATCHER SUB @ 13268' RKB. BLED PRESSURE FROM TBG & IA. 11/14/05 SHOT 9 TBG PUNCHER HOLES FROM 13170' TO 13172' 11/17/05 LOADED WELL WITH 500 BBLS.9.6 BRINE. PUMPED DOWN TUBING, TAKING RETURNS FROM IA. WELL LEFT SHUT IN. 11/22/05 Pre- Rig MITOA- failed, POT IC- passed, PPPOT-IC- failed, Post Rig Work 12/15/05 UNABLE TO PUMP, TBG PRESSURED UP, SLOWLY DRIFTED TBG TO 1750' WLM, IN PROGRESS 12/16/05 LOADED I/A W/ BRINE AND DIESEL CAP TO 3000' PT TBG & I/A (GOOD TEST) IN PROGRESS 12/17/05 BAILED FROM 13,194' WLM TO 13,235' WLM, IN PROGRESS 12/18/05 BAILED, PULLED CATCHER & PLUG @ 13,268' RKB TUBING (0-13255, 00:3.500, 10:2.992) SURF CASING (0-9006, 00:9.625, Wt:40.00) PROO CAS ING (0-13324, 00:7.000, Wt:26.00) SLEEVE·C '13164-13165, , 00:4.312) LINER , 13183-14136, · 00:3.500, Wt:9.30) SEAL 13213-13214, · 00:4.000) NIP , 13268-13269, · 00:3.500) Perf :13814-13824) L 1 LINER TOP 13478-13826, 00:2.375, Wt:4.70) HPBO 13814-13944) Perf : 13870-13880) Perf : 13904-13944) ) ConocoPhillips Alaska, Ilnc > tD..32 _I I III "I I -~- ) KRU 1)-32 Well Type: INJ Orig 12/4/2000 Completion: Annular Fluid: Last W/O: 11/27/2005 Reference Log: Ref Log Date: Last Tag: 13761 TD: 14138 ftKB Last Tag Date: 8/3112005 Max Hole Angle: 76 deg 6440 GàsibgSffi6g+GOfIJI.MON··.STHIN(3$ Description Size SURF CASING 9.625 PROD CASING 7.000 CONDUCTOR 20.000 LINER 3.500 L 1 LINER TOP 2.375 WINDOW to L 1 3.500 ; Tubing StrinQ - TUBING Size I Top 3.500 0 Rêrforàtiòns5l.imma ry Interval TVD 13814 - 13824 6535 - 6540 Angle @ TS: 65 deg @ 13803 Angle @ TD: 63 deg @ 14138 API: 500292298200 SSSV Type: NIPPLE Rev Reason: Pull Plug Last Update: 1/6/2006 Top o o o 13183 13478 13826 Bottom 9006 13324 117 14136 13826 13836 TVD Wt Grade Thread 4577 40.00 L-80 BTCM 6330 26.00 J-55 BTC MOD 117 91.50 H-40 WELDED 6679 9.30 L-80 SLHT 6541 4.70 L-80 STL 6545 0.00 Zone C-4 Ft SPF 10 4 Date 51212001 Type Comment IPERF 2.5" HSD,DP,31JUJ, 60 deg ph IPERF 2.5" HSD,DP,3IJUJ, 60 deg ph IPERF 2.5" HSD,DP,3IJUJ, 60 deg ph Status 13870 - 13880 6559 - 6564 10 4 51212001 40 4 511/2001 C-3 13904 -13944 6574 - 6592 C-3,C-2,C-1 Stiniûlàtiör1s&$reatt'r1ånts Interval I Date I Type 13814 - 13944 5/5/2001 HPBD . Gas Lift Mandrels/Valves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Mfr 1 5178 3165 CAMCO KBUG-M CAMCO DMY 1.5 BK 0.000 0 C)ther1ÞIÜgs,eqÚip~ ,ete; )-JEWELRYfPOSTWØ RKO\lER) Depth TVD Type Description 501 501 NIP CAMCO 'DS' LANDING NIPPLE 13164 6265 SLEEVE-C BAKER CMU SLIDING SLEEVE - CLOSED 11/27/2005 13190 6276 PACKER BAKERZXP LINER TOP PACKER 13213 6285 SEAL 80-40 SBE 36' GBH-22 SEALS 13268 6307 NIP CAMCO XN NIPPLE w/2.75" XXN PLUG 13826 6541 Whipstock FLOW-THRU WHIPSTOCK TO L 1 General Notes Date Note 10/30/2004 Bi-LATERAL WELL: 1D-32 ORIGINAL COMPLETION; CTD DRILLED 1D-32L 1 LATERAL LEG 1 WILL BE PRE-PRODUCED BEFORE GOING TO INJECTION Date Run 11/27/2005 Vlv Cmnt ID 2.875 2.812 4.000 2.992 2.750 0.000 RECEIVED e STATE OF ALASKA e JAN 1 3 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska 0" & G REPORT OF SUNDRY WELL OPERATIONS ' as Cons. Commission 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska. Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 104' Repair Well 0 Pull Tubing 0 Operat. ShutdownD Plug Perforations 0 Perforate New Pool D Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Stimulate 0 Waiver 0 Convert Pre o Produced Injector o to WAG Injection Time Extension Re-enter Suspended Well Exploratory 0 Service -0 5. Permit to Drill Number: 200-173 6. API Number: 50-029-22982-00 9. Well Name and Number: 1 D-32 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool Total Depth measured 14138' fee.t true vertical 6679' feet Effective Depth measured 13758 feet true vertical 6512 feet Casing Length Size MD Structural CONDUCTOR 117' 20" 117' SURF CASING 8902' 9-5/8" 9006' PROD CASING 13220' 7" 13324' PROD. CASING 953' 3-1/2" 14136' WINDOW TO L 1 10' 3-1/2" 13836' Plugs (measured) Junk (measured) TVD Burst ~o"apse: 117' 4577' 6330' 667Q!«-;.¡, ...., íf1;:::/j'\ .. l' ¡;"wf~ð\!¡:¡;t.'j ¡ ...~ f'¡' . \:.:,t"Jtr sL l7 'íf: í\.p ( L,Ul)l! Perforation depth: Measured depth: 13814-13824'; 13870-13880'; 13904-13944' true vertical depth: 6535-6540'; 6559-6564'; 6574-6592' RBDMS 8Ft ,IAN J ? 2006 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 13255' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 501' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 656 103 3650 15. Well Class after proposed work: Exploratory 0 Development 0 Service [~ 16. Well Status after proposed work: OilO GasLJ WAGŒ 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 13. Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Oil-Bbl 473 Casin Pressure 797 400 Tubin Pressure 187 1284 Daily Report of Well Operations_X WDSPL 0 -/7-Ö~ Robert D. Christensen Title Phone Production Engineering Technician 907-659-7535 Date OJ II t) tp Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only e 1D-32 DESCRIPTION OF WORK COMPLETED SUMMARY e, Date Event Summary 1/6/2006ICommenced WAG EOR Injection - e e --.,. {fu ~') .\.:::..1 If!.ß\ ¡g, uJ. FRANK H. MURKOWSKI, GOVERNOR AIfASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John Peirce Wells Group Tech. ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 ~- .. ", -,' " . -", ,.' ".:,' -,~,.,_." ".,' ':-'" ..~, '. ~.,," _,_ ",...._¡;è'iß;' .~ ,,' -,'::. , Re: KRU 1D-32 Sundry Number: 305-298 SÇANNEU NO\i 0 ~~ ZOD5 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thiS!/. day of October, 2005 Encl. RE: MASP for lD-32 e e ;a:)-\~~ "d04- \s, "Ç Subject: RE: MASP for 10-32 From: "Ennis, J .I" <,JJ.Ennis@conocophil1ips.com> Date: Tuc, 04 Oct 2005 10:55:54 -0800 ~~ :, "" " To: t~111- maunder@adrnin.state.ak.us, .>ti¡ . . .'.' ~':!i:" . .:i'- CC: "Peirce, JohnW" <J~hn.W.Peirce@c()itocoPW~I~ps.com>, "Gober~ Howard" <Howard.Gobe~conoC()phil1ips.corI}~~ "~ukavji~,Stevc J" . >~., '. ...... . <SteveJ .Mukayi~@co~~çpph.illi~s:cPF~' "'iMoó~cŸ~ M" <M. Moone~@conocop~i~Iip~:C01rtF; "Eggemeyer, j craine ç~',~::WeromeX'::):5gg~meycr@conocopbillips.cOIli> '':.'''''' " Good morning Tom, The 1D-32 workover MASP checks out OK although, as you indicate, it is an unusually low value for the Kuparuk reservoir. A static BHP of 2339 psi was obtained on 8/31/05 at 13470' MD (6391' TVD). Assuming a worst-case scenario of a gas gradient back to surface (0.1 psi/ft), yields a 1700 psi MASP. The difference between the 2004 CTD MASP and the current value is a greater reservoir pressure was anticipated (-3300 psi) during CTD operations, the actual reservoir pressure found (-3000 psi) in 2004 was lower than anticipated and the well has since been pre-produced. The similarity to 1D-137 is an unfortunate coincidence. We did alter our BOP testing policy earlier this year. Pertinent excerpts from our current policy are as follows: Well control equipment, except annular BOP's, will be tested to their rated pressure after the installation of any wellhead body component or prior to drilling out each casing string unless the following conditions are encountered, in which case the pressure test will be limited as follows: a)80 percent of casing burst pressure is less than the BOP rated pressure b)wellhead rated pressure is less than the BOP rated pressure c) sound engineering concludes that a lower test pressure is above the maximum potential surface pressure to which the BOPE may be subjected, and if applicable, a waiver is obtained from the appropriate agencies allowing testing to that lower pressure. For drilling operations, annular BOP's should be tested to a maximum of 70 percent of rated working pressure if not otherwise specified. For workover operations, the annular BOP's may be tested to 50% of their rated working pressure if not otherwise specified. Please let me know if any other questions or concerns. Jim Ennis j.j.ennis@conocophillips.com (907)265-1544 (W) (907)632-7281 (C) -----Original Message----- From: Peirce, John W Sent: Monday, October 03, 2005 7:08 AM To: Ennis, J J¡ Gober, Howard¡ Mukavitz, Steve J Subject: FW: MASP for 1D-32 FYI from AOGCC regarding MASP numbers and BOP testing. -----Original Message----- 10f2 10/4/2005 1 :48 PM RE: MASP for lD-32 e e From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Saturday, October 01, 2005 4:28 PM To: Peirce, John W Subject: MASP for 1D-32 John, I was in today looking at the pile of sundries that came in on Friday. On 1D-32 and -32L1 I am requesting that you recheck the MASP. According to the 401 submitted when the lateral was added in 2004, the MASP was calculated at 2765 psi. I know that the well has produced, however has the BHP declined so far to make the MASP now 1700 psi?? That seems low. This value is similar to what you had for 1D-137. Also, has CPAI changed their policy for BOP testing?? The 3000 psi you give for 1D-137 is appropriate. If the MASP for 1D-32 is as high as it could be, 3500 psi might be more appropriate. Regardless, the drilling people normally test to the working pressure of the BOP regardless of MASP. I can support testing to the lower pressure and routinely list a minimum BOP test pressure. Just wanted to see if the philosophy has changed. Thanks, Tom Maunder, PE AOGCC 20f2 10/4/2005 1 :48 PM e e John Peirce Wells Group Technician Drilling & Wells ConocJ'Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6471 September 30,2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED SEP 3 Alaska . 0 2005 Oil & Gas C Ons Co AnchOl"age" f'I1rniSSion Subject: Application for Sundry Approval for 1 D-32 and 1 D-32L 1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk multilateral well 1 D-32 and 1 D-32L 1. We are planning to workover this well to pull and replace the tubing. If you have any questions regarding this matter, please contact me at 265-6471. Sincerely, I~---- / John Peirc~ Wells Group Technician CPAI Drilling and Wells JP/skad L · ..- _}m¡O-4--OJ STATE OF ALASKA /'.x"" ALASKA OIL AND GAS CONSERVATION COMMISSION ~ APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Irro/-." 1. Type of Request: Abandon D Suspend D Operation Shutdown D Perforate D Waiver D Other D Alter casing D Repair well 0 Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 200-173 -./ 3. Address: Stratigraphic D Service 0 6. API Number: v'" P. O. Box 100360, Anchorage, Alaska 99510 ,- , 50-029-22982-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 34' 1 D-32 8. Property Designation: 10. Field/Pool(s): ADL 28248 I 25650, ALK 591 Kuparuk River Field I Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14138' 6679' 13758' 6512' Casing Length Size MD TVD l:. .,.... _Burst Collapse CONDUCTOR 117' " ¡&':.. -"':J\ 1- 117' 20" 117' -...., V'_, 11 SURF CASING SFp !) _ -I 1-' 8902' 9-5/8" 9006' 4577' PROD CASING 13220' 7" 13324' ~'I -. ~ U ¿uas LINER .6679' ., J( A'-'aS ConS. t'-^-.. 953' 3-1/2" 14136' WINDOW TO L 1 10' 3-1/2" 13836' 6545' .~ ~n Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13814'-13824',13870'-13880', 13904'-13944' 6535'-6540',6559'-6564',6574'-6592' 3-1/2" L-80 13255' Packers and SSSV Type: Packers and SSSV MD (ft) Baker 5x7" ZXP liner pkr @ 13191 ' Landing Nipple @ 533' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development D Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: October 14,2005 Oil D Gas D Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ 0 WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name John Peirce Title: Wells Group Tech. Signature 421V:¿::;;:?~- Phone Date 9-3D-O::; / ~/ - .---::_--~ Commission Use Only L..--r I '/ Sundry Number: ~ Conditions of approval: Notify Commission so that a representative may witness ~OC' .. 2,q;~ Plug Integrity D BOP Test 'Ø--. Mechanical Integrity Test ~ Location Clearance D oth.c 3CX::O ~\ ~-\t -A "" '> ~ \ ö.,",~c¿j , RBDMS BFl 0 CT 0 5 Z005 ::~~n?ø ~ APPROVED BY Ib/#o5 COMMISSIONER THE COMMISSION Date: L/ ~ - f { Form 10-403 Revised 7/2005 L Submit in Duplicate MI RU Workover Rig, Verify that the well is dead, <.O~ì """" ~ m. "Ij NO tree. NU 11" 5M BOPE. Pull BPV. Test BOPE to 250/3000 psi (MASP = 1700 psi). \0 f¿ .- ~ Unland tubing hanger. If tubing does not pull free from seal assembly, cut the tubing in the middle of first full joint above the seal assembly. POOH with 3.5" tubing. Run new 3.5" completion and stab into seal assembly, else overshot the tubing stub and set a stacker packer if tubing cut was required. Space out and land hanger. Pressure test tubing and inner annulus. Bleed tubing & IA down to zero psi. NO BOPS, NU tree, PT tree & packofts. Set BPV. 4 '"\"4è..~~ \-ß~ S. \.c~ \J ~Jè ROMO workover rig. \... _ .-i ~ C"\. '-~"'-ü r '42~ \0 l( e e Kuparuk 1 D-32 General Workover Procedure for Replacement of Corroded Leaky Tubing Pre-Ria Work 1.) Perform POT PPPOT T&IC. Function test lockdown screws. 2.) Pull CA-2 plug from OS Nipple at 13172' RKB. RIH & tag fill. 3.) Obtain SBHP at 13470' & 13227' RKB. (SBHP 8/31/05 indicated KWF is -7.1 ppg) 4.) Set PXN plug w/prong in the XN Nipple at 13268' RKB. Set Catcher Sub on top of PXN. 5.) Tubing punch circulation hole at 13195' RKB in middle of firstfull joint above seal assembly. 6.) Circulate the well to 9.6 ppg Brine through the circulation hole above, and a confirmed tubing leak (0.25 bpm @ 1950 psi leak) located somewhere between 5245' and 13172' RKB. 7.) Bleed tubing down to zero psi and check for flow. 8.) Prep location for Workover Rig. 9.) Set BPV within 24 hours of rig arrival on location. General Workover Procedure 1.) 2.) 3.) 4.) 5.) 6.) 7.) 8.) Post-Ria Work 1.) 2,) 3.) 4.) 5.) 6.) 7.) 8.) Pull BPV. RU Slickline. Shift Sliding Sleeve open. Circ out 9.6 ppg KW Brine via Sliding Sleeve w/corrosion inhibited Brine & FP w/Oiesel cap. Retrieve ball & rod and RHC plug (if needed following a stacker packer set), Shift Sliding Sleeve closed. PT IA & tubing. Pull Catcher Sub and PXN plug from XN Nipple at 13268' RKB. Tag fill. Reset the well house and return well to injection. Run IPROF w/shut-in temp passes to verify no water injection into liner holes above C sand. \rJ~((:"~~\\'c;.. ~~\~~ ~ \,,\~t...\'~"" (£),,~c-À- I.~~fè,--\a'\ ~~.~ \\-NL>~~ '-"- \~.Æ~ q, " e e Kuparuk 1 D-32 General Workover Procedure for Replacement of Corroded Leaky Tubing Pre-Ria Work 1.) Perform POT PPPOT T&IC. Function test lockdown screws. 2.) Pull CA-2 plug from OS Nipple at 13172' RKB. RIH & tag fill. 3.) Obtain SBHP at 13470' & 13227' RKB. (SBHP 8/31/05 indicated KWF is -7.1 ppg) 4.) Set PXN plug w/prong in the XN Nipple at 13268' RKB. Set Catcher Sub on top of PXN. 5.) Tubing punch circulation hole at 13195' RKB in middle of first full joint above seal assembly. 6.) Circulate the well to 9.6 ppg Brine through the circulation hole above, and a confirmed tubing leak (0.25 bpm @ 1950 psi leak) located somewhere between 5245' and 13172' RKB. 7.) Bleed tubing down to zero psi and check for flow. 8.) Prep location for Workover Rig. 9.) Set BPV within 24 hours of rig arrival on location. General Workover Procedure 1.) MIRU Workover Rig. Verify that the well is dead. 2.) NO tree. NU 11" 5M BOPE. Pull BPV. Test BOPE to 250/3000 psi (MASP = 1700 psi). 3.) Unland tubing hanger. If tubing does not pull free from seal assembly, cut the tubing in the middle of first full joint above the seal assembly. 4.) POOH with 3.5" tubing. 5.) Run new 3.5" completion and stab into seal assembly, else overshot the tubing stub and set a stacker packer if tubing cut was required. Space out and land hanger. 6.) Pressure test tubing and inner annulus. Bleed tubing & IA down to zero psi. 7.) NO BOPS, NU tree, PT tree & packoffs. Set BPV. 8.) ROMO workover rig. Post-Ria Work 1.) Pull BPV. 2.) RU Slickline. Shift Sliding Sleeve open. 3.) Circ out 9.6 ppg KW Brine via Sliding Sleeve w/corrosion inhibited Brine & FP w/Oiesel cap. 4.) Retrieve ball & rod and RHC plug (if needed following a stacker packer set). 5.) Shift Sliding Sleeve closed. PT IA & tubing. 6.) Pull Catcher Sub and PXN plug from XN Nipple at 13268' RKB. Tag fill. 7.) Reset the well house and return well to injection. 8.) Run IPROF w/shut-in temp passes to verify no water injection into liner holes above C sand. ) ') ~' ~..:J, " \~~ [-;=D ~ ,~ \ I, r /ß/'1 \, 'I r ! L , I l ,I , \ I ";::¡ c "~\ : lii.' '! ¡ I.(b!J LJ i ll' U ~ (,~11\?1 I 'I ! ¡' U! ;,::ìJ t r r! i \~¡ /'i\~\ ii ~i~", \ (7n~"), r-1~/7 i, \ i t\\ :: i, J\:' i~ i,\; " I "i'll, ,,I !)\\ )!i :, \~ !! / ,0 \ : "\~)\ ;U:\ / U\ ltlJ ~U~jæ.' :" I (, U FRANK H. MURKOWSKI, GOVERNOR A.{A~1iA ORAND GAS CONSERVATION COJDIISSIOlV 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Seitz Kuparuk Staff Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 d<.OO ~ ~73 Re: Kuparuk 1D-32 Sundry Number: 305-235 SC/~NNE[) l-\UG 1 if 2005 Dear Mr. Seitz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decisi t Superior Court unless rehearing has been requested( "' Si J DATED thi/r day of August, 2005 Enc!. 1. Type of Request: Abandon ~ (.,(tr~/7~Oš ~.- dY7-sy¡ /1.· RECEIVED I\( ,9 ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 1 {; 2005 APPLICATION F~~~~.~~RY APPROV ALAlash Oil & ß¡!B CUllS. Commission D Suspend D Operation Shutdown D Perforate D Waiver Ar~omge Other 0 D Repair well D Plug Perforations D Stimulate D Time Extension D convert to injector D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 4. Current Well Class: 5. Permit to Drill Number: Development 0 Exploratory D 200-173 Y'" Stratigraphic D Service D 6. API Number: ) STATE OF ALASKA Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 34' 8. Property Designation: ADL 28248 125650, ALK 591 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 14138' 6679' 13758' Casing Length Size 50-029-22982-00 9. Well Name and Number: 1 D-32 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6512' MD v TVD Burst Collapse CONDUCTOR 117' 20" SURF CASING 8902' 9-5/8" PROD CASING 13220' 7" LINER 953' 3-1/2" WINDOW TO L 1 10' 3-1/2" 117' 117' 9006' 4577' 13324' 6330' 14136' 6679' 13836' 6545' Perforation Depth MD (ft): 13814'-13824', 13870'-13880', 13904'·13944' Packers and SSSV Type: Baker 5x7" ZXP liner pkr @ Landing Nipple @ 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Brian Seitz --::)._/U4"~ /~ Perforation Depth TVD (ft): 6535'-6540',6559'-6564',6574'-6592' Packers and SSSV MD (ft) 13191' 533' 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: Oil D Gas D WAG D GINJ D Tubing Size: 3-1/2" Tubing Grade: L-80 Tubing MD (ft): 13255' Service 0 1-Sep-05 Date: Plugged D WINJ 0 Abandoned D WDSPL D Contact: Title: Brian Seitz @ 265-6961 Kuparuk Staff Engineer "1j -.a D ~ j /f ./ Phone n.J 'Ó16/ ate :.J/ ~j /¿J _,) Signature Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3oÇ'-d- 3~ Plug Integrity D BOP Test D Mechanical Integrity Test ~ Location Clearance D Other: RBDMS BFL AUG 1 9 2005 Form 10-403 Revised 11/2004 '- APPROVED BY COMMISSI.ONE, R"N A,' LTHE COMMISSION OR\G\\ ' . Date: 110(' Submit in Duplicate ) ') KRU 1 D-32 & 1 D-32L 1 Conversion to Injection Background KRU 1D-32 was drilled and completed as a C-sand injector in December of2000 to support offset producers 1D-30 and 1D-32. The well remained on water injection until September of2004, when the 1D-32L1 horizontal lateral was drilled with coiled tubing while preserving the original wellbore. After the coiled tubing sidetrack, the well was put on pre-production in November of 2004 at an initial rate of 600 BOPD and 25% water cut. The well most recently tested on July 4, 2005 at 495 BOPD and 15% wc. However, with only one gas lift mandrel at 3185' tvd, the well is becoming increasingly unstable. The plan is to now complete the necessary facility work tó convert the well back to its originally intended service of water injection to support offset producers 1D-30 and 1 D-34. ~ ---, / A CBL run on 4/24/01 indicates good cement across the top and above the C-sand pay interval. The last MITIA for 1D-32 was performed on 7/24/04 as part ofpre-CTD diagnostics. The well passed the MITIA. Summary of Operations Necessary piping and instrumentation will be put back in place to convert surface slot 32 on DS-1D back to water injection service. Proposed wellwork is limited to changing out the OV at 5,230' rkb with a DV and perform an MITIA per AOGCC requirements. ./~ ~';;i'; '. '1ir ;~Yt ~~..~.~ . - fI ;.' "N. ., '~'.'. '"'''''''''''''''''''''''~_''''' I_._.~.~ MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _Marker .doc ) ) Dan Venhaus Wells Group CTD Engineer Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4372 February 7,2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RE EIVED FEB 0 9 2005 AlasKa Oil & Cl'lf"l~ Cnm. . '. ' II.nI,;:¡. u missu:m Anchorage Subject: Report of Sundry Well Operations for 10-32 (APD # 200-173) Dear Commissioner: ConocoPhillips Alaska, Inc, submits the attached Report of Sundry Well Operations to convert the Kuparuk well 1 0-32 from an injector to a producer effective 10/31/04. If you have any questions regarding this matter, please contact me at 263-4372, Sincerely, q:¿~ D. Venhaus Wells Group CTD Engineer CPAI Drilling and Wells DV Iskad SCANNED FEB 11 2005 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc, 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 34' Repair Well 0 Pull Tubing 0 Operat. ShutdownD Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development - [2] Stratigraphic 0 1. Operations Performed: 8. Property Designation: ADL 28248/25650, ALK 591 11. Present Well Condition Summary: Total Depth measured 14138' feet true vertical 6679' feet Effective Depth measured 13758' feet true vertical 6512' feet Casing Length Size MD Structural CONDUCTOR 117' 20" 117' SURF CASING 8902' 9-5/8" 9006' PROD CASING 13220' 7" 13324' LINER 953' 3-1/2" 14136' WINDOW TO L 1 10' 3-1/2" 13836' Perforation depth: Measured depth: 13814'-13824',13870'-13880',13904'-13944' true vertical depth: 6535'-6540',6559'-6564', 6574'-6592' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 13255' MD. Packers & SSSV (type & measured depth) Baker 5 x 7" ZXP liner pkr @ 13191' Landing Nipple @ 533' 12. Stimulation or cement squeeze summary: Intervals treated (measured) n/a Treatment descriptions including volumes used and final pressure: Stimulate 0 Waiver 0 Other [2] Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: to convert from injector to producer Exploratory 0 Service 0 200-173 6. API Number: 50-029-22982 -00 9. Well Name and Number: 1 0-32 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Collapse Burst 117' 4577' 6330' 6679' 6545' RE EIVED FE8 0 9 Z005 .Alaska Oi! & Cons. Commission Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Tubinq Pressure 13. Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Casinq Pressure 15. Well Class after proposed work: Exploratory 0 Development [2] Service 0 16. Well Status after proposed work: Oil[2] GasD WAG 0 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: Contact Printed Name Dan Venhaus @ 263-4372 ~'~eUh / s l..// / 7 i:~ l:h1~ Title Phone Signature OR\GINAL. Form 10-404 Revised 04/2004 WDSPL 0 Coiled Tubing Engineer 907 -263-4372 Date Preoared bv Sharon Allsuo-Drake 263-4612 RBDMS BFL FEB 0 9 2005 Submit Original Only Re: KRU 10-11 and 10-32 Thanks Brian. We got most of what was needed to be filed. I am surprised that production on a well completed as an injector didn't "jump out" of the system. If this is the worst we do on this, we aren't too bad. Have a nice weekend. Tom Seitz, Brian wrote: Tom- We just finished drilling a new producer (lD-28) north of 1D-11. We are waiting on test results from it, and additional tests on 1D-11, before we make any decisions regarding conversion timing. I expect we will try and produce 1D-11 for at least 2-3 more months if upcoming testing shows continued strong production. ID-32 was shut-in during the month of December waiting on a flowline hook-up. The well is now on production and we plan to test it next week, following the initial flowback and testing of 1D-28. Like 1D-11, we plan to produce 1D-32 for -3 months. And sorry about the confusion on the 404s. We'll get the paperwork staightened out. Regards, Brian 265-6961 - h. Íl\.H"'iE~ \ S E ~D ".li;'" ~\.'..' '2:_.0', O~." SCn!~p~-·~~' '- _!" : ð_ !-" -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, February 04, 2005 2: 0 3 ......·PM......··..................................·-..............·....·.................................................................................................................................... To: Allsup-Drake, Sharon K¡ Seitz, Brian Cc: Steve McMains Subject: KRU 1D-11 and 1D-32 Sharon and Brian, Last fall Brian and I had exchanged some messages with regard to the planned laterals out of these two injection wells and the desire to pre-produce after the laterals were completed. The advise at that time was to file the 407s for the laterals with them completed as producers. That was done as requested. Only thing we missed was changing the status of the motherbores from injectors to producers. Sharon, would you please file 404s for 1D-11 and 1D-32 notifying us of the change from injector to producer with effective dates of 11/20/04 and 10/31/04 respectively?? This will straighten out the paperwork. Brian, I note that the production from 1D-11 et al has been impressive. Congratulations! !! Is the combination still producing?? How long before conversion?? On 1D-32, not as good but there was some oil there. Our production report shows the well SI in December. What is going on with the well?? Thanks in advance to both of you. Tom Maunder, PE AOGCC ~~~~ 10f2 9/12/2005 8:26 AM RE: KRU ID-ll and ID-32 LI: Request for' )er from monthly testing ) \'\)- \ \ \~~-O 'l~, - \ \ L \. ;}04'~d-\ \ - \ \ \... ~ ~~'.ð-\à \'~'-"'J GOO-\~~ - s,) \-1- ~Ð'-\'~ \<iç Subject: RE: KRU ID-II and ID-32 LI: Request for waiver from monthly testing From: "Seitz, Brian" <Brian.Seitz@conocophillips.com> Date: Wed, 27 Oct 2004 09:22:43 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us>, "Venhaus, Dan E" <Dan.E.Venhaus@conocophillips.com> CC: John D Hartz <jac~hartz@admin.state.ak.us>, Steve McMains <steve _mcmains@admin.state.ak.us>, "Johnstone, Sam" <Sam.Johnstone@conocophillips.com>, "Lamar Gantt (E-mail)..<ganttll@bp.com> Thanks Tom. Dan & Lamar - please note that this applies to 1 D-32 as well with regards to how to file the completions report. Brian -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, October 27, 20049:16 AM To: Seitz, Brian Cc: John D Hartz; Steve McMains Subject: Re: KRU 1D-11 and 1D-32 L1: Request for waiver from monthly testing Brian, With regard to the plan to produce I D-II, L I and L2 for some 3 to 6 months, when the lateral completion reports (form 407s) are submitted they should show the completion as I-oil. This will make sure the production record is established appropriately. When CP AI has determined it time to convert to injector, then 403s should be submitted to provide notice and request approval of the conversion. I hope this answers your question. Tom Maunder, PE AOGCC Seitz, Brian wrote: Thanks Tom. I appreciate the quick turn-around on this on$CANNE[j NOV 0 4 2004 Brian -----Original Message----- From: Thomas Maunder [mailto:t~~_~aunder@admin.state.a~~us] Sent: Thursday, September 30, 2004 3:17 PM To: Seitz, Brian Cc: jack hartz@admin.state.ak.us¡ CPF1 Prod Engr Subject: Re: KRU 1D-11 and 1D-32 L1: Request for waiver from monthly testing Brian, Jack and I have discussed your proposal and find it acceptable. I have received the sundries for the wells and will include a copy of this email with them. Please call with any questions. Tom Maunder, PE AOGCC 1 {)f"> 11/1/,,>()(\J o.¿;¡O '1\" RE: KRU ID-II and ID-32 LI: Request for' )er from monthly testing ) Seitz, Brian wrote: Tom- ConocoPhillips is evaluating the temporary conversion of two Kuparuk water injection wells, KRU 1D-11 and KRU 1D-32 L1, to production. While on production, both wells will be tied into the production header. However, tying into the test header to allow for well testing through the DS-1D test facility is likely to add significant cost and delay to a project that is short term in nature. As such, we request a waiver from the monthly well testing requirement for the estimated 3-6 months that these two wells will be on production. We propose testing the wells through a temporary test skid every other month during the production period. KRU 1D-11 is a current water injector perforated in only the C4 sands. We plan to perforate oil bearing C1 sands and evaluate its productivity in support of other development planned in the area. Depending upon results of the C1 test, perforations may also be added in the C3 sands. Production is expected to last no longer than 6 months. An Application for Sundry Approval for the temporary conversion to production will be filed today. KRU 1D-32 is a current water injector scheduled to be sidetracked as 1D-30 L1 with coiled tubing in October. Following the coiled tubing sidetrack, we plan to flow test the well and if results are encouraging, put it on production for a period expected to last no longer than 6 months. A permit to drill and an Application for Sundry Approval for the temporary conversion to production will be filed this week. Please contact me if you wish to discuss our plans for these wells or require additional detail. Regards, Brian Seitz Kuparuk CPF-1 Lead Engineer (907) 265-6961 ") ,,") 11/1/")(I(lJ f\.-f\ ^ 1\.1 I -~-~ C ~II' ".:ÞLL LOG TRANSMITTAL ProActive Diagnostic Services, 'nc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 RE: Distribution - Final Print[s) u:~~ cP-&D - /73 ~ OCT 1 2 2004. The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 WELL LOG TYPE DIGITAL OR CD-ROM 1 DATE Open Hole Res. Eva!. CH 1 Mech. CH 10-32 1 0-03-04 Caliper Survey MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUE LINE 1 1 1 1 Rpt or 2 Color Date : /?Þ;ht/ PRoAcTivE DÍAGNOSTic SERVicES, INC., PO Box 1 }69 STAffoRd 1)( 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com SCANNED NO\! 0 8 1.004 ;)00 ~. i13 @ 11 '. ^\ l;J1 f[ !.. (..#,). '..\.!.' '" to,!~ I.;, æJ lrü U Ls lliJ r-;"'\ ¡ f¡ \ ff~ FRANK H. MURKOWSKI, GOVERNOR AT1ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. ]7H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Seitz Kuparuk Staff Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk 1D-32 Sundry: 304-366 Dear Mr. Seitz: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. / BY ORDER OF IYE COMMISSION DATED this.!!f- day of October, 2004 Enc!. SCANNED OCT 0 9 2004 RECEIVED 4' STATE OF ALASKA ' ~5Ù ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 3 0 2004 APPLICATION FOR SUNDRY APPROVIALO. & G C c.' \. 20 MC 25.280 ~lãsKa I as ons. OMmISS , ålld,ót&Ù& D Suspend D Operation Shutdown D Perforate D Wàtver LJ Annular Disp, D D Repair well D Plug Perforations D Stimulate D Time Extension D Other 0 D D D D Temporarily Pull Tubing Perforate New Pool Re-enter Suspended Well Convert to Producer 5. Permit to Drill Number: 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 104' 4. Current Well Class: Development Stratigraphic 0 D Exploratory D Service D 200-173 6. API Number: 50-029-22982-00 9. Well Name and Number: 1 0-32 10. Field/Pool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6679' Length 8. Property Designation: ADL 028248 11. Total depth MD (ft): 14138' Casing CONDUCTOR 117' SURF CASING 8902' PROD CASING 13220' LINER 953' Size MD TVD Burst Collapse 20" 117' 9-5/8" 9006' 7" 13324' 3-1/2" 14136' Signature Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D Mechanical Integrity Test D Tubing Size: 3-1/2" Tubing Grade: L-80 Tubing MD (ft): 132551 Sundry Number: 3t::1,,/... 3" (f. Location Clearance D Oth;r: ~VV~~~\.\ ';:-~~X_\".~c (lC~'\~Q:.\\~ \l'\"O~C£-\-\cc .~\., ~ ~'t\,\ \~'\td:~("r~~ \ \.î;....H::~'\;\ l~"I/.CJQ«X"o,c'b. \\'\M). ') ~<;,'V\~'> c., '-\.0' Q.~ Ic''''\.C> ~ ~ç,. ~~\'OlV~~ , Subsequent Form Required: .. BfL OCT 0 ~ ?O,n~ Approved by: g¡ ~ 0 R I c~~I~l~E~~~~~~~~~~ION Date: It; 4 ~1' V Form 10403 Revis 12120SCA~ OCT fY'/9Tma4IONS ON REVERSE SUbm¡:l D:¡ca: KRU 1 D-32 and 1 D-32 L 1 Temporary Conversion to Production Backeround KRU ID-32 was drilled and completed as a C-sand water injector in December of2000. A coiled tubing lateral (lD-32 Ll) is scheduled to be drilled in October of 2004 to provide additional support to recently drilled ID-30 Ll. Following the coiled tubing drilling, the well will be flowed back and tested. If test results are promising, the well will remain on production for an estimated 3 -6 months, after which it will be returned to water injection service. Summary of Operations . Move in Nordic 2 and drilllD-32 Ll per Permit to Drill dated 9/29/04 . At completion of drilling operations, flow well to tank to clean up . Conduct well test through portable test skid during flow-back period . If well is able to sustain viable production, tie into DS 1 D production facilities and produce for an estimated 3-6 months, testing periodically with portable test skid . At end of production period, return to water injection service SCANNED OCT 0 9 2004 Re: KRU 1 D-ll and 1 D-32 L 1: Request for waiver from monthly testing Subject: Re: KRU 1D-11 and 1D-32 L1: Request for waiver from monthly testing From: Thomas Maunder <tom - maunder@admin.state.ak.us> Date: Thu, 30 Sep 2004 15:17:07 -0800 To: "Seitz, Brian" <Brian.Seitz@conocophillips.com> CC: jack_hartz@admin.state.ak.us, CPF1 Prod Engr <n1269@conocophillips.com> Brian, Jack and I have discussed your proposal and the sundries for the wells and will include Please call with any questions. Torn Maunder, PE AOGCC find it acceptable. I have received a copy of this email with them. Seitz, Brian wrote: Tom- ConocoPhillips is evaluating the temporary conversion of two Kuparuk water injection wells, KRU ID-ll and KRU ID-32 Ll, to production. While on production, both wells will be tied into the production header. However, tying into the test header to allow for well testing through the DS-ID test facility is likely to add significant cost and delay to a project that is short term in nature. As such, we request a waiver from the monthly well testing requirement for the estimated 3-6 months that these two wells will be on production. We propose testing the wells through a temporary test skid every other month during the production period. KRU ID-ll is a current water injector perforated in only the C4 sands. We plan to perforate oil bearing Cl sands and evaluate its productivity in support of other development planned in the area. Depending upon results of the Cl test, perforations may also be added in the C3 sands. production is expected to last no longer than 6 months. An Application for Sundry Approval for the temporary conversion to production will be filed today. KRU ID-32 is a current water injector scheduled to be sidetracked as ID-30 Ll with coiled tubing in October. Following the coiled tubing sidetrack, we plan to flow test the well and if results are encouraging, put it on production for a period expected to last no longer than 6 months. A permit to drill and an Application for Sundry Approval for the temporary conversion to production will be filed this week. Please contact me if you wish to discuss our plans for these wells or require additional detail. Regards, Brian Seitz Kuparuk CPF-l Lead Engineer (907) 265-6961 1 of 1 SCANNED OCT 0 9 2004 9/30/20043:17 PM ~ c:2trO - ( 7 3> Memory Mutti-Finger Caliper log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. October 3, 2004 5533 1 3.5" 9.3 lb. L-80 EUE 8RD Tubing Well: Field: State: API No.: Top Log IntvI1.: Bot. Log Intvl1.: 1 D-32 Kuparuk Alaska 50-029-22982-00 Suñace 13,894 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the XN Nip @ 13,268' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate the 3.5" tubing logged is in good to poor condition with respect to corrosive damages. A hole is recorded in joint 432 @ 13,619'. Three other possible holes are recorded in joints 433, 437 and 438. Wall penetrations from 20% to 84% are recorded throughout the tubing logged. The damage appears in the form of general corrosion with deeper lines of corrosion and isolated pitting. Cross-sectional wall loss of 21% is recorded in an area of corrosion in joint 435 @ 13,683'. Deposits restrict the I.D. to 2.71" injoint432 @ 13,614'. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: Hole (100%) Jt. 432 @ 13,619 Ft. (MD) Possible Hole ( 87%) Jt. 433 @ 13,637 Ft. (MD) Possible Hole ( 86%) Jt. 438 @ 13,806 Ft. (MD) Possible Hole ( 85%) Jt. 437 @ 13,752 Ft. (MD) Corrosion (84%) Jt. 427 @ 13,452 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Corrosion (21%) Jt. 435 @ 13,683 Ft. (MD) Corrosion (21%) Jt. 436 @ 13,747 Ft. (MD) Corrosion (20%) Jt. 433 @ 13,619 Ft. (MD) Corrosion (20%) Jt. 429 @ 13,495 Ft. (MD) Corrosion (20%) Jt. 425 @ 13,365 Ft. (MD) MAXIMUM RECORDED ID RESTRICTIONS: Deposits Minimum I.D. = 2.71" Jt. 432 @ 13,614 Ft. (MD) Deposits Minimum I.D. = 2.72" Jt. 420 @ 13,205 Ft. (MD) Deposits Minimum I.D. = 2.72" Jt. 434 @ 13,674 Ft. (MD) Deposits Minimum I.D. = 2.72" Jt. 402 @ 12,636 Ft. (MD) Deposits Minimum I.D. = 2.73" Jt. 440 @ 13,875 Ft. (MD) I Field Engineer: N. Kesseru Analyst: M. Lawrence Witness: V. Vaughn ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Q. Well: Field: Company: Country: 10-32 Kuparuk ConocoPhillips Alaska, Inc. USA PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of fingers: Anal st: October 3, 2004 MFC 24 No. 00387 1.69 24 M. Lawrence Tubing: Weight 9.3 f Grade & Thread l-80 EUE 8RD Nom. Upset 3.5 ins Upper len. 1.2 ins lower len. 1.2 ins Nom.OD 3.5 ins Penetration and Metal loss (% wall) - penetration body 400 - metal loss body 300 200 100 -- û 0 to 1% 1 to 10% 10 to 20 to 40 to over 20% 40% 85% 85% 3 0 Damage Configuration ( body) 300 250 200 150 100 50 0 isolated pitting general line ring hole / poss corrosion corrosion corrosion ihle hole 4 - penetration body 0 1 NomJD 2.992 ins Damage Profile (% wall) - metal loss body 50 100 GlM 1 Bottom of Survey = 441 Analysis Overview page 2 a Well: Field: Company: Country: PDS Caliper Minimum Diameter Profile 10-32 Kuparuk ConocoPhillips Alaska USA Survey Date: Tool: Tool Size: Tubing 1.0.: October 3, 2004 MFC 24 No. 00387 1.69 inches 2.992 inches Minimum Measured Diameters (In.) 1.69 1.79 1.89 1.99 2.09 2.19 2.29 2.39 2.49 2.59 2.69 2.79 2.89 2.99 1 8 15. 25 35 45 55 65 75 85 95 105 11S 125 135 145 155 165 172 182 192 t 20"1 .Q E 212 :I Z 222 .5232 Q - 242 252 262 272 282 292 302 312 322 332 342 352 362 372 382 392 402 412 419 425 435 Pipe: Body Wall: Upset Wall: NominaII.D.: Joint No. PDS REPORT JOINT TABULATION SHEET 3.5 in 9.3 ppf L-80 EUE 8RD 0.254 in 0.254 in 2.992 in Jt. Depth (Ft.) 1 1.1 1.2 1.3 2 3 4 5 6 7 8 9 10 11 12 13 14 15 15.1 15.2 15.3 16 17 18 19 20 21 22 23 24 25 26 9 41 51 62 66 97 129 159 190 221 252 283 315 347 378 410 441 473 505 511 513 518 550 579 611 642 672 702 732 764 795 826 858 889 919 951 982 1013 1044 1076 1105 1136 1167 1198 1230 1261 1293 1324 J 35.5- . 1386 ,., "-I 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 Pen. Pen. Upset Body (Ins.) (Ins.) 0 0.03 0 0.01 0 0.02 () 0.03 0 0.03 0 0.03 0 0.04 0 0.04 0 0.03 () 0.09 0 0.03 0 0.11 () 0.11 0 0.11 0 0.11 0 0.11 0 0.12 0 0.10 0 0.02 0 0 0 0.01 0 0.09 0 0.08 0 0.09 0 0.12 0 0.13 0 0.11 0 0.13 0 0.11 0 0.12 0 0.09 0 0.15 0 0.08 0 0.13 0 0.14 0 0.14 0 0.14 0 0.14 0 0.12 0 0.12 0 0.11 0 0.12 0 0.13 0 0.12 0 0.12 0.08 0.15 0 0.12 0 0.13 0 _.<).1 5 0 0.12 Pen. Metal % Loss <Yo 13 6 9 13 11 11 15 16 13 35 12 45 43 43 43 43 47 39 9 0 3 34 33 36 48 53 44 52 44 49 36 58 31 53 57 56 57 54 46 49 44 45 52 47 48 57 46 50 59 48 2 3 1 1 1 2 3 2 2 2 1 3 3 3 4 4 3 3 I 0 1 3 2 2 3 4 5 6 4 6 4 4 4 6 6 6 6 7 6 7 6 9 7 6 6 9 5 8 .5 6 Min. 1.0. (Ins.) 2.95 2.96 2.91 2.91 2.94 2.96 2.95 2.95 2.94 2.94 2.95 2.95 2.95 2.95 2.96 2.95 2.90 2.95 2.87 2.88 3.01 2.95 2.95 2.94 2.95 2.95 2.94 2.94 2.94 2.91 2.94 2.94 2.94 2.92 2.93 2.92 2.94 2.94 2.93 2.93 2.94 2.90 2.95 2.95 2.95 2.91 2.95 2.92 2.93 2.93 Well: Field: Company: Country: Survey Date: 10-32 Kuparuk ConocoPhillips Alaska, Ine. USA October 3, 2004 Comments Shallow Ditting. Lt. DeDosits. PUP PUP PUP Shallow Ditting. Lt. Denosits. Shallow Ditting. Shallow Ditting. Shallow Ditting. Isolated Ditting. Isolated nittiml:. Isolated Ditting. Isolated Dittin\!:. Isolated Ditting. Isolated Ditting. Isolated Ditting. Lt. DeDosits. Isolated Ditting. Lt. DeDosits. PUP Lt. DeDosits. DS NIP PUP Isolated Dillin\!:. Isolated Dillin\!:. Isolated Dittin\!:. Isolated Dittin\!:. Lt. DeDosits. Isolated uitting. Isolated Ditting. Isolated Ditting. Lt. DeDosits. Isolated Ditting. Lt. Denosits. Corrosion. Isolated Dittin\!:. Isolated Ditting. Isolated Ditting. Isolated Ditting. Isolated Ditting. Isolated Ditting. Isolated Dittin\!:. Line corrosion. Isolated Ditting. Isolated Ditting. Lt. DeDosits. Isolated Dillin\!:. Isolated nittiml:. Lt. Denosits. Isolated Dittin\!:. Lt. DeDosits. Isolated Dittin\!:. Corrosion. Lt. DeDosits. Line corrosion. Line corrosion. Isolated Ditting. Isolated Ditting. Isolated Dillin\!:. Page 1 Damage Profile (%wall) 0 50 100 . III-III ll1II-18I - II18I- lIlli- . . . . I Penetration Body Metal Loss Body PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaILD.: 3.5 in 9.3 ppf L-80 EUE 8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 10-32 Kuparuk ConocoPhillips Alaska, Ine. USA October 3, 2004 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage P rofile No. (Ft.) Upset Body % Loss LD. Comments (%wall) (Ins.) (Ins.) '10 (Ins.) 0 50 tOo 45 1418 0 0.11 43 6 2.93 Isolated Ditting. ... ~. 1449 0 0.13 53 6 2.9Q- ~rosion. Lt. Deposits. 47 1480 0 0.15 57 6 2.92 Isolated nittin\!. 48 1512 0 0.13 50 6 2.92 Corrosion. 49 1543 0 0.13 52 9 2.91 Corrosion. 50 1574 () 0.17 68 5 2.94 Isolated Dittin\!. 51 1606 () 0.15 60 11 2.92 Corrosion. 52 1637 0 0.12 46 7 2.94 Line corrosion. Lt. DeDosits. 53 1668 0 0.12 47 7 2.92 Line corrosion. Lt. Deposits. 54 1699 () 0.14 57 8 2.92 Isolated Ditting. 55 1731 () 0.13 50 8 2.90 Isolated Dittin\!. 56 1761 0 0.14 54 6 2.92 Line corrosion. Lt. DeDosits. 57 1792 0 0.15 58 6 2.95 Isolated Ditting. 58 1823 0 0.12 46 6 2.91 Line corrosion. S9 1854 0 0.12 47 6 2.94 Corrosion. 60 1886 () 0.13 52 6 2.94 Isolated Ditting. Lt. DeDosits. 61 1916 0 0.12 46 6 2.90 Isolated pitting. Lt. Deposits. 62 1948 () 0.12 48 6 2.93 Isolated Dittin\!. Lt. DeDosits. 63 1980 0 0.12 46 5 2.94 Isolated Ditting. 64 2011 0 0.15 60 5 2.94 Isolated Dittin\!. 65 2043 () 0.16 64 6 2.94 Isolated Dittin\!. 66 2074 () 0.13 50 5 2.94 Isolated Ditting. 67 2106 0 0.11 43 5 2.94 Isolated Ditting. Lt. DeDosits. 68 2137 () 0.09 37 4 2.95 Isolated Ditting. 69 2166 () 0.13 52 6 2.95 Line corrosion. 70 2198 () 0.11 44 7 2.91 Line corrosion. Lt. Deoosits. 71 2229 0 O.tO 38 7 2.88 Corrosion. Lt. Deposits. 72 2260 () 0.13 50 9 2.87 Line corrosion. Lt. DeDosits. 73 2292 () 0.13 51 4 2.89 Corrosion. 74 2323 () 0.11 43 5 2.92 Isolated Ditting. 75 2354 0 0.11 42 6 2.91 Corrosion. Lt. DeDosits. 76 2385 0 0.09 37 4 2.90 Isolated Ditting. Lt. DeDosits. 77 2417 0 0.09 35 4 2.90 Isolated Ditting. 78 2448 () 0.11 45 4 2.93 Isolated Ditting. 79 2480 0 0.13 49 4 2.93 Isolated Ditting. 80 2511 0 0.10 41 6 2.91 Isolated Dittin\!. 81 2543 0 0.09 35 5 2.90 Isolated Ditting. Lt. DeDosits. 82 2574 () 0.07 28 4 2.89 Isolated pitting. Lt. DeDosits. 83 2604 0 0.08 31 5 2.88 Isolated Ditting. Lt. DeDosits. 84 2635 () 0.08 31 6 2.88 Isolated Ditting. Lt. DeDosits. 85 2666 () 0.08 30 5 2.87 Corrosion. Lt. Deoosits. f------86 2697 0 0.07 28 5- _2.90 Corrosi9n. Lt. D~Rosits.- .~ 87 2728 () 0.08 30 7 2.90 Isolated Dittim!:. Lt. DeDosits. -III 88 2758 (J 0.07 29 3 2.86 Isolated Ditting. Lt. DeDosits. 89 2789 0 0.10 38 3 2.88 Isolated Ditting. Lt. DeDosits. 90 2820 () 0.13 50 4 2.89 Isolated Ditting. Lt. DeDosits. 91 2851 0 0.09 35 3 2.87 Isolated pitting. Lt. Deposits. 92 2883 0 0.14 54 3 2.94 Isolated Dittin\!. 93 2914 0 0.16 64 L 2.92 Isolated pitting. Lt. Deposits. -. ._~ 94 2945 0 0.08 32 4 2.89 Isolated Ditting. Lt. DeDosits. -III IPenetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 EUE 8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 10"32 Kuparuk ConocoPhillips Alaska, Inc. USA October 3, 2004 Joint Jt. Depth Pen. Pen. Pen. Metal 1'v1in. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (%wall) (Ins.) (Ins.) % (Ins.) 0 50 100 95 2975 () 0.11 43 3 2.94 Isolated Dittin\!. 96 3007 0 0.12 46 5 2.92 Isolated Dittin\!. Lt. DeDosits. 97 3038 0 0.07 26 3 2.90 Isolated Dittin\!. Lt. DeDosits. 98 3070 0 0.06 25 2 2.89 Isolated Dittin\!. Lt. DeDosits. 99 3101 0 0.06 23 3 2.92 Isolated nittin\!. Lt. DeDosits. 100 3132 () 0.09 35 3 2.91 Isolated Dittin\!:. 101 3164 0 0.05 19 3 2.87 Shallow nittin\>. Lt. DeDosits. 102 3195 0 0.09 37 2 2.90 Isolated nittin\>. Lt. Denosits. 103 3227 0 0.07 26 8 2.89 Isolated nittin\>. Lt. Denosits. 104 3258 0 0.07 29 3 2.90 Isolated nittin\>. Lt. Denosits. 105 3288 0 0.05 20 5 2.93 Shallow Dittin\!. 106 3319 0 0.08 32 2 2.87 Isolated nittin\!. Lt. DeDosits. 107 3351 0 0.06 22 2 2.91 Isolated Dittin\!:. Lt. DeDosits. 108 3382 0 0.05 21 9 2.90 Isolated Dittin\!:. Lt. DeDosits. 109 3414 0 0.09 37 3 2.89 Isolated Dittin\!:. Lt. DeDosits. 110 3445 0 0.11 44 3 2.91 Isolated nitting. Lt. DeDosits. 111 3477 () 0.06 24 2 2.93 Isolated nittin\!. Lt. DeDosits. 112 3509 0 0.08 30 5 2.90 Isolated nittin\!. Lt. Denosits. 113 3540 () 0.04 17 9 2.85 Shallow Dittin\!:. Lt. Deoosits. 114 3571 0 0.04 17 10 2.91 Shallow Dittin\!:. 115 3603 () 0.05 19 2 2.86 Shallow Dittin\!:. Lt. DeDosits. 116 3634 () 0.04 16 3 2.86 Shallow nitting. Lt. DeDosits. 117 3665 0 0.04 15 6 2.88 Shallow nitting. 118 3694 () 0.05 19 4 2.80 Shallow corrosion. Lt. Denosits. 119 3725 () 0.05 20 2 2.89 Shallow nittin\!. Lt. Denosits. 120 3757 () 0.04 17 8 2.90 Shallow nittin\!:. Lt. Denosits. 121 3788 () 0.05 20 B 2.85 Isolated pitting. Lt. Deposits. -- .. 122 3819 () 0.06 22 7 2.89 Isolated Dittin\!:. Lt. DeDosits. 123 3851 0 0.04 16 9 2.87 Shallow Dittin\!:. Lt. DeDosits. 124 3882 () 0.03 13 6 2.88 Shallow Dittin\!:. Lt. DeDosits. 125 3913 0.05 0.04 15 2 2.88 Shallow nitting. Lt. DeDosits. 126 3943 () 0.04 16 8 2.87 Shallow nittin\!. Lt. DeDosits. 127 3974 0 0.06 22 3 2.89 Isolated nittin\!. Lt. Denosits. 128 4006 () 0.05 21 6 2.91 Isolated nittin\!. Lt. DeDosits. 129 4037 () 0.04 16 5 2.89 Shallow nittin\!. Lt. DeDosits. 130 4068 0 0.03 13 6 2.89 Shallow Dittin\!:. Lt. DeDosits. 131 4100 0 0.04 15 3 2.91 Shallow Dinin\!:. Lt. DeDosits. 132 4131 0 0.04 17 2 2.91 Shallow Dittin\!:. - 133 4162 0 0.04 16 3 2.85 Shallow nittim:o. Lt. Denosits. 134 4192 () 0.04 17 9 2.87 Shallow nittino. Lt. Denosits. 135 4224 () 0.05 18 9 2.91 Shallow Dittin\!. Lt. DeDosits. 136 4255 () 0.03 12 3 2.89 Lt. DeDosits. 137 4286 () 0.07 29 6 2.92 Isolated Dittin\!:. ~ 138 4318 0 0.05 20 8 2.90 Shallow Dittin\!:. Lt. DeDosits. 139 4349 0 0.04 15 2 2.82 Line shallow corrosion. Lt. DeDosits. 140 4379 0 0.06 24 6 2.85 Isolated nittim~.. Lt. DeDosits. 141 4410 0 0.07 29 2 2.88 Isolated nittino. Lt. Denosits. 142 4442 0 0.07 26 3 2.91 Isolated nittim!. Lt. DeDosits. 143 44]3 () 0.04 17 6 2.88 Shallow pitting. p. Deposits. . 144 4504 0 0.04 14 3 2.93 Shallow Dittin\!:. Lt. DeDosits. III IPenetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: Body Waf/: Upset Wall: NominaIID.: 3.5 in 9.3 ppf L-80 WE 8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 10-32 Kuparuk ConocoPhìllips Alaska, Inc. USA October 3, 2004 Joint Jt Depth Pen. Pen. Pen. Metal Min. Dan lage Profile No. (Ft) Upset Body % Loss I.D. Comments (%wall) (Ins.) (Ins.) 'Yo (Ins.) 0 50 100 145 4536 [) 0.05 18 2 2.93 Shallow pitting. Lt Deposits. '" 146 4568 () 0.04 14 2 2.91 Shallow pitting. Lt Deposits. 147 4599 0 0.09 34 4 2.91 Isolated nittinll. Lt Deposits. - 148 4631 () 0.04 16 2 2.87 Shallow nittinll. Lt Deoosits. . 149 4662 0 0.05 20 2 2.86 Lìne shallow corrosion. Lt Deoosits. I'" 150 4694 0 0.03 13 2 2.93 Shallow oittinl!. 151 4726 0 0.06 22 2 2.90 Isolated pitting. '" 152 4757 0 0.06 22 2 2.91 Isolated pittinl!:. Lt. Deposits. 153 4789 () 0.03 11 2 2.89 Lt Deposits. '" 154 4820 0 0.04 17 4 2.87 Shallow pittinl!:. Lt Deposits. ..~ 155 4852 () 0.03 10 6 2.88 Lt Denosits. . 156 4883 0 0.03 12 2 2.91 Lt Deposits. - 157 4915 0 0.04 17 2 2.89 Shallow nittinl!:. Lt. Deoosits. -~ 158 4947 () 0.04 16 2 2.90 Shallow oittinll. Lt Deoosits. -'" 159 4978 0 0.04 14 2 7.89 Shallow pittinl!:. Lt Deposits. - 160 5010 0 0.07 27 2 2.90 Isolated oittinl!:. Lt Deposits. 1'"1'" 161 5041 0 0.04 17 2 2.93 Shallow pittinl!:. Lt Deposits. .'" 162 5072 0 0.04 14 9 2.89 Shallow pittinl!:. Lt Deposits. I" 163 5103 0 0.04 14 2 2.93 Shallow pittinl!:. Lt Deposits. II 164 5135 0 0.04 17 2 2.91 Shallow pittinl!:. Lt. Deposits. . II 165 5167 0 0.04 15 2 2.93 Shallow pittinl!:. Lt. Deposits. 1"111 165.1 5199 0 0.03 10 1 2.89 PUP - 165.2 5204 0 0 0 0 N/A GLM 1 (Latch @ 9:00\ 165.3 5213 0 0.03 12 1 2.89 PUP - 166 5219 () 0.03 12 2 2.94 Lt. Deposits. '" 167 5251 0 0.06 24 2 2.94 Isolated pittinl!:. Lt Deposits. III'" 168 5282 0 0.05 19 2 2.92 Shallow pittinl!:. Lt Deposits. II" 169 5314 0 0.03 12 2 2.94 Shallow nittinll. Lt Denosits. '" 170 5345 [) 0.04 16 5 2.88 Shallow nittinll. Lt. Deposits. .'" 171 5377 0 0.07 27 2 2.90 Isolated pittinl!:. Lt. Deposits. II" 172 5408 n 0.04 16 4 2.90 Shallow pittinl!:. Lt Deposits. ..'" n 173 5440 0 0.04 _17 2 l-9L Shallow pitting. Lt. Deposits. 174 5472 0 0.04 17 2 2.92 Shallow pittinl!:. Lt Deposits. II" 175 5503 0 0.04 14 2 2.92 Shallow pittinl!:. Lt Deposits. 176 5535 0 0.04 17 1 2.92- _~¡'allow pitting. Lt Deposits. . 177 5567 0 0.04 15 2 2.90 Shallow pitting. Lt. Deposits. m. 178 5598 0 0.04 16 6 2.89 Shallow oittinl!:. Lt Deposits. ~ 179 5630 () 0.04 17 2 2.92 Shallowoittinll. Lt Deposits. 180 5661 0 0.06 22 2 2.90 Isolated pittinl!:. Lt Deposits. - 181 5693 0 0.03 11 2 2.93 Lt. Deposits. 182 5725 0 0.05 21 2 2.92 Isolated pittinl!:. Lt Deposits. . 183 5756 0 0.08 33 3 2.91 Isolated pittinl!:. Lt. Deposits. 184 5788 () 0.06 22 3 2.90 Isolated nittinll. Lt Deposits. 185 5819 0 0.06 22 2 2.92 Isolated pitting. Lt Deposits. 186 5851 0 0.04 17 2 2.92 Shallow oittinl!:. Lt Deposits. 187 ,5883 () 0.03 13 n" ,2 _2.92.... Shallow oittinl!:. 188 5915 0 0.09 36 3 2.92 Isolated pittinl!:. Lt Deposits. 189 5946 0 0.07 28 3 2.91 Isolated pittinl!:. 190 59l8n -- 0 0.07 26 3 2.90 Isolatedpitting. Lt Deposits. . 191 6010 0 0.08 31 4 2.92 Isolated nittinl!:. Lt Denosits. I Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaILD.: 3.5 in 9.3 ppf L-80 EUE 8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 10-32 Kuparuk ConocoPhillips Alaska, Ine. USA October 3, 2004 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Dam age Profile No. (Ft.) Upset Body % Loss !.D. Comments (%wall) (Ins.) (Ins.) 'Yo (Ins.) 0 50 100 192 6041 0 0.07 29 3 2.90 Isolated Ditting. Lt. Deposits. - 193 6070 0 0.09 35 4 2.90 Isolated Dittin\!. - 194 6102 0 0.06 24 2 2.90 Isolated Dittin\!. Lt. DeDosits. - 195 6133 0 0.07 26 2 2.91 Isolated Dittin\!. Lt. DeDosits. - 196 6165 () 0.07 28 2 2.92 Isolated Dittimz. Lt. Deposits. - 197 6197 0 0.06 22 2 2.93 Isolated Ditting. Lt. Deposits. - 198 6228 () 0.06 25 2 2.92 Isolated pitting. Lt. Deposits. - 199 6260 () 0.04 16 2 .-2,92 ... 5J!.aJlow pitting. 200 6291 () 0.05 19 2 2.94 Shallow Dittin\!. Lt. DeDosits. - 201 6323 0 0.04 15 3 2.94 Shallow Dittin\!. 202 6355 0 0.04 15 1 2.93 Shallow Dittin\!. Lt. DeDosits. 203 6386 0 0.07 26 2 2.92 Isolated Dittin\!. Lt. DeDosits. 204 6418 () 0.06 24 2 2.90 Isolated Ditting. Lt. Deposits. ... 205 6450 0 0.06 25 3 2.91 Isolated Dittin\!. Lt. DeDosits. 206 6481 () 0.06 22 3 2.92 Isolated Ditting. - 207 6513 0 0.05 19 2 2.91 Shallow pittinl!. Lt. Deposits. . 208 6544 () 0.05 20 2 2.89 Isolated pitting. Lt. Deposits. - 209 6576 0 0.05 20 2 2.91 Shallow pitting. Lt. Deposits. - 210 6607 0 0.04 16 2 2.91 Shallow Dittin\!. Lt. Deposits. . 211 6639 () 0.07 28 2 2.90 Isolated Dittin\!. Lt. DeDosits. - 212 6671 0 0.04 16 2 2.88 Shallow Dittin\!. Lt. DeDosits. 213 6703 () 0.06 22 2 2.89 Isolated Dittin\!. Lt. DeDosits. I'" 214 6734 () 0.05 19 2 2.88 Shallow Ditting. Lt. Deposits. "" 215 6766 () 0.04 14 2 2.88 Shallow pitting. Lt. Deposits. 216 6797 () 0.04 14 2 2.88 Shallow pittinl!. Lt. Deposits. 217 6829 0 0.04 17 2 2.91 Shallow Dittirw. Lt. Deoosits. ~ e---218_. 6860 () 0.06 no. 3 2.92 Isolated Dittin\!. I'" 219 6892 () 0.04 17 2 2.92 Shallow Dittin\!. Lt. DeDosits. ~ 220 6922 0 0.04 16 2 2.87 Shallow Dittin\!:. Lt. DeDosits. 221 6952 () 0.06 25 2 2.89 Isolated Ditting. Lt. Dcposits. "" 222 6983 0 0.05 21 2 2.90 Isolated pitting. Lt. Deposits. "" 223 7014 () 0.05 20 2 2.92 Isolated pitting. Lt. Deposits. "" 224 7046 () 0.06 22 6 2.89 Isolated Ditting. Lt. Deposits. "" 225 7078 () 0.04 14 2 2.89 Shallow Ditting. Lt. Deposits. 226 7109 0 0.04 17 2 2.92 Shallow Dittin\!:. Lt. DeDosits. . 227 7140 0 0.04 17 2 2.87 Shallow Dittiml:. Lt. DeDosits. . 228 7173 0 0.05 19 2 2.92 Shallow Ditting. Lt. Deposits. 229 7204 0 0.07 29 2 2.92 Isolated Ditting. Lt. Deposits. - 230 7234 0 0.05 20 3 2.92 Shallow pitting. Lt. Deposits. - 231 7266 0 0.05 20 2 2.89 Isolated Ditting. Lt. Deposits. - 232 7298 0 0.05 18 2 2.92 Shallow DittiOlI:. Lt. DeDosits. - 233 7329 0 0.06 23 2 2.94 Isolated DittiOl!.. Lt. DeDosits. - 234 7362 () 0.07 28 2 2.92 Isolated Dittin\!:. Lt. DeDosits. - 235 7393 () 0.08 32 2 2.91 Isolated Dittin\!. Lt. DeDosits. 236 7425 0 0.06 23 2 2.92 Line corrosion. Lt. Deposits. 237 7456 0 0.05 18 2 2.91 Shallow pitting. Lt. Deposits. - 238 7488 0 0.06 22 2 2.89 Isolated pitting. Lt. Deposits. - 239 7519 () 0.07 27 2 2.93 Isolated Dittin\!. Lt. DeDosits. - 240 7551 0 0.06 24 2 2.92 Isolated Dittin\!. Lt. DeDosits. - 241 7583 0 0.07 28 2 2.90 Isolated Dittin\!:. Lt. DeDosits. - I Penetration Body Metal Loss Body Page 5 PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 EUE 8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 10-32 Kuparuk ConocoPhillips Alaska, Inc. USA October 3, 2004 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damag e Profile No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins.) (Ins.) 'Yo (Ins.) 0 50 100 242 7614 0 0.08 33 2 2.91 Line corrosion. Lt. Denosits. III 243 7645 0 0.10 39 2 2.92 Isolated Dittin\!. Lt. DeDosits. III- 244 7678 0 0.08 31 2 2.88 Isolated Dittin\!. Lt. Denosits. III 245 7709 0 0.06 25 2 2.93 Isolated nittino. Lt. Denosits. .~ 246 7741 0 0.06 23 2 2.94 Isolated nittino. Lt. Denosits. . 247 7772 0 0.10 39 3 2.92 Line corrosion. Lt. Denosits. . III. 248 7804 0 0.05 20 3 2.92 Shallow nittino. Lt. Denosits. . 249 7835 0 0.08 30 3 2.92 Isolated nittimz. Lt. Denosits. - III 250 7867 0 0.09 35 2 2.93 Isolated nittin\!. - III I 251 7897 0 0.05 18 2 2.93 Shallow nittimz. - 252 7929 0 0.07 28 3 2.94 Isolated Dittinl!:. - II 253 7962 0 0.07 27 2 2.94 Isolated Dittinl!:. 254 7994 0 0.08 31 3 2.94 Isolated Dittinl!:. 255 8025 0 0.09 35 3 2.94 Line corrosion. 256 8057 0 0.07 28 2 7.94 Isolated nittim!. . 257 8088 0 0.09 34 3 2.92 Isolated nittin\!. Lt. Denosits. . 258 8119 0 0.12 47 3 2.92 Isolated nittin\!. Lt. Denosits. 259 8150 () 0.09 34 2 2.92 Isolated nittin\!. Lt. Denosits. .. 260 8183 0 0.12 47 3 2.94 Isolated Dittinl!:. 261 8213 0 0.08 31 2 2.94 Isolated Dittin\!. ... 262 8246 0 0.08 33 3 2.94 Corrosion. Lt. Denosits. ... 263 8276 0 0.10 37 3 2.92 Line corrosion. Lt. Denosits. -. 264 8308 0 0.08 33 3 2.94 Line corrosion. .. 265 8339 0 0.09 35 3 2.91 Line corrosion. ..~ 266 8371 0 0.08 33 3 2.92 Isolated nittin\!. Lt. Denosits. III. 267 8403 0 0.09 35 3 2.94 Line corrosion. . 11.~ _268 8434 0 0.10 39 2 2.94 Line corrosion. . III- III -- III- 269 8466 0 0.08 31 4 2.94 Line corrosion. 270 8496 0 0.09 37 2 2.94 Isolated nittino. Lt. Denosits. -. 271 8528 0 0.10 39 3 2.94 Isolated nittin\!. Lt. Denosits. ... 272 8559 0 0.08 33 4 2.94 Line corrosion. ... 273 8591 0 0.09 34 3 2.92 Line corrosion. Lt. Denosits. . III. 274 8622 0 0.10 41 4 2.93 Isolated Dittinl!:. Lt. Denosits. .. 275 8654 () 0.09 34 3 2.93 Line corrosion. 276 8686 0 0.10 39 4 2.93 Isolated nittin<>. . 277 8716 0 0.09 36 3 2.94 Line corrosion. II 278 8748 0 0.09 34 3 2.92 Isolated nittin\!. Lt. Denosits. II 279 8780 0 0.10 39 3 2.92 Isolated nittin\!. Lt. Denosits. II 280 8812 0 0.13 52 5 2.94 Line corrosion. 281 8844 0 0.08 30 3 2.94 Isolated nittinl!:. Lt. Denosits. III 282 8874 0 0.07 26 3 2.92 Isolated Dittinl!:. ~ 283 8906 0 0.10 40 --~ - _2.94 Line corrosion. II- 284 8938 0 0.09 36 4 2.94 Isolated nittin<>. Lt. Denosits. III I 285 8969 0 0.07 29 2 2.90 Isolated nittin<>. Lt. Denosits. III 286 9000 0 0.09 37 4 2.92 Corrosion. Lt. Denosits. III. 287 9031 0 0.08 31 3 2.93 Corrosion. Lt. Denosìts. III 288 9064 0 0.12 46 3 2.90 Line corrosion. Lt. Denosits. 289 9094 0 0.10 39 4 2.87 Isolated Dittìn\!. Lt. Denosits. . III. 290 9125 0 0.09 36 4 2.9L __Isolated Dittimz.. Lt. DeDosits. - III I 291 9157 0.04 0.08 31 4 2.92 Isolated nittin<>. Lt. Denosits. - III I Penetration Body Metal Loss Body Page 6 PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 EUE 8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 D-32 Kuparuk ConocoPhillips Alaska, Inc. USA October 3, 2004 Joint J1. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (F1.) Upset Body % Loss 1.0. Comments (%wall) (Ins.) (Ins.) 'Yo (Ins.) 0 50 100 292 9189 () 0.09 36 4 2.93 Line corrosion. L1. Deoosits. 293 9220 () 0.07 29 3 2.93 Line corrosion. L1. Deoosits. 294 9253 0 0.09 34 5 2.92 Line corrosion. L1. Deoosits. ,. 295 9284 0 0.08 31 3 2.89 Line corrosion. L1. Deoosits. - 296 9316 0 0.09 37 3 2.90 Line corrosion. L1. Deposits. - 297 9347 0 0.08 31 3 2.89 Isolated pittim!.. L1. Deposits. - 298 9377 () 0.11 43 .5 2.93 Line corrosion. L1. Deposits. - 299 9409 () 0.09 37 3 2.91 Line corrosion. L1. Deposits. - 300 9441 () 0.12 48 4 2.91 Isolated nittim!:. L1. Deoosits. 301 9473 0 0.07 29 4 2.94 Isolated nittin\!:. - 302 9504 0 0.11 44 .5 2.91 Line corrosion. L1. Deoosits. 303 9535 0 0.09 36 4 2.94 Line corrosion. Lt. Deposits. 304 9568 0 0.07 28 4 2.93 Isolated pittim!.. L1. Deposits. 305 9595 0 0.09 34 4 2.92 Line corrosion. L1. Deposits. - 306 9628 0 0.09 34 3 2.93 Line corrosion. Lt. Deposits. "" 307 9659 0 0.10 38 5 2.93 Isolated pitting. L1. Deposits. "" 308 9690 0 0.09 35 4 2.92 Line corrosion. L1. Deposits. "" 309 9722 0 0.07 26 3 2.90 Isolated pitting. L1. Deposits. "" 310 9754 0 0.07 27 4 2.90 Isolated pitting. L1. Deposits. "" 311 9785 0 0.09 34 3 2.90 Isolated nittin\!:. L1. Deoosits. "" 312 9817 0 0.08 30 :3 2.90 Line corrosion. L1. Deposits. I" 313 9848 0 0.10 40 3 2.89 Line corrosion. Lt. Deposits. 314 9879 0 0.08 30 5 2.92 Isolated pitting. L1. Deposits. "" 315 9910 0 0.08 33 6 2.91 Corrosion. L1. Deposits. "" 316 9941 () 0.07 28 6 2.89 Line corrosion. L1. Deposits. "" 317 9972 0 0.09 35 :3 2.88 Line corrosion. Lt. Deuosits. II 318 10004 0 0.09 34 4 2.87 Line corrosion. L1. Deposits. "" 319 10035 0 0.07 29 6 2.87 Line corrosion. L1. Deoosits. I" 320 10066 0 0.08 30 5 2.90 Line corrosion. L1. Deposits. 321 10098 0 0.09 35 :3 2.88 Line corrosion. L1. Deposits. II 322 10129 0.07 0.09 35 8 2.90 Isolated pitting. L1. Deposits. II 323 10161 0 0.09 35 4 2.86 Line corrosion. L1. Deposits. II 324 10189 () 0.10 40 7 2.86 Corrosion. L1. Deposits. "" 325 10220 0 0.08 31 4 2.85 Line corrosion. L1. Deposits. 326 10252 0 0.09 35 5 2.86 Line corrosion. Lt. Deoosits. 327 10284 0 0.08 30 7 2.82 Line corrosion. L1. Deposits. 328 10315 0 0.11 42 5 2.87 Line corrosion. L1. Deposits. ,. 329 10346 0 0.09 36 8 2.83 Line corrosion. L1. Deposits. - 330 10377 0 0.11 43 9 2.87 Line corrosion. L1. Deposits. 331 10409 0 0.11 44 6 2.88 Line corrosion. L1. Deposits. 332 10440 0 0.10 39 7 2.86 Line corrosion. L1. Deoosits. - 333 10470 0 0.12 45 7 2.82 Line corrosion. Deoosits. 334 10500 () 0.10 39 6 2.88 Line corrosion. L1. Deposits. - 335 10531 D D.ll 43 7 2.86 Line corrosion. L1. Deposits. 336 10563 0.06 D.12 49 8 2.87 Line corrosion. L1. Deposits. 337 10593 0.07 0.12 45 7 2.87 Line corrosion. L1. Deposits. 338 10624 0.06 0.15 59 B 2.89 Line corrosion. L1. Deposits. 339 10656 O.Og 0.13 51 6 2.85 Line corrosion. L1. Deposits. 340 10686 D 0.13 52 8 2.79 Line corrosion. L1. Deposits. 341 10718 () 0.14 57 .5 2.92 Line corrosion. L1. Deposits. IPenetration Body Metal Loss Body Page 7 PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 EUE 8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 10-32 Kuparuk ConocoPhillips Alaska, Inc. USA October 3, 2004 I Joint . Jt. Depth Pen. Pen. Pen. Metal Min. I Damage Profile I No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) 'Yo (Ins.) 0 50 100 342 10750 0.08 0.14 55 5 2.89 Line corrosion. Lt. Deoosits. 343 10Z~ L-() 0.13 52_- ~... 2.91 Corrosion. Lt. Deposits. 344 10812 0 0.13 52 4 2.90 Line corrosion. Lt. Deoosits. 345 10845 0.D5 0.09 34 (, 2.88 Line corrosion. Lt. Deoosits. 346 108ì7 D 0.11 41 6 2.84 Line corrosion. Lt. Deposits. 347 1D907 0 0.11 42 7 2.84 Line corrosion. Lt. Deposits. 348 10937 0.06 0.10 40 8 2.89 Isolated pittim!. Lt. Deposits. 349 10968 0.D7 0.12 47 6 2.91 Isolated pittin\!.. Lt. Deposits. 350 10999 D.D6 0.09 34 5 2.90 Isolated pittin\!.. Lt. Deoosits. 351 11029 0 0.14 56 7 2.88 Line corrosion. Lt. Deposits. 352 11059 0 0.12 49 8 2.86 Line corrosion. Lt. Deposits. 353 11092 0.07 0.13 52 7 2.85 Line corrosion. Lt. Deposits. 354 11124 0 0.16 61 6 2.83 Line corrosion. Lt. Deposits. 355 11154 0.05 0.13 51 8 2.86 Line corrosion. Lt. Deposits. 356 11185 0 0.13 49 5 2.87 Line corrosion. Lt. Deposits. 357 11218 0.09 0.13 50 9 2.87 Line corrosion. Lt. Deposits. 358 11247 a 0.11 45 6 2.81 Line corrosion. Lt. Deposits. 359 11279 0.10 0.14 55 7 2.85 Line corrosion. Lt. Deposits. 360 11308 D.06 0.13 51 9 2.83 Line corrosion. Lt. Deposits. 361 11338 0 0.19 74 15 2.87 Line corrosion. Lt. Deposits. 362 11369 0.14 0.17 69 9 2.88 Line corrosion. Lt. Deposits. 363 11400 0.13 0.14 55 9 2.90 Line corrosion. Lt. Deposits. 364 11432 0 0.14 54 9 2.85 Line corrosion. Lt. Deposits. 365 11462 0.07 0.16 64 13 2.87 Line corrosion. Lt. Deposits. 366 11493 0 0.18 69 12 2.89 Line corrosion. Lt. Deposits. 367 11525 0 0.18 72 11 2.86 Line corrosion. Lt. Deoosits. .... 368 11557 -- 0 0.14 ~ --LL. 2.87 Line corrosion. Lt. J)eposits. 369 11585 0 0.15 59 12 2.87 Line corrosion. Lt. Deposits. 370 11617 0.12 0.18 70 13 2.89 Line corrosion. Lt. Deposits. 371 11648 0.09 0.20 80 11 2.86 Line corrosion. Lt. Deposits. 372 11678 D 0.15 61 14 2.84 Line corrosion. Lt. Deposits. 373 11 709 0.12 0.20 77 13 2.81 Line corrosion. Lt. Deposits. 374 11740 0.11 0.20 ì7 15 2.87 Line corrosion. Lt. Deposits. 375 11771 0.10 0.13 52 11 2.85 Line corrosion. Lt. Deposits. 376 11802 0 0.17 65 14 2.87 Corrosion. Lt. Deposits. 377 11833 0.13 0.16 65 13 2.87 Line corrosion. Lt. Deposits. 378 11865 D.l0 0.19 74 16 2.86 Corrosion. Lt. Deposits. 379 11895 0 0.17 67 16 2.78 Corrosion. Denosits. 380 11926 0.12 0.17 69 8 2.87 Line corrosion. Lt. Deposits. 381 11958 0.07 0.20 79 11 2.85 Line corrosion. Lt. Deposits. 382 11990 0.10 0.20 79 13 2.91 Line corrosion. Lt. Deposits. 383 12019 0 0.21 82 10 2.89 Line corrosion. Lt. Deposits. 384 12052 D.l] 0.17 68 13 2.89 Line corrosion. Lt. Deposits. 385 12082 0.D7 0.17 67 12 2.86 Line corrosion. Lt. Deposits. 386 12114 0.05 0.18 72 12 2.90 Line corrosion. Lt. Deposits. 387 12143 D.ll 0.20 77 14 2.89 Line corrosion. Lt. Deposits. 388 12175 0.08 0.18 70 12 2.81 Line corrosion. Deposits. 389 12204 o.on 0.20 78 13 2.89 Line corrosion. Lt. Deposits. 390 12236 0 0.20 80 13 2.87 Line corrosion. Lt. Deposits. 391 12266 0.06 0.16 65 12 2.83 Line corrosion. Deposits. IPenetration Body Metal Loss Body Page 8 PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 WE 8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 10-32 Kuparuk ConocoPhillips Alaska, (nc. USA October 3, 2004 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damag e Profile No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 392 12298 0.12 0.17 68 13 2.83 Line corrosion. Lt. Deposits. 393 12330 0.06 0.16 65 9 2.84 Line corrosion. Lt. Deposits. 394 12362 0.03 0.16 64 13 2.77 Line corrosion. Denosits. 395 12394 0.0/\ 0.17 67 11 2.84 Line corrosion. Lt. Dellosi!~~. 396 12424 0 0.17 66 11 2.87 Line corrosion. Lt. Deposits. 397 12457 0.15 0.18 69 12 2.82 Line corrosion. Lt. Deposits. 398 12488 0.13 0.18 70 13 2.82 Line corrosion. Lt. Deposits. 399 12519 0.14 0.16 61 13 2.79 Line corrosion. Deposits. 400 12551 0.11 0.16 62 11 2.80 Line corrosion. Lt. Denosits. 401 12582 0.07 0.16 61 13 2.78 Line corrosion. Denosits. 402 12611 O.OS 0.16 64 13 2.72 Line corrosion. Lt. Deposits. 403 12642 0 0.12 47 9 2.81 Line corrosion. Lt. Deposits. 404 12673 0 0.12 49 13 2.75 Line corrosion. Deposits. 405 12705 0.09 0.14 57 9 2.84 Line corrosion. Lt. Deposits. 406 12736 0.07 0.14 54 8 2.78 Line corrosion. Lt. Deposits. 407 12766 O.Oì 0.17 68 10 2.83 Line corrosion. Lt. Deposits. 408 12796 0 0.17 65 13 2.83 Line corrosion. Lt. Deposits. 409 12828 0 0.18 70 13 2.85 Line corrosion. Lt. Denosits. 410 12859 0.11 0.17 66 14 2.84 Line corrosion. It. Deposits. 411 12888 0.11 0.15 59 12 2.88 Line corrosion. It. Deposits. --. . 412 12920 0.09 0.14 57 17 2.87 Corrosion. Lt. Deposits. 413 12952 0.10 0.16 64 14 2.80 Line corrosion. Lt. Deposits. 414 12983 0.08 0.15 59 13 2.83 Line corrosion. Lt. Deposits. 415 13015 0 0.18 71 13 2.79 Line corrosion. Lt. Deposits. 416 13045 0.10 0.15 61 15 2.82 Corrosion. Lt. Deposits. , 417 13076 0.11 0.17 67 17 2.80 Line corrosion. Lt. Denosits. . 418 13107 0 0.14 54 9 2.81 Line corrosion. Lt. Denosìts. 418.1 13136 0 0.02 8 1 2.86 PUP Lt. Deposits. I 418.2 13141 0 0 0 0 2.81 DS NIP 418.3 13142 0 0.03 12 1 2.87 PUP Shallow pittim!:. Lt. Deposits. 419 13149 0 0.17 69 15 2.79 Line corrosion. Lt. Deposits. 419.1 13181 0.11 0.15 57 10 2.86 PUP Corrosion. Lt. Deposits. 420 13186 0 0.06 23 6 2.72 Isolated pitting. Deposits. - 420.1 13222 0 0 0 - 0 5.00 PACKER 420.2 13231 D 0 0 0 3.00 SEAL ASSY. 421 13236 D.06 0.19 76 15 2.84 Line corrosion. Lt. Deposits. 421.1 13264 0 0 0 0 2.75 XN NIP 422 13272 0.09 0.13 50 18 2.87 Line corrosion. Lt Deposits. 423 13303 0.09 0.17 69 15 2.82 Line corrosion. Lt. Deposits. 424 13334 D.l0 0.19 73 19 2.89 Line corrosion. Lt. Deposits. 425 13367 D 0.17 67 20 2.74 Corrosion. Denosits. 426 13400 0.11 0.18 72 19 2.84 Line corrosion. Lt. Deposits. 427 13429 0 0.21 84 17 2.78 Corrosion. Deposits. 428 13459 0.09 0.16 63 15 2.78 Line corrosion. Deposits. ~--- -- 429 13492 0.15 0.17 68 20 2.86 Line corrosion. Deposits. 430 13523 0.11 0.18 72 18 2.88 Line corrosion. Lt. Denosits. 431 13559 0.11 0.20 78 19 2.82 Line corrosion. Deposits. 432 13592 0 0.26 tOO 19 2.71 Hole! 433 13621 (J.l ß 0.22 87 2D 2.79 Possible Hole! 434 13652 0.14 0.17 69 17 2.72 Corrosion. Deposits. IPenetration Body Metal Loss Body Page 9 PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 EUE 8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 10-32 Kuparuk ConocoPhillips Alaska, (nc. USA October 3, 2004 Joint )t. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (Ins.) (Ins.) '}'o (Ins.) 0 50 100 435 13681 0.09 0.21 82 21 2.80 Corrosion. Lt. De osits. 436 13714 0.09 0.18 72 21 2.78 Corrosion. De osits. 437 13747 0 0.22 85 18 2.78 Possible Hole! 438 13779 0.20 0.22 86 16 2.85 Possible Hole! 439 13811 0.09 0.20 77 19 2.77 Corrosion. De osits. 440 13842 0.07 0.20 80 19 2.73 Corrosion. De osits. 441 13877 0 0.19 74 17 2.85 Line corrosion. Lt. De osits. I Penetration Body Metal Loss Body Page 10 <!as. Well: Field: Company: Country: Tubing: PDS Report Cross Sections 10-32 Kuparuk ConocoPhillips Alaska, Inc. USA 3.S ins 9.3 ppf L-BO EUE 8RD Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: October 3, 2004 MFC 24 No. 00387 1.69 24 M. Lawrence .- Cross Section for joint 432 at depth 13618.62 ft Tool speed = S5 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 86 % Tool deviation = 76 0 Finger 6 Penetration = 0.259 ins Hole! 0.26 ins = 100% Wall Penetration HIGH SIDE = UP Cross Sections page 1 Q. Well: Field: Company: Country: Tubing: PDS Report Cross Sections 10-32 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 pQf L-80 EUE 8RD Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: October 3,2004 MFC 24 No. 00387 1.69 24 M. Lawrence Cross Section for joint 433 at depth 13636.78 ft Tool speed = 54 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 89 % Tool deviation = 75 0 Finger 21 Penetration = 0.22 ins Possible Hole! 0.22 ins = 87% Wall Penetratìon HIGH SIDE = UP Cross Sectìons page 2 ,I cJrk Well: Field: Company: Country: Tubing: PDS Report Cross Sections 10-32 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ¡mf L-80 EUE 8RD Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: October 3, 2004 MFC 24 No. 00387 1.69 24 M. Lawrence Cross Section for joint 435 at depth 13683.09 ft Tool speed = 56 NominallD = 2.992 Nominal OD = 3.500 Remaining wall area = 79 % Tool deviation = 72 c' Finger 1 Penetration = 0.039 ins Co~rosion 21% Cross-Sectional Wall Loss HIGH SIDE = UP Cross Sections page 3 cIas. Well: Field: Company: Country: Tubing: PDS Report Cross Sections 10-32 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 EUE 8RD Survey Date: Tool Type: Tool Size: No. of Fingers: Anal~. October 3, 2004 MFC 24 No. 00387 1.69 24 M. Lawrence Cross Section for joint 432 at depth 13613.89 ft Tool speed = 51 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 88 % Tool deviation = 71 0 Finger 18 Projection = -0.357 ins Deposits Minimum 1.0. = 2.71 ins HIGH SIDE = UP Cross Sections page 4 .PHlllIPS Alaska, Inc. ~ A SUbsidiary of PHILLIPS PETROLELt.1 COMPANY NIP (533-534, 00:3.500) TUBING (0-13255, 00:3.500, 10:2.992) GasUl! landreliOlmmy Valve 1 (5230-5231, 00:5.968) NIP (13172-13173, 00:3.500) PACKER (13190-13191, 00:7.000) SBE (13210-13211, 00:6.000) SEAL (13218-13219, 00:4.000) NIP (13268-13269, 00:3.5OO} HPBD (13814-13944) Perf (13870-13880) Perf (13904-13944) LINER (13183-14136, 00:3.500, Wt:9.30) .. === - ,---- ~ ~ 11>-32 API: 500292298200 SSSV Tvoe: NIPPLE Annular Fluid: Reference LOQ: Last Tag: 14106 LaslTag Date: 4/3012001 Casing String - ALL Description SURF CASING PROD CASING CONDUCTOR LINER TubinG StrinG. TUBING Size I Top 3.500 0 Perforations Summarv Interval TVD 13814 - 13824 6535 - 6540 13870 -13880 6559 - 6564 6574 - 6592 C-3,C-2,C-1 Comment Stimulations & Treatments Interval Date I 13814 - 13944 5/512001 HPBD Gas Lift MandrelsNaives St I MD I TVD I ':.~ :v: I YMfr I V Type I VODTLatCh] Port I TRO I ~: I C~~ 115230131851CAMCO MMG CAMCO I DMY 1.5 T RK 10.000 I 0 15/4120011 (1) 1. Test fA to 3000# Okav Other plugs, equip., etc. - JEWELRY Depth TVD Type 533 533 NIP 13172 6268 NIP 13190 6276 PACKER 13210 6284 SBE 13218 6287 SEAL 13268 6307 NIP 14134 6678 SHOE 13904 - 13944 KRU 1 D-32 Well Tvoo: INJ aria Comoletion: 12/4/2()()0 LastW/O: Ref LOQ Date: TD: 14138ftKB Max Hole Anole: 76 deo (W 6440 Anole (å) TS: 65 dea (W 13803 Anole (w TD: 63 deg @ 14138 Rev Reason: HPBD by ImO- Last Update: 21712002 Size 9.625 7.000 20.000 3.500 Bottom 9006 13324 117 14136 TVD 4577 6330 117 6679 Grade Thread L-80 BTCM J-55 BTC MOD H-40 .WELDED L-80 SLHT Wt 40.00 26.00 91.50 9.30 Top 0 0 - 0- 13183 I Bottom I 13255 1 I Wt I Grade I 1 9.30 I L~O 1 Thread EUE 8RD TVD 6302 Zone C-4 Status Ft SPF Date 10 4 5/212001 Twe Comment IPERF 2.5" HSD,DP,3IJUJ, 60 deg oh IPERF 2.5" HSD,DP,3IJUJ, 60 deg ph IPERF 2.5" HSD,DP,3IJUJ, 60 deg oh C-3 5/2/2001 10 4 40 4 5/1/2001 Twe I DescriDtlon Cameo 'DS' Nioole w/2.875" No-Go orofile Camco'DS' Nioole w/2.812" No-Go orofile Baker 5 x 7" ZXP Liner Too Packer w/5" TKC Counlinn Baker SBE '80-40' 4" ID wffKC Couplinos & XO Baker 35' GBH-22 Seal Assembly 'XN' Nioole w/2.75" No-Go Baker Float Shoo ID 2.875 2.812 5.000 4.000 3.000 2.750 0.000 RE: I 0-32 ~lITIA Subject: RE: 10-32 MITlA From: NSK Problem \Vell Sup\' <n 1617(@conocophillips.com> Date: tvlon. 26 Jul 200409:07:02 -0800 To: Thonlas l'ilaunder <tom_maunder(@adn1in.state.ak.us> ç)Oé)- \'\ ~ Tom: Nina has left the slope so you have to communicate with me! I know that isn't as fun-- 10-32 is being prepped for a CTD sidetrack. The over the next 2-3 months are IC-08, IY-24, lD-3 the first two are approved so the list could ch have planned & IF-18. Onlj' t shorter. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message----- Prom: Thomas Maunder [m~11tQ:[om_maunder0admln.~t~te.~~.us] Sent: Monday, July 26, 2004 6:55 AM To: NSK Problem Well Supv Subject: Re: 10-32 MITIA Nina, Long time no wrice. With regard to this Thanks, Tom MIT, what is the coil work?? NSK Problem Well Supv wrote: The attached file contalns data for an MITIA on 10-32 from 7/24/04. «MIT KRU ID-32 7-24-04.xls» Thanks, Nina Woods Problem Well Supervlsor ConocoPhillips Alaska (907) 659-7224 I of 1 7/28/200-1 7:33 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email toWinton_Aubert@admin.stateak.us.Bob_Fleckenstein@admln.stateak.us;Jim_Regg@admln.stateak.us OPERA TOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. 10 07/24/04 APC - Arend, Brake n/a Pretest Initial 15 Min. 30 Min. 1,600 1.600 1.600 1,600 Interval 0 30 2.500 2,480 2,470 P/F P OA: 450/450/450 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: Packer Depth Well 10-32 Type In]. S TVD 6.427' Tubing P.T.D. 2001730 Type test P Test psi 2500 Casing Notes: Pressure test conducted for Pre-Coil Tubing Drilling Operations. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 2004-0724_MIT _KRU_1 D-32.xls Permit to Drill 2001730 MD 14138 ~-~ 'I'VD DATA SUBMITTAL COMPLIANCE REPORT 61212003 Well Name/No. KUPARUK RIV UNIT 1D-32 Operator CONOCOPHILLIPS ALASKA INC 6679 ,'/ Completion Dat 5/1/2001 f Completion Statu 1WINJ Current Status 1WINJ APl No. 50-029-22982-00-00 UlC Y REQUIRED INFORMATION Mud Log No Sample N__9o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt ~.,,,-' Log Log Run Name Scale Media No Interval Start Stop 8976 14082 (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments Case 9/18/2001 (~'0299 8976-14082 Directional Survey Directional Survey Directional Survey MWD Directional Survey MWD Cement Bond Log with PSP/SCMT 10298 10299 LIS Verification Bottom Hole Pressure Press/Tem FINAL FINAL FINAL FINAL 8975 14089 Case FINAL 13100 14063 ch FINAL 8975 14089 CH FINAL 8976 14082 CH FINAL CH FINAL 13060 14049 ch 9/18/2001 2/22/2001 2/22/2001 2/22/2001 2/22/2001 6/1/2001 9/18/2001 9/18/2001 9/18/2001 5/15/2001 /-I~298 (.1.0298 "112)299 8975-14089 Dir Survey Digital Data Dir Survey Paper Copy MWD Dir Survey Digital Data MWD Dir Survey Paper Copy .--fl-3100=14063 Color Print 8975-14089 Digital Data 8976-14082 Digital Data LIS Verification 13060-14049 BL, Sepia Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis RP.c~.iv~.d ? Daily History Received? ¢/N Formation Tops ¢ N Permit to Drill 2001730 DATA SUBMITTAL COMPLIANCE REPORT 612/2003 Well Name/No. KUPARUK RIV UNIT 1D-32 Operator CONOCOPHILLIPS ALASKA INC APl No. 50-029-22982-00-00 MD 14138 TVD 6679 Completion Dat 5/1/2001 Completion Statu 1WINJ Current Status 1WINJ UIC Y Comments: Compliance Reviewed By: Date: Annular Disposal during the first quarter of 2002: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 2P-417 25534 100 0 25634 887 5431 31952 October March 2P-448, 2P-422A, Grizzly gl, 2001 2002 2P-451, 2P-441, 2P-420 CD2-'i4 16138 100 0 16238 376 14459 31073 November March CD2-32, CD2-47, CD2-45 2001 2002 1C-14 9626 100 0 9726 0 22489 32215 October January 1R-36, 1C-24, 1C-109 2001 2002 CD2-15 10346 100 0 10446 371 0 10817 March March CD2-50 2002 2002 CD2-47 16459 100 0 16559 375 10415 27349 December January CD2-34, CD2-26, 2001 2002 CD2-45 22514 100 0 22614 377 0 22991 January February CD2-49, CD2-17 2002 2002 2P-415A 4843 100 0 4943 52 0 4995 March March Grizzly #1, 2P-431, 2P-441 2002 2002 CD2-26 0 0 0 0 380 0 380 .... Freeze protect only for CD2-26 CD2-49 0 0 0 0 386 0 386 Feb 2002 Feb 2002 Freeze protect only Total Volumes into Annuli for which Disposal Authorization Expired during the first quarter 2002: Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 1D-32 23162 100 0 337 23599 Open, Freeze Protected January February 1D-39 2001 2001 1J-03 30024 100 0 0 30124 Open, Freeze Protected March 2001 May 2001 1J-09, 1J-14, 1J-10 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 17, 2001 RE: MWD Formation Evaluation Logs 1D-32, AK-MM-00259 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-.Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1D-32: Digital Log Images 1 CD Rom RECEIVED SEP 1 8 2001 ~m Oil & Gas Cons. Commission An~orage WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7t~ Avenue, Suite 100 Anchorage, Alaska September 14, 2001 MWD Formation Evaluation Logs 1D-32, AK-MM-00259 1 LDWG formatted Disc with verification listing. APl#: 50-029-22982-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 RECEIVED 5/30/2001 Schlumberger NO. 1178 Schlumberger Technology Corporation, by and through is Geoquest DiviSion 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie ComPany: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1B-01 I~'O-/.)~D LEAK DETECTION LOG 05/16101 1B-01 J/' LEAK DETECTION LOG 05118101 I 1 1B-11 I~!.-I._.%~ LEAK DETECTION LOG 05117101 1 1 1D-121 )°]'7-1~'/ TEMPIPRESSIDENSITY SURVEY 05119101 I 1 1D-135 C-~D-~ TEMPIPRESSIDENSITY SURVEY 05119/01 I 1 =^.~ ~./~,/- ,~^~,~?~c?,o,,o~ 3F-21~ D~)-,~D~ PRESSURE SURVEY 05111101 I 1 1D-37~Oi~-1'7,~ 21224 SCMT 04124101 1 2A-15/~'~-/q~ 21223 USIT 04123101 1 2P-417~/~z~c~ 21243 FRACADE ADVISOR 05112/01 1 r'",-- CEiVI D s,~.,.. ~~-~~~ ~_ _~--- .^~,: JUN01 2001 A~a~l&~~s.~~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 661-8317. Thank you. AI1Ctl01~O 5/8/2001 Schlumberger NO. 1117 Schlumberger TechnOlogy Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Field: Sepia Kuparuk ColOr Print 1 D-32 ~O~:>-(7,~ STATIC BHP 06/02/01 I 1 1D-40A ~ oo-Ic~O 21147 SCMT 03/10101 1 1R-29 14/I-0,~~ 21205 USIT 04115101 1 . ; . RECEIVED DATE: UAV 4 ~ q~ft,I I-I~"~t ! ~,1 LVUI Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317.~flTfa'#k~b'ff.° Anchorage MEMORANDUM TO: Julie Heusser Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 11, 2001 · SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~/.L'~U,~¢.~ Phillips P.I. Supervisor/.~z'~r ,-~,-- ,,.... 1D Pad 't~''O~, 1 D-32, 1 D-39, 1 D-40A FROM: Chuck Scheve KRU Petroleum Inspector Kupamk NON,~ CONFIDENTIAL Packer Pretest Initial 15 Min. 30 Min. 200-190 Notes: Notes: Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to 1D Pad in the Kuparuk river field and witnessed the initial MIT on wells 1D-32, 1D-39 and 1D-40A. The pretest pressures were observed and found to be stable. A standard annulus pressure test was then performed with all 3 wells demonstrating good mechanical integrity. M.I.T.'s performed: _3 Attachments: Number of Failures: 0 Total Time during tests: 3 houm, C.C.: MIT report form 5/12/00 L.G. MIT KRU 1-D Pad 5-11-01 CS 5/18/01 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 April 24, 2001 RECEIVED APR ?., 5 2.00t Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, First Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the first quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the first quarter of 2001. PleaSe call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files 'zo o - loo 7oo-101, Annular Dis ¢osal during the first quarter of 2001: ' h(1) - h~(2) ' h(3~ Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date CD1-44 8929 100 0 9029 22899 31928 Dec. '00 Jan.'01 cm-33, COl-NQ1, COl-10, c01-28 2N-318 12276 100 0 12376 1619 13995 Dec.'00 Jan.'01 2N-314 CD1-43 30552 100 0 30652 385 31037 Jan.'01 Feb.'01 CD1-NQ1, CD1-21 CD1-31 6698 100 0 6798 392 7190 Feb.'01 Mar.'01 CDI-14 1D-42 17187 100 0 17287 15118 32405 Dec.'00 Jan.'01 1D-37, 1D-39 ., 1D-32 23162 100 0 23262 337 23599 Jan.'01 Feb.'01 1D-39 1J-03 13020 100 0 13120 0 13120 Mar.'01 Mar.'01 1J-09~ 1J-14 Total Volumes into Annuli 3r which Disposal Authorization Expired during the first quarter 2001: ~ ' Total Voiume ~ ~ ' Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus 1L-28 9837 100 0 9937 Open, Freeze Protected March 2000 April 2000 1L-20A, 1L-26A CD1-27 32714 100 0 32814 Open, Freeze Protected May 2000 June 2000 CD 1-44, CD 1-19A, CD 1-09, CD 1-06 CD1-38 20220 100 0 20320 Open, Freeze Protected March 2000 May 2000 CD 1-44, CD 1-41, CD 1- 19A CD1-05 286 100 0 386 Open, Freeze Protected Jan. 2000 Jan. 2000 CD1-05 CD1-03 33890 100 0 33990 Open, Freeze Protected Aug. 2000 Sept. 2000 CD1-43, CD1-31, CD1-~ 30 2'~0- O~ _ PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 May 11,2001 Commissioner Cammy Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 1D-32 (200-173) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kupamk well 1D-32. If you have any questions regarding this matter, please contact me at 265-6434 or Todd Mushovic at 265-6974. Sincerely, J. Trantham Drilling Engineering Supervisor PA1 Drilling JT/skad RECEIVED MAY 1 5 ZOO1 Alaska 0il & Gas Cons. Commission Anchorage WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil E] Gas BI Suspended F~ Abandoned E] service [~] [~,.¢--~.-----.-. Produced Water Injector 2. Name of Operator l~]'lOfqS t 7. Permit Number Phillips Alaska, Inc. ,~.,~i~ ~~ ' .¢:;D 200-173 3. Address :; ~a~_.~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ;'~~'k~ 50-029-22982-00 4. Location of well at surface ....... .. ~ 9. Unit or Lease Name 417' FNL, 420' FEL, Sec. 23, Tll N, R10E, UM (ASP: 560671, 5959249) i Kuparuk River Unit : ~" . 10. Well Number At Top Producing Interval-- ~ -,_- ..._. ~. L~./~'.c.~ 2404' FSL, 1630' FWL, Sec. 30, T11N, R11E, UM (ASP: 568068,5951576) -. . ..... 1D-32 At Total Depth .... '-/'~--i.._ _ i 11. Field and Pool 2146' FSL, 1789' FWL, Sec. 30, T11 N, R11E, UM (ASP: 568230, 5951318) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 34 feetI ADL 28248/25650 ALK 591 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions November 9, 2000 November 30, 2000 D~¢,~ ,..~J::::, I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 14138' MD/6679' TVD 14101' MD/6662' TVD YES [~] No r-~I N/A feet MD 1775' 22. Type Electric or Other Logs Run GR/Res/Neu Dens, SCMT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 130' 30" 15 cu. Yards, ABI, type III 9.625" 40# L-80 Surface 9005' 12.25" 490 sx AS III, 450 sx LiteCRETE 7" 26# J-55 Surface 13324' 8.5" 190 sx Class G 3.5" 9.3# L-80 13183' 14136' 6.125" 225 sx Class G 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" 13255' 13191' 13904'-13944' MD 6574'-6592' TVD 4 spf 13870'-13880' MD 6559'-6564' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13814'-13824' MD 6535'-6540' TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED HPBD: see attachment 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. RECEIVED N/A f AY 1 5 Z001 Alaska 0il & Gas Cons. Commission Anchorage , Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit Ir~ duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 13799' 6529' Base Kuparuk C 13964' 6601' RECEIVED Top Kuparuk A 14138' 6679' Base Kuparuk A 14138' 6679' Alaska 0il & Gas Cons. Commission Anchorage Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following Is true and correct to the best of my knowledge. Questions? Call Todd Mushovic 265-6974 Signed ~;~/J Title Ddllln,q E n,qineerln.q Supervisor Date J. Trantham i~:~ti~. ~~,~--,.,~..~ ~__~.2./~ ;.~L..~¢~ Prepared by Sharon AIIsup-Dral(e INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1'- Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5'- Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24.' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 01/12/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:ID-32 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:il/09/00 START COMP: RIG:NABORS 16E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22982-00 11/08/00 (D1) MW: 8.6 VISC: 210 PV/YP: 17/31 APIWL: 10.4 TD/TVD: 130/6399 ( 130) DRILLING @ 354' SUPV:G.R. WHITLOCK Move rig to 1D-32. Rig accepted on 1D-32 @ 1200 hrs 11/8/00. Hold pre-spud meeting. RIH w/BHA tag @ 130' 11/09/00 (D2) MW: 9.6 VISC: 238 PV/YP: 28/39 TD/TVD: 1638/1600 (1508) DRILLING @ 2100' SUPV:G.R. WHITLOCK Drill from 130' to 1638' APIWL: 6.8 11/10/00 (D3) MW: 9.7 VISC: 280 PV/YP: 30/56 APIWL: 6.5 TD/TVD: 2470/2027 ( 832) CIRC AND WAIT ON WEATHER SUPV:G.R. WHITLOCK Drill from 1638' to 2027'. CBU. Circ slow. Phase III conditions. 11/11/00 (D4) MW: 9.6 VISC: 215 PV/YP: 32/41 · APIWL: 5.8 TD/TVD: 3075/2285 ( 605) DRILLING @ 3600' SUPV:G.R. WHITLOCK Circ slow and wait on weather to moderate and fill water tanks. Drill from 2470' to 3075' 11/12/00 (D5) MW: 9.7 VISC: 208 PV/YP: 38/46 APIWL: 5.6 TD/TVD: 4210/2767 (1135) DRILLING @ 4750' SUPV:G.R. WHITLOCK Drill from 3075' to 4059' Pump sweep and circ until hole clean. POOH wet. tight spots. RIH. Bridges @ 1180', 3136', 3234', 3790'. RIh to 4059' Circ hole clean. Drill from 4059' to 4210' 11/13/00 (D6) MW: 9.7 VISC: 228 PV/YP: 41/52 TD/TVD: 6090/3463 (1880) POOH FOR BIT CHANGE SUPV:G.R. WHITLOCK Drill from 4210' to 6090' APIWL: 5.4 11/14/00 (D7) TD/TVD: 6090/3463 ( SUPV:FRED HERBERT MW: 9.7 VISC: 235 PV/YP: 42/51 0) DRILLING @ 6700' APIWL: 5.2 Drilling 12.25" hole from 6090' to 6317'. Finish circ sweep out of hole. Drilling 12.25" hole from 6317' to 6387'. Circ sweep around, circ hole clean. Monitor well. POOH 5 stands, pump dry job. Continue to POOH slow to prevent swabbing. Swabbed 2850' to 2660'. RIH slow. Circ bottoms up. drilling Date: 01/12/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 12.25" hole from 6387' to 6414'. Lost 92 MP. Work on problems. 11/15/00 (D8) MW: 9.8 VISC: 195 PV/YP: 46/61 APIWL: 4.0 TD/TVD: 7906/4136 (1816) DRILLING AHEAD @ 8120' SUPV:FRED HERBERT Work on SCR's for 92 MP. Cable to power supply broken & burnt @ connector. Drilling 12.25" hole from 6414' to 7906'. Pump sweep around and circ hole clean. POOH. 11/16/00 (D9) MW: 9.6 VISC: 216 PV/YP: 43/61 APIWL: 4.2 TD/TVD: 9017/4580 (1111) WIPER TRIP FOR CASING RUN SUPV:FRED HERBERT POOH to 6320'. No hole problems. RIH to bottom. Circ bottoms up. Drilling 12.25" hole from 7906' to 9017' Pump densified sweep, circ hole clean for wiper trip. 11/17/00 (D10) TD/TVD: 9017/4580 ( SUPV:FRED HERBERT MW: 0.0 VISC: 216 PV/YP: 0/ 0 0) RUN 9-5/8" CASING APIWL: 0.0 Pump dry job & POOH to HWDP. RIH to bottom. Circ & cond mud for casing run. Mud thick until bottoms up, circ & reduced rate. Pump sweep cond ud. Monitor well. POOH slow to prevent swabbing. 11/18/00 (Dll) TD/TVD: 9017/4580 ( SUPV:FRED HERBERT MW: 9.6 VISC: 56 PV/YP: 20/19 0) CIRC & COND FOR 2ND STAGE CEMENT JOB. APIWL: 5.6 Rig up to run 9-5/8" casing. PJSM. Run 9-5/8" casing to 6920'. Casing stuck w/installing centrilizer & stop collar. circ & attempt to free casing. Pull casing free. Circ & condition mud ~ 6920'. Monitor for losses. Run 9-5/8" casing. Attempt to land casing would not go down. Work casing down to bottom. Circ & cond for cement job. Break circ slowly. Could not recip casing after landing. Loosing mud slightly. Stop circ. Monitor well. 11/19/00 (D12) TD/TVD: 9017/4580 ( SUPV:FRED HERBERT 11/20/00 (D13) TD/TVD: 9017/4580 ( SUPV:FRED HERBERT MW: 9.6 VISC: 52 PV/YP: 19/18 0) P/U BHA #3 APIWL: 6.0 Circ & cond mud for cement job. PJSM. Pump cement. Bump plug. Check floats OK. Circ & cond mud for 2nd stage cement job. Hold PJSM for 2nd stage. Cement 2nd stage. Nipple down diverter stack. Nipple up head and test. Nipple up BOPs. Rig up test equipment. MW: 9.6 VISC: 55 PV/YP: 18/16 APIWL: 0.8 0) CUT DRILLING LINE Test BOPE to 250/5000 psi. RIH. Circ out thick mud. Drill out cement & stage collar. Tagged stage collar @ 2105' Date: 01/12/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 Test casing to 2500 psi. Clean out cement stringers to 2700' Circ out thick mud. RIH w/'G' pipe. Pipe not going in the hole well (floating). Circ out thick mud. POOH. RIH to 3000'. No problems. RIH. Dp still floating in hole. Pushing junk or rubber below bit. 11/21/00 (D14) MW: 8.7 VISC: 42 PV/YP: 12/12 TD/TVD: 9822/4914 ( 805) DRLG AHEAD AND 10330' SUPV:FRED HERBERT APIWL: 8.7 TIH to 5940' Circ out thick mud. Continue to TIH and circ. Pipe still floating. Tag cement @ 885' Drill cement from 8855' to 8881'. CBU, perform casing test to 2500#, OK. Drilling baffle plate, cement float collar, shoe & 17' cement below shoe. Drill hole from 9017' to 9052'. Circ and inject excess fluids & displace with LSD mud 8.4 ppg. Perform LOT EMW 13.3. Drill new hole from 9052' to 9225' Sperry Sun survey problems. Drilling from 9225' to 9822' 11/22/00 (D15) MW: 9.0 VISC: 42 PV/YP: 16/10 APIWL: 7.0 TD/TVD:l1571/5617 (1749) DRILLING AHEAD @ 12229' SUPV:FRED HERBERT Drilling 8.5" hole from 9822' to 11195' Circ & cond mud, pump sweep, monitor well, pump dry job. POOH to shoe. RIH to bottom. Circ bottoms up after wiper trip. Got back moderate amount of sand & shale. Drilling 8.5" hole from 11195' to 11571' 11/23/00 (D16) MW: 9.8 VISC: 54 PV/YP: 21/21 APIWL: 4.2 TD/TVD:13335/6334 (1764) CIRC & COND MUD FOR 7" CASING SUPV:FRED HERBERT Drilling 8.5" hole from 11571' to 12701'. Circ sweep around, displace well w/9.8 ppg mud. Drilling 8.5" hole from 12701' to 13335' Circ & cond, circ sweep around. Monitor well, pump dry job. POOH to shoe. 11/24/00 (D17) TD/TVD:13335/6334 ( SUPV:FRED HERBERT MW: 9.8 VISC: 52 PV/YP: 20/21 0) RUN 7" CASING APIWL: 4.4 POOH to 9.625" shoe. Monitor well every 1500' w/POOH. RIH to bottom. Break circ slowly, pump sweep. Circ & cond mud for casing job. POOH to run 7" casing. Monitor well @ 11500', shoe, 4500' & HWDP (OK). Hole took good fill. Rig up to run 7" casing. Date: 01/12/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 11/25/00 (D18) TD/TVD:13335/6334 ( SUPV:FRED HERBERT MW: 9.8 VISC: 42 PV/YP: 19/15 0) CHANGE RAMS APIWL: 4.6 Rig to run 7" casing. PJSM. Run 7" casing, float equipment & spiro gliders. Attempt to circ thru float equipment. Circ thru float equipment OK, run 7" casing. Circ & cond mud 8 9-5/8" shoe (9006'). Run 7" casing to 11000' Shoe @ 13323' Circ & cond mud for cement job. 11/26/00 (D19) TD/TVD:13335/6334 ( SUPV:FRED HERBERT MW: 9.9 VISC: 51 PV/YP: 22/16 0) P/U 4" DP APIWL: 4.8 Circ & cond mud for cement job. PJSM. Cement job. Bump plug. Check floats. PJSM. Rig up test equipment to test BOPE. PJSM. 11/27/00 (D20) TD/TVD:13335/6334 ( SUPV:FRED HERBERT MW: 9.8 VISC: 41 PV/YP: 15/13 0) DRILL CEMENT Test BOPE to 250/5000 psi. RIH. APIWL: 4.6 11/28/00 (D21) TD/TVD:13335/6334 ( SUPV:G.R. WHITLOCK MW: 11.3 VISC: 44 PV/YP: 23/19 0) RIH APIWL: 4.4 RIH to 13206'. Break circ and drill 15' of cement to 13221'. CBU. Test casing to 3500 psi. Drill cement to 13238', FC, cement to 13320', shoe, cement to 13335' Displace well w/ mud and try to start MWD w/no success. POOH. Safety meeting. Check MWD instruments. 11/29/00 (D22) TD/TVD:13335/6334 ( SUPV:G.R. WHITLOCK MW: 11.3 VISC: 53 PV/YP: 17/27 0) MONITORING WELL FOR SHORT TRIP APIWL: 3.6 Trip in. Drill from 13335' to 13370'. CBU for LOT. Do FIT to 16.0 ppg MWD. Drill from 13370' to 13970' 11/30/00 (D23) MW: 11.3 VISC: 53 PV/YP: 17/31 APIWL: 3.5 TD/TVD:13970/6334 ( 635) RIH W/ 3-1/2" LINER SUPV:G.R. WHITLOCK Drill from 13970' to 14138'. Pump hi-vis sweep. Circ anad cond mud. POOH to 13180'. RIH. Pump sweep and circ and condition mud. POOH to shoe. 12/01/00 (D24) MW: 11.3 VISC: 50 PV/YP: 20/18 APIWL: 3.8 TD/TVD:13970/6334 ( 0) CIRC SUPV:G.R. WHITLOCK Hold safety meeting. RIH w/3.5" liner. Circ and condition mud. Date: 01/12/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 12/02/00 (D25) TD/TVD:13970/6334 ( SUPV:G.R. WHITLOCK 12/03/00 (D26) TD/TVD:13970/6334 ( SUPV:G.R. WHITLOCK 12/04/00 (D27) TD/TVD:13970/6334 ( SUPV:G.R. WHITLOCK MW: 11.3 VISC: 50 PV/YP: 20/18 0) RUNING 3-1/2" TUBING APIWL: 3.8 Circ and condition mud. Pump cement. Bump plug. Check floats, OK. Set hanger and liner top packer. R/U to run tubing. PJSM. Run 3.5" tubing. MW: 8.5 VISC: 0 PV/YP: 0/ 0 0) INSTALLING XMAS TREE APIWL: 0.0 RIH w/3.5" tubing. Circ tubing volume. Test liner and casing to 3500 psi, OK. Displace well w/seawater. Test tubing to 3000 psi. Test annulus to 3000 psi. MW: 0.0 VISC: 0) RIG RELEASED 0 PV/YP: 0/ 0 APIWL: 0.0 Freeze protect tubing. N/D BOPE. N/U Xmas tree and adapter flange. Test tree and adapter to 5000 psi. Finish freeze protecting injection well. Rig relased at 1200 pm on 12/4/00. Date Comment t 'i~' 1D-32 Event History 05/01/01 PERFORATED 13904-13944 FT MD WITH 2 RIHS - CHARGES = 31J U J, HMX @ 4 SPF. RAN GUN GR FOR CORRELATION AS COLLARS ARE NOT USEABLE IN LINER. PERFORMED INJECTIVIY TEST, PUMPED 1 BPM AT 2200 PSI, 2.5 BPM AT 3100 PSI. ~ [Perf] 05/02/01 PERFED 13870-13880 FT AND 13814-13824 FT WITH 2.5" HSD @ 4 SPF, CHARGES = 31J UJ. RAN GUN GR FOR TIE IN. AFTER PERFS, RAN A SBHP. 05/04/01 PULL DGLV, TEST IA 05/05/01 PUMPED INITIAL HPBD. WELL VERY HARD TO BREAK DOWN INITIALLY. TREATED AT VERY HIGH PRESSURES. REDUCED ROCK SALT DIVERSION STAGES DUE TO HIGH TREATING PRESSURES. SAW -300 PSI DIVERSION IN BOTH STAGES. SAW LITTLE EFFECT FROM SCOUR STAGES. TURNED WELL O Page I of I 5/8/01 15-Dec-00 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 DEFINITIVE SURVEYS Re: Distribution of Survey Data for Well 1D-32 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 14,138.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Kuparuk River Unit Phillips Alaska Kuparuk ID, Slot ~D-32 ~D-32 Surveyed: 30 November, 2000 S UR VEY REPORT December, 2000 Your Ref: AP1500292298200 Surface Coordinates: 5959249.09 N, 560670.66 E (70° 17' 57.2~39" N, ~49° 30' 3~.~42~" W) Kelly Bushing: ~04.45ft above Mean Sea Level DRILLING SERVICE'-- Halliburton Company Survey Ref: svy9344 Sperry-Sun Drifting Services Survey Report for ID-32 Your Ref: APl 500292298200 Surveyed: 30 November, 2000 Kuparuk River Unit Measured Depth (ft) Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -104.45 0.00 130.00 0.000 0.000 25.55 130.00 196.41 0.490 82.970 91.96 196.41 287.35 0.930 78.010 182.89 287.34 376.33 2.350 76.850 271.83 376.28 469.14 3.770 85.350 364.51 468.96 559.93 5.930 87.320 454.97 559.42 654.29 9.240 87.440 548.49 652.94 745.64 10.850 87.170 638.44 742.89 837.46 13.500 90.440 728.18 832.63 932.55 16.980 92.140 819.92 924.37 1025.89 20.600 89.710 908.27 1012.72 1118.38 23.680 87.580 993.93 1098.38 1208.09 26.860 87.750 1075.05 1179.50 1302.92 30.710 89.690 1158.14 1262.59 1397.91 34.480 89.820 1238.16 1342.61 1488.96 39.190 89.190 1311.01 1415.46 1583.45 42.840 89.600 1382.30 1486.75 1672.45 45.040 88.120 1446.38 1550.83 1764.57 46.720 88.960 1510.51 1614.96 1857.37 48.800 88.160 1572.89 1677.34 1950.38 50.650 88.320 1633.01 1737.46 2045.92 53.330 91.930 1691.85 1796.30 2138.92 55.260 91.830 1746.13 1850.58 2226.97 58.160 92.290 1794.45 1898.90 Local Coordinates Northings Eastings (ft) (ft) 0.00 N 0.00 E 0.00 N 0.00 E 0.03 N 0.28 E 0.24 N 1.39 E 0.80 N 3.87 E 1.48 N 8.77 E 1.94 N 16.43 E 2.51 N 28.87 E 3.26 N 44.78 E 3.61 N 64.14 E 3.00 N 89.12 2.58 N 119.17 3.44 N 154.00 5.00 N 192.26 5.97 N 237.90 6.19 N 289.06 6.68 N 343.63 7.32 N 4O5.63 8.57 N 467.36 10.24 N 533.47 11.98 N 602.15 14.16 N 673.07 13.95 N 748.32 11.47 N 823.79 8.82 N 897.34 Global Coordinates Northings Eastings (ft) (ft) 5959249.09 N 560670.66 E 5959249.09 N 560670.66 E 5959249.13 N 560670.94 E 5959249.34 N 560672.05 E 5959249.92 N 560674.53 E 5959250.64 N 560679.41 E 5959251.16 N 560687.07 E 5959251.83 N 560699.51E 5959252.71 N 560715.42 E 5959253.21N 560734.76 E 5959252.81N 560759.75 E 5959252.63 N 560789.80 E 5959253.78 N 560824.63 E 5959255.64 N 560862.88 E 5959256.98 N 560908.51 E 5959257.61 N 560959.66 E 5959258.54 N 561014.23 E 5959259.69 N 561076.21E 5959261.43 N 561137.94 E 5959263.64 N 561204.03 E 5959265.93 N 561272.69 E 5959268.68 N 561343.60 E 5959269.08 N 561418.84 E 5959267.21 N 561494.34 E 5959265.16 N 561567.90 E Dogleg Rate (°/'~OOft) 0.00 0.74 0.49 1.60 1.60 2.39 3.51 1.76 2.98 3.69 3.97 3.44 3.55 4.18 3.97 5.19 3.87 2.73 1.94 2.33 1.99 4.O9 2.08 3.32 Vertical Section 0.00 0.00 0.17 0.79 2.09 4.97 9.91 18.07 28.49 41.57 59.21 80.22 103.59 128.82 159.55 194.64 231.87 274.11 315.74 360.06 406.11 453.39 505.38 559.16 611.75 Phillips Alaska Kuparuk 1D Comment AK--6 BP IFR-AK Continued... December, 2000 - 6:47 - 2- DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for rD-32 Your Ref: AP1500292298200 Surveyed: 30 November, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 2323.05 58.210 91.790 1845.10 1949.55 2411.95 58.360 92.120 1891.84 1996.29 2506.29 62.390 90.860 1938.46 2042.91 2599.77 64.140 90.870 1980.51 2084.96 2690.75 66.520 89.600 2018.49 2122.94 2784.17 65.830 2877.18 63.630 2970.82 64.590 3063.50 65.770 3155.38 65.560 2056.22 2095.93 2136.81 2175.72 2213.60 90.860 91.070 91.750 93.410 98.130 2160.67 2200.38 2241.26 2280.17 2318.05 3250.84 64.720 99.620 2253.73 2358.18 3343.99 64.100 104.180 2293.98 2398.43 3437.64 63.700 104.170 2335.18 2439.63 3532.03 64.500 106.230 2376.42 2480.87 3621.60 65.300 109.000 2414.42 2518.87 3719.58 65.390 110.690 2455.29 2559.74 3816.41 65.140 113.710 2495.82 2600.27 3907.38 64.870 115.930 2534.26 2638.71 4000.29 64.320 118.870 2574.13 2678.58 4095.03 64.820 119.980 2614.81 2719.26 4190.77 65.140 120.890 2655.30 2759.75 4284.95 64.590 125.260 2695.32 2799.77 4379.76 63.810 126.870 2736.59 2841.04 4474.17 63.640 126.270 2778.38 2882.83 4568.14 66.010 129.350 2818.36 2922.81 Local Coordinates Northings Eastings (ft) (ft) 5.92 N 978.93 E 3.34 N 1054.51E 1.22 N 1136.47 E 0.04 S 1219.95 E 0.37 S 1302.62 E 0.71S 1388.07 E 2.12 S 1472.16 E 4.20 S 1556.38 E 7.99 S 1640.41E 16.40 S 1723.67 E 29.76 S 1809.24 E 47.07 S 1891.42 E 67.66 S 1972.96 E 89.93 S 2054.89 E 114.48 S 2132.19 E 144.71 S 2215.94 E 177.93 S 2297.36 E 212.53 S 2372.18 E 251.15 S 2446.69 E 293.18 S 2521.21 E 337.13 S 2596.01E 383.64 S 2667.43 E 433.88 S 2736.43 E 484.32 S 2804.42 E 536.46 S 2871.58 E Global Coordinates Northings Eastings (fi) (fi) 5959262.91 N 561649.51 E 5959260.94 N 561725.11 E 5959259.49 N 561807.09 E 5959258.90 N 561890.57 E 5959259.24 N 561973.24 E 5959259.59 N 562058.69 E 5959258.85 N 562142.79 E 5959257.46 N 562227.02 E 5959254.34 N 562311.08 E 5959246.60 N 562394.40 E 5959233.94 N 562480.08 E 5959217.29 N 562562.40 E 5959197.36 N 562644.10 E 5959175.75 N 562726.21E 5959151.83 N 562803.70 E 5959122.28 N 562887.70 E 5959089.71 N 562969.38 E 5959055.71 N 563044.48 E 5959017.71N 563119.29 E 5958976.27 N 563194.15 E 5958932.93 N 563269.30 E 5958887.00 N 563341.10 E 5958837.31N 563410.50 E 5958787.43 N 563478.90 E 5958735.83 N 563546.48 E Dogleg Rate (o/looft) 0.45 0.36 4.43 1.87 2.91 1.44 2.37 1.22 2.06 4.69 1.67 4.46 0.43 2.14 2.94 1.57 2.84 2.23 2.92 1.18 0.92 4.24 1.74 0.60 3.89 Vertical Section 670.06 723.99 781.99 840.40 897.59 956.70 1015.66 1075.17 1135.80 1199.26 1267.89 1337.05 1408.14 1480.72 1551.76 1631.37 1711.54 1788.17 1867.48 1949.29 2032.67 2115.59 2199.54 2282.94 2367.00 Phillips Alaska Kuparuk 1D Comment Continued... 15 December, 2000 - 6:47 - 3 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for rD-32 Your Ref: APl 500292298200 Surveyed: 30 November, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4662.38 65.940 129.350 2856.73 2961.18 4757.06 66.620 132.320 2894.82 2999.27 4850.00 66.740 135.500 2931.62 3036.07 4944.12 66.640 137.850 2968.87 3073.32 5037.74 66.430 139.180 3006.15 3110.60 5131.80 67.250 141.600 3043.15 3147.60 5226.34 67.580 143.280 3079.46 3183.91 5320.21 67.890 144.590 3115.02 3219.47 5415.12 70.090 145.400 3149.05 3253.50 5510.30 69.760 146.060 3181.72 3286.17 5604.67 70.440 145.630 3213.84 3318.29 5697.39 71.110 148.180 3244.38 3348.83 5792.65 71.750 149.440 3274.72 3379.17 5884.38 72.610 149.570 3302.79 3407.24 5978.17 74.170 148.910 3329.60 3434.05 6072.74 73.550 149.640 3355.89 3460.34 6165.63 72.920 149.930 3382.68 3487.13 6259.29 75.470 149.900 3408.19 3512.64 6344.12 74.580 148.670 3430.11 3534.56 6440.26 76.380 148.470 3454.21 3558.66 6532.44 74.380 150.120 3477.48 3581.93 6628.38 71.360 149.090 3505.73 3610.18 6721.64 69.160 149.160 3537.23 3641.68 6815.20 66.600 148.620 3572.46 3676.91 6909.68 64.660 148.200 3611.44 3715.89 591.04 S 2938.14 E 647.71S 3003.71E 706.90 S 3065.18 E 769.77 S 3124.49 E 834.10 S 3181.37 E 900.72 S 3236.50 E 969.92 S 3289.71 E 1040.14 S 3340.85 E 1112.71 S 3391.66 E 1186.58 S 3442.00 E 1260.01 S 3491.82 E 1333.35 S 3539.62 E 1410.60 S 3586.38 E 1485.85 S 3630.70 E 1563.08 S 3676.66 E 1641.17 S 3723.08 E 1718.02 S 3767.84 E 1796.00 S 3813.01E 1866.45 S 3854.86 E 1945.86 S 3903.39 E 2022.54 S 3948.94 E 2101.61S 3995.31E 2176.95 S 4040.36 E 2251.15 S 4085.13 E 2324.46 S 4130.21E 5958681.79 N 563613.48 E 5958625.65 N 563679.50 E 5958566.96 N 563741.45 E 5958504.57 N 563801.26 E 5958440.70 N 563858.66 E 5958374.53 N 563914.33 E 5958305.76 N 563968.09 E 5958235.96 N 564019.80 E 5958163.80 N 564071.20 E 5958090.33 N 564122.13 E 5958017.31N 564172.54 E 5957944.36 N 564220.93 E 5957867.49 N 564268.31 E 5957792.60 N 564313.23 E 5957715.75 N 564359.82 E 5957638.04 N 564406.86 E 5957561.54 N 564452.24 E 5957483.94 N 564498.04 E 5957413.83 N 564540.46 E 5957334.81N 564589.63 E 5957258.50 N 564635.80 E 5957179.80 N 564682.81E 5957104.83 N 564728.46 E 5957030.99 N 564773.83 E 5956958.05 N 564819.50 E Dogleg Rate (°/'~OOft) 0.07 2.96 3.14 2.30 1.32 2.52 1.68 1.33 2.45 0.74 0.84 2.7O 1.42 0.95 1.79 0.99 0.74 2.72 1.75 1.88 2.78 3.31 2.36 2.79 2.09 Vertical Section 2452.41 2538.66 2623.91 2710.34 2796.16 2882.43 2969.24 3055.37 3142.98 3231.21 3318.75 3404.84 3493.05 3578.13 3665.77 3754.35 3840.90 3928.54 4008.44 4099.43 4186.39 4275.66 4361.30 4445.93 4530.13 Phillips Alaska Kuparuk 1D Comment Continued... 15 December, 2000.6:47 - 4 - DriilQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for f D-$2 Your Ref: APl 500292298200 Surveyed: 30 November, 2000 Kuparuk River Unit Measured Depth Incl. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 7001.49 64.280 147.970 3651.01 3755.46 7096.61 63.960 149.310 3692.53 3796.98 7189.93 64.180 148.430 3733.34 3837.79 7284.60 65.160 149.150 3773.84 3878.29 7377.44 66.080 148.770 3812.16 3916.61 7471.95 65.830 149.640 3850.67 3955.12 7568.07 65.770 149.480 3890.07 3994.52 7658.90 66.080 149.470 3927.13 4031.58 7752.51 66.080 149.780 3965.08 4069.53 7849.01 66.020 149.770 4004.25 4108.70 7938.69 66.480 148.350 4040.37 4144.82 8035.04 66.210 148.490 4079.03 4183.48 8128.29 66.550 148.830 4116.39 4220.84 8222.97 67.080 148.010 4153.67 4258.12 8316.94 66.680 147.830 4190.57 4295.02 8410.10 66.200 149.390 4227.81 4332.26 8505.96 65.620 149.200 4266.93 4371.38 8601.71 65.450 149.750 4306.59 4411.04 8694.31 66.070 148.780 4344.61 4449.06 8788.55 65.850 148.810 4383.00 4487.45 8882.37 65.950 148.980 4421.31 4525.76 8958.55 65.670 148.960 4452.52 4556.97 9053.05 65.580 149.700 4491.52 4595.97 9150.18 65.210 148.780 4531.97 4636.42 9242.49 65.410 150.270 4570.53 4674.98 2394.78 S 4174.01 E 2467.86 S 4218.54 E 2539.70 S 4261.93 E 2612.88 S 4306.27 E 2685.33 S 4349.87 E 2759.47 S 4394.06 E 2835.06 S 4438.48 E 2906.49 S 4480.60 E 2980.32 S 4523.87 E 3056.52 S 4568.26 E 3126.92 S 4610.47 E 3202.11S 4656.68 E 3275.08 S 4701.12 E 3349.22 S 4746.70 E 3422.45 S 4792.60 E 3495.34 S 4837.08 E 3570.58 S 4881.76 E 3645.66 S 4926.03 E 3718.23 S 4969.18 E 3791.84 S 5013.77 E 3865.17 S 5058.01E 3924.72 S 5093.84 E 3998.75 S 5137.74 E 4074.64 S 5182.91 E 4146.92 S 5225.44 E 5956888.09 N 564863.87 E 5956815.37 N 564908.99 E 5956743.89 N 564952.96 E 5956671.06 N 564997.88 E 5956598.97 N 565042.07 E 5956525.19 N 565086.85 E 5956449.96 N 565131.88 E 5956378.87 N 565174.58 E 5956305.39 N 565218.44 E 5956229.55 N 565263.45 E 5956159.49 N 565306.22 E 5956084.69 N 565353.04 E 5956012.07 N 565398.07 E 5955938.30 N 565444.24 E 5955865.45 N 565490.73 E 5955792.92 N 565535.80 E 5955718.04 N 565581.09 E 5955643.32 N 565625.96 E 5955571.10 N 565669.70 E 59554~7.85 N 565714.88 E 5955424.88 N 565759.72 E 5955365.63 N 565796.02 E 5955291.95 N 565840.52 E 5955216.43 N 565886.30 E 5955144.49 N 565929.41 E Dogleg Rate (°/'~00ft) 0.47 1.31 0.88 1.24 1.06 0.88 0.16 0.34 0.30 0.06 1.54 0.31 0.49 0.97 0.46 1.62 0.63 0.55 1.17 0.24 0.20 0.37 0.72 0.94 1.48 Vertical Section 4611.27 4694.92 4776.89 486O.48 4943.04 5027.22 5112.61 5193.41 5276.73 5362.55 5442.65 5528.99 5612.50 5697.64 5782.34 5865.82 5951.15 6036.06 6118.39 6202.47 6286.11 6353.95 6437.86 6523.98 6605.68 Phillips Alaska Kuparuk 1D Comment Continued... 15 December, 2000 - 6:47 - 5 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for 1D-32 Your Ref: APl 500292298200 Surveyed: 30 November, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 9336.40 65.370 152.070 4609.64 4714.09 9428.67 64.870 152.660 4648.46 4752.91 9523.65 65.410 150.850 4688.39 4792.84 9618.29 65.200 150.120 4727.93 4832.38 9712.50 66.360 151.020 4766.58 4871.03 9806.28 66.210 150.440 4804.30 4908.75 9901.24 65.890 149.110 4842.85 4947.30 9994.90 66.280 150.730 4880.82 4985.27 10092.49 65.950 151.140 4920.33 5024.78 10182.21 65.640 152.970 4957.12 5061.57 10279.43 65.370 149.950 4997.43 5101.88 10373.28 65.570 150.470 5036.40 5140.85 10463.80 65.580 149.370 5073.83 5178.28 10558.08 65.850 148.900 5112.60 5217.05 10652.04 67.450 147.310 5149.85 5254.30 10746.39 67.990 148.610 5185.62 5290.07 10843.66 67.580 147.480 5222.40 5326.85 10933.09 67.190 148.270 5256.78 5361.23 11028.78 66.640 147.370 5294.31 5398.76 11121.51 66.210 147.290 5331.39 5435.84 11217.99 65.980 148.330 5370.49 5474.94 11311.41 65.610 146.940 5408.79 5513.24 11402.30 66.080 148.450 5445.99 5550.44 11500.47 66.380 148.380 5485.56 5590.01 11593.11 66.220 149.170 5522.79 5627.24 4221.71S 5266.61E 4295.87 S 5305.44 E 4371.78 S 5346.22 E 4446.61 S 5388.58 E 4521.44 S 5430.79 E 4596.34 S 5472.77 E 4671.32 S 5516.46 E 4745.41S 5559.37 E 4823.40 S 5602.71 E 4895.69 S 5641.06 E 4973.39 S 5683.32 E 5047.49 S 5725.74 E 5118.81 S 5767.05 E 5192.57 S 5811.14 E 5265.81S 5856.72 E 5339.81S 5903.03 E 5416.21 S 5950.69 E 5486.13 S 5994.59 E 5560.63 S 6041.47 E 5632.18 S 6087.35 E 5706.82 S 6134.33 E 5778.79 S 6179.94 E 5848.88 S 6224.26 E 5925.42 S 6271.32 E 5997.95 S 6315.29 E 5955070.03 N 565971.18 E 5954996.19 N 566010.61 E 5954920.61N 566052.00 E 5954846.13 N 566094.96 E 5954771.65 N 566137.78 E 5954697.09 N 566180.36 E 5954622.46 N 566224.65 E 5954548.72 N 566268.16 E 5954471.08 N 566312.13 E 5954399.11 N 566351.06 E 5954321.74 N 566393.95 E 5954247.99 N 566436.96 E 5954177.01N 566478.85 E 5954103.60 N 566523.53 E 5954030.74 N 566569.70 E 5953957.11N 566616.61E 5953881.10 N 566664.88 E 5953811.54 N 566709.35 E 5953737.42 N 566756.82 E 5953666.24 N 566803.28 E 5953591.98 N 566850.87 E 5953520.38 N 566897.06 E 5953450.65 N 566941.94 E 5953374.50 N 566989.61 E 5953302.32 N 567034.17 E Dogleg Rate (°/100ft) 1.74 0.79 1.82 0.74 1.51 0.59 1.32 1.64 0.51 1.89 2.84 0.55 1.11 0.54 2.31 1.40 1.16 0.92 1.04 0.47 1.01 1.41 1.60 0.31 0.80 Vertical Section 6688.25 6768.76 6851.88 6935.30 7018.62 7101.83 7186.28 7269.54 7355.94 7434.76 7520.20 7603.13 7683.29 7767.13 7851.61 7937.16 8025.38 8106.30 8192.60 8276.06 8362.54 8446.13 8527.47 8615.36 8698.23 Phillips Alaska Kuparuk 1D Comment Continued... 15 December, 2000 - 6:47 - 6 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Reporf for fD-$2 Your Ref: APl 500292298200 Surveyed: 30 November, 2000 Kuparuk River Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 11690.43 65,910 148,110 5562.28 5666.73 11780.55 65,370 148.410 5599.45 5703.90 11878.85 64,900 148.440 5640.78 5745.23 11968,18 64.350 149,390 5679.06 5783.51 12062.35 65.700 149,840 5718.82 5823.27 12155.18 65.230 150.090 5757.37 5861.82 12254.12 64.690 149.540 5799.25 5903.70 12344.26 65.950 151,060 5836.89 5941.34 12438.25 66.210 150,660 5875.00 5979.45 12536.17 66.840 150.010 5914.00 6018.45 12627.33 66.440 149.180 5950.15 6054.60 12721.38 67.450 150.180 5986.98 6091.43 12814.67 67,330 150.030 6022.85 6127.30 12907.22 66.920 150,480 6058.82 6163.27 13002.88 66.730 150.020 6096.47 6200.92 13093.88 66.430 150.060 6132.64 6237.09 13186.42 66.220 151.040 6169.80 6274.25 13260.01 65.890 150.670 6199.67 6304.12 13386.70 65.610 148.320 6251.71 6356.16 13483.11 65.370 148.600 6291.70 6396.15 13578.49 65.470 148.450 6331.38 6435.83 13675.52 64.650 148.490 6372.29 6476.74 13768.22 65.240 148.860 6411.55 6516.00 13865.21 64.390 148.750 6452.82 6557.27 13965.77 63.540 148.380 6496.96 6601.41 6073.91S 6361.58 E 6143.73 S 6404.77 E 6219.71 S 6451.47 E 6288.83 S 6493.14 E 6362.47 S 6536.32 E 6435.58 S 6578.59 E 6513.06 S 6623.65 E 6584.21S 6664.23 E 6659.25 S 6706.07 E 6737.29 S 6750.52 E 6809.47 S 6792.87 E 6884.17 S 6836.56 E 6958.83 S 6879.48 E 7032.87 S 6921.79 E 7109.22 S 6965.42 E 7181.56 S 7007.12 E 7255.36 S 7048.79 E 7314.10 S 7081.55 E 7413.62 S 7140.18 E 7488.38 S 7186.06 E 7562.35 S 7231.35 E 7637.35 S 7277.36 E 7709.08 S 7321.02 E 7784.16 S 7366.48 E 7861.25 S 7413.60 E 5953226.74 N 567081.07 E 5953157.27 N 567124.82 E 5953081.67 N 567172.13 E 5953012.89 N 567214.36 E 5952939.60 N 567258.13 E 5952866.84 N 567300.99 E 5952789.72 N 567346.68 E 5952718.90 N 567387.83 E 5952644.20 N 567430.27 E 5952566.52 N 567475.35 E 5952494.69 N 567518.29 E 5952420.34 N 567562.57 E 5952346.03 N 567606.10 E 5952272.34 N 567649.00 E 5952196.34 N 567693.25 E 5952124.34 N 567735.54 E 5952050.88 N 567777.80 E 59519~2.40 N 567811.03 E 5951893.36 N 567870.46 E 5951818.97 N 567916.95 E 5951745.37 N 567962.83 E 5951670.75 N 568009.44 E 5951599.37 N 568053.68 E 5951524.66 N 568099.74 E 5951447.95 N 568147.49 E Dogleg Rate (°/100ft) 1.05 0.67 0.48 1.14 1.50 0.56 0.74 2.07 0.48 0.89 0.94 1.45 0.20 0.63 0.48 0.33 1.00 0.64 1.71 0.36 0.18 0.85 0.73 0.88 0.91 Vertical Section 8785.18 8865.54 8952.79 9031.60 9114.72 9196.84 9284.05 9363.58 9446.79 9533.99 9615.48 9699.73 9783.42 9866.23 9951.63 10032.80 10115.00 10180.15 10292.67 10378.48 1O463.3O 1O549.35 10631.43 10717.17 10805.51 Phillips Alaska Kuparuk 1D Comment Continued... DrillQuest 2.00.05 15 December, 2000.6:47 - 7- Sperry-Sun Drilling Services Survey Report for 1D-32 Your Ref: APl 500292298200 Surveyed: 30 November, 2000 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 14062.40 63.120 147.660 6540.33 6644.78 7934.50 S 7459.33 E 14068.73 62.650 147.870 6543.22 6647.67 7939.26 S 7462.34 E 14138.00 62.650 147.870 6575.04 6679.49 7991.37 S 7495.06 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100fi) 5951375.07 N 568193.81E 5951370.33 N 568196.85 E 5951318.49 N 568229.99 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.380° (09-Nov-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 136.460° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14138.00ft., The Bottom Hole Displacement is 10956.18ft., in the Direction of 136.836° (True). 0.80 7.99 0.00 Vertical Section 10890.11 10895.63 10955.94 Phillips Alaska Kuparuk 1 D Comment. PROJECTED SURVEY Continued... 15 December, 2000 - 6:47 - 8 - DrillQuest 2. 00.05 Sperry-Sun Drilling Services Survey Report for 1D-32 Your Ref: APl 500292298200 Surveyed: 30 November, 2000 Kuparuk River Unit Phillips Alaska Kuparuk 1D Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 14138.00 6679.49 7991.37 S 7495.06 E Comment PROJECTED SURVEY Survey tool program for ~D-32 From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 14138.00 Vertical Depth (ft) 6679.49 Survey Tool Description AK-6 BP IFR-AK 15 December, 2000 - 6:47 - 9 - DrillQuest 2.00.05 15-Dec-00 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-32 MWD 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 14,138.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Kuparuk River Unit Phillips Alaska Kuparuk ID, Slot ~D-32 ~D-32 MWD Surveyed: 30 November, 2000 S UR VEY REPORT December, 2000 Your Reft APl 5002298200 Surface Coordinates: 5959249.09 N, 560670.66 E (70° 17' 57.2139" N, Kelly Bushing: 104.45ft above Mean Sea Level 149° 30' 31.1421" VV) sper~m~-suq DRILLING 5ERVIr-E5 A Halliburton Company Survey Ref: svy9345 Sperry-Sun Drilling Services Survey Report for '1D.32 MWD Your Ref: AP1 5002298200 Surveyed: 30 November, 2000 Kuparuk River Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -104.45 0.00 130.00 0.000 0.000 25.55 130.00 196.41 0.490 82.810 91.96 196.41 287,35 0.930 77.800 182.89 287.34 376.33 2.350 76.200 271.83 376.28 469.14 3.770 84.450 364.51 468.96 559.93 5.930 86.750 454.97 559.42 654.29 9.240 86.850 548.49 652.94 745.64 10.850 87.090 638.44 742.89 837.46 13.500 89.790 728.18 832.63 932.55 16.980 91.690 819.92 924.37 1025.89 20.600 89.510 908.27 1012.72 1118.38 23.680 86.960 993.93 1098.38 1208.09 26.860 87.100 1075.05 1179.50 1302.92 30.710 88.720 1158.14 1262.59 1397.91 34.480 90.880 1238.16 1342.61 1488.96 39.190 89.480 1311.01 1415.46 1583.45 42.840 90.830 1382.30 1486.75 1672.45 45.040 90.090 1446.38 1550.83 1764.57 46.720 88.830 1510.51 1614.96 1857.37 48.800 1950.38 50.650 2045.92 53.330 2138.92 55.260 2226.97 58.160 1572.90 1633.03 1691.87 1746.14 1794.47 91.380 88.45O 92.020 91.260 91.710 1677.35 1737.48 1796.32 1850.59 1898.92 0.00 N 0.00 E 0.00 N 0.00 E 0.O4 N O.28 E 0.24 N 1.39 E 0.83 N 3.87 E 1.58 N 8.75 E 2.13 N 16.41 E 2.82 N 28.84 E 3.66 N 44.75 E 4.14 N 64.10 E 3.77 N 89.09 3.51N 119.14 4.64 N 153.97 6.62 N 192.21 8.24 N 237.83 8.37 N 288.98 8.24 N 343.55 8.04 N 4O5.55 7.55 N 467.30 8.19 N 533.42 8.04 N 602.11 8.17 N 673.05 7.82 N 748.30 5.66 N 823.78 3.75 N 897.35 5959249.09 N 560670.66 E 5959249.09 N 560670.66 E 5959249.13 N 560670.94 E 5959249.34 N 560672.05 E 5959249.95 N 560674.52 E 5959250.74 N 560679.40 E 5959251.35 N 560687.05 E 5959252.15 N 560699.48 E 5959253.12 N 560715.38 E 5959253.75 N 560734.73 E 5959253.58 N 560759.71 E 5959253.56 N 560789.77 E 5959254.97 N 560824.59 E 5959257.26 N 560862.81 E 5959259.25 N 560908.42 E 5959259.79 N 560959.57 E 5959260.10 N 561014.13 E 5959260.41N 561076.13 E 5959260.42 N 561137.88 E 5959261.58 N 561204.00 E 5959261.99 N 561272.68 E 5959262.69 N 561343.63 E 5959262.95 N 561418.87 E 5959261.40 N 561494.37 E 5959260.08 N 561567.95 E Dogleg Rate (Ol'~OOft) 0.00 0.74 0.49 1.60 1.60 2.39 3.51 1.76 2.95 3.70 3.95 3.49 3.55 4.14 4.15 5.25 3.97 2.54 2.07 3.03 3.12 4.07 2.18 3.32 Vertical Section 0.00 0.00 0.17 0.78 2.06 4.89 9.76 17.82 28.17 41.16 58.63 79.53 102.70 127.61 157.86 193.00 230.69 273.54 316.43 361.52 4O8.94 457.72 509.81 563.37 615.43 Phillips Alaska Kuparuk 1D Comment MWD Magnetic Continued... 15 December, 2000 - 6:49 - 2 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for 1D-32 MWD Your Ref: AP1 5002298200 Surveyed: 30 November, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 2323.05 58.210 91.260 1845.12 1949.57 2411.95 58.360 90.830 1891.85 1996.30 2506.29 62.390 90.800 1938.48 2042.93 2599.77 64.140 90.890 1980.53 2084.98 2690.75 66.520 88.590 2018.51 2122.96 2784.17 65.830 90.160 2056.24 2160.69 2877.18 63.630 90.480 2095.95 2200.40 2970.82 64.590 91.210 2136.83 2241.28 3063.50 65.770 93.030 2175.74 2280.19 3155.38 65.560 96.650 2213.61 2318.06 3250.84 64.720 98.790 2253.75 2358.20 3343.99 64.100 103.690 2294.00 2398.45 3437.64 63.700 103.760 2335.20 2439.65 3532.03 64.500 106.420 2376.44 2480.89 3621.60 65.300 111.310 2414.45 2518.90 3719.58 65.390 109.210 2455.33 2559.78 3816.41 65.140 112.200 2495.85 2600.30 3907.38 64.870 114.250 2534.29 2638.74 4000.29 64.320 117.600 2574.16 2678.61 4095.03 64.820 118.630 2614.84 2719.29 4190.77 65.140 119.730 2655.34 2759.79 4284.95 64.590 123.980 2695.35 2799.80 4379.76 63.810 126.280 2736.62 2841.07 4474.17 63.640 125.640 2778.42 2882.87 4568.14 66.010 128.990 2818.40 2922.85 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1.63 N 978.97 E 0.25 N 1054.58 E 0.91S 1136.56 E 2.14 S 1220.04 E 1.75 S 1302.70 E 0.82 S 1388.15 E 1.29 S 1472.25 E 2.53 S 1556.48 E 5.65 S 1640.54 E 12.71 S 1723.94 E 24.34 S 1809.76 E 40.70 S 1892.13 E 60.65 S 1973.83 E 82.76 S 2055.80 E 108.98 S 2132.52 E 139.82 S 2216.05 E 170.90 S 2298.30 E 203.41 S 2374.07 E 240.09 S 2449.53 E 280.41 S 2525.00 E 322.71S 2600.74 E 367.69 S 2673.14 E 416.80 S 2742.95 E 466.51 S 2811.47 E 518.07 S 2879.07 E 5959258.63 N 561649.58 E 5959257.86 N 561725.21E 5959257.35 N 561807.19 E 5959256.80 N 561890.68 E 5959257.85 N 561973.33 E 5959259.48 N 562058.77 E 5959259.69 N 562142.88 E 5959259.13 N 562227.11 E 5959256.69 N 562311.19 E 5959250.30 N 562394.65 E 5959239.37 N 562480.56 E 5959223.67 N 562563.06 E 5959204.38 N 562644.91 E 5959182.93 N 562727.06 E 5959157.33 N 562803.99 E 5959127.17 N 562887.76 E 5959096.75 N 562970.27 E 5959064.85 N 563046.29 E 5959028.78 N 563122.05 E 5958989.07 N 563197.84 E 5958947.39 N 563273.92 E 5958902.99 N 563346.68 E 5958854.45 N 563416.88 E 5958805.29 N 563485.80 E 5958754.28 N 563553.82 E Dogleg Rate (o/'~ooft) 0.40 0.44 4.27 1.87 3.48 1.71 2.39 1.24 2.19 3.60 2.22 4.79 0.43 2.67 5.02 1.95 2.82 2.06 3.31 1.11 1.09 4.13 2.33 0.63 4.O9 Vertical Section 673.19 726.28 783.60 841.99 898.65 956.84 1015.11 1074.03 1134.20 1196.77 1264.31 1332.91 1403.66 1476.15 1548.01 1627.90 1707.10 1782.85 1861.43 1942.64 2025.48 2107.96 2191.64 2274.88 2358.83 Phillips Alaska Kuparuk 1 D Comment Continued... 15 December, 2000 - 6:49 - 3 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for I D-32 MWD Your Reft APl 5002298200 Surveyed: 30 November, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4662.38 65.940 129.110 2856.76 2961.21 4757.06 66.620 131.330 2894.85 2999.30 4850.00 66.740 134.070 2931.65 3036.10 4944.12 66.640 136.600 2968.90 3073.35 5037.74 66.430 138.460 3006.18 3110.63 5131.80 67.250 140.900 3043.18 3147.63 5226.34 67.580 142.240 3079.49 3183.94 5320.21 67.890 143.640 3115.06 3219.51 5415.12 70.090 144.550 3149.09 3253.54 5510.30 69.760 144.660 3181.76 3286.21 5604.67 70.440 144.400 3213.88 3318.33 5697.39 71.110 146.990 3244.41 3348.86 5792.65 71.750 148.500 3274.75 3379.20 5884.38 72.610 148.730 3302.82 3407.27 5978.17 74.170 147.980 3329.63 3434.08 6072.74 73.550 148.950 3355.92 3460.37 6165.63 72.920 148.960 3382.72 3487.17 6259.29 75.470 149.200 3408.22 3512.67 6344.12 74.580 148.970 3430.14 3534.59 6440.26 76.380 147.660 3454.25 3558.70 6532.44 74.380 149.420 3477.51 3581.96 6628.38 71.360 148.500 3505.77 3610.22 6721.64 69.160 148.230 3537.27 3641.72 6815.20 66.600 147.920 3572.49 3676.94 6909.68 64.660 147.590 3611.48 3715.93 572.30 S 2945.92 E 628.27 S 3012.10 E 686.14 S 3074.81E 747.61 S 3135.57 E 810.95 S 3193.55 E 876.88 S 3249.50 E 945.26 S 3303.75 E 1014.59 S 3356.10 E 1086.35 S 3408.05 E 1159.22 S 3459.83 E 1231.49 S 3511.32 E 1303.80 S 3560.66 E 1380.17 S 3608.85 E 1454.72 S 3654.33 E 1531.23 S 3701.48 E 1608.65 S 3748.99 E 1684.85 S 3794.86 E 1762.16 S 3841.16 E 1832.47 S 3883.26 E 1911.66 S 3932.15 E 1987.73 S 3978.70 E 2066.28 S 4025.97 E 2141.01S 4072.00 E 2214.57 S 4117.83 E 2287.35 S 4163.74 E 5958700.60 N 563621.10 E 5958645.16 N 563687.73 E 5958587.80 N 563750.91E 5958526.82 N 563812.16 E 5958463.95 N 563870.66 E 5958398.47 N 563927.13 E 5958330.53 N 563981.94 E 5958261.63 N 564034.84 E 5958190.29 N 564087.37 E 5958117.84 N 564139.74 E 5958045.99 N 564191.81E 5957974.08 N 564241.73 E 5957898.10 N 564290.53 E 5957823.92 N 564336.61E 5957747.80 N 564384.38 E 5957670.76 N 564432.52 E 5957594.93 N 564479.00 E 5957518.00 N 564525.92 E 5957448.04 N 564568.59 E 5957369.24 N 564618.12 E 5957293.55 N 564665.28 E 5957215.38 N 564713.18 E 5957141.03 N 564759.82 E 5957067.84N 564806.24 E 5956995.43 N 564852.74 E Dogleg Rate (°/lOOft) 0.14 2.26 2.71 2.47 1.84 2.54 1.35 1.42 2.48 0.36 0.77 2.73 1.65 0.97 1.83 1.18 0.68 2.73 1.08 2.29 2.85 3.28 2.37 2.75 2.08 Vertical Section 2444.18 2530.34 2615.50 2701.91 2787.77 2874.10 2961.04 3047.35 3135.16 3223.66 3311.51 3397.92 3486.47 3571.84 3659.78 3748.64 3835.47 3923.40 4003.37 4094.45 4181.66 4271.16 4357.05 4441.94 4526.33 Phillips Alaska Kuparuk 1D Comment Continued... 15 December, 2000 - 6:49 - 4 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for 1D-32 MWD Your Reft APl 5002298200 Surveyed: 30 November, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 7001.49 64.280 147.140 3651.05 3755.50 7096.61 63.960 148.570 3692.57 3797.02 7189.93 64.180 147.770 3733.37 3837.82 7284.60 65.160 148.450 3773.88 3878.33 7377.44 66.080 147.980 3812.20 3916.65 7471.95 65.830 148.970 3850.71 3955.16 7568.07 65.770 148.810 3890.11 3994.56 7658.90 66.080 148.790 3927.16 4031.61 7752.51 66.080 149.190 3965.12 4069.57 7849.01 66.020 149.160 4004.29 4108.74 7938.69 66.480 147.690 4040.41 4144.86 8035.04 66.210 147.760 4079.07 4183.52 8128.29 66.550 147.900 4116.43 4220.88 8222.97 67.080 147.040 4153.71 4258.16 8316.94 66.680 146.820 4190.60 4295.05 8410.10 66.200 148.400 4227.84 4332.29 8505.96 65.620 148.400 4266.97 4371.42 8601.71 65.450 148.710 4306.62 4411.07 8694.31 66.070 147.640 4344.64 4449.09 8788.55 65.850 147.760 4383.03 4487.48 8882.37 65.950 147.800 4421.34 4525.79 8958.55 65.670 147.790 4452.56 4557.01 9053.05 65.580 148.530 4491.56 4596.01 9150.18 65.210 147.430 4532.00 4636.45 9242.49 65.410 148.740 4570.56 4675.01 2357.12 S 4208.42 E 5956926.02 N 564897.97 E 2429.58 S 4253.95 E 5956853.94 N 564944.09 E 2500.88 S 4298.22 E 5956782.99 N 564988.93 E 2573.53 S 4343.42 E 5956710.71 N 565034.72 E 2645.41 S 4387.96 E 5956639.19 N 565079.84 E 2718.98 S 4433.09 E 5956565.99 N 565125.56 E 2794.05 S 4478.39 E 5956491.29 N 565171.46 E 2864.98 S 4521.35 E 5956420.71 N 565214.99 E 2938.32 S 4565.43 E 5956347.73 N 565259.67 E 3014.05 S 4610.62 E 5956272.36 N 565305.47 E 3083.98 S 4653.60 E 5956202.78 N 565349.01 E 3158.60 S 4700.73 E 5956128.54 N 565396.74 E 3230.92 S 4746.22 E 5956056.59 N 565442.81 E 3304.30 S 4793.02 E 5955983.60 N 565490.20 E 3376.72 S 4840.18 E 5955911.56 N 565537.94 E 3448.83 S 4885.92 E 5955839.82 N 565584.27 E 3523.36 S 4931.78 E 5955765.66 N 565630.72 E 3597.71 S 4977.24 E 5955691.68 N 565676.79 E 3669.45 S 5021.77 E 5955620.30 N 565721.89 E 3742.20 S 5067.76 E 5955547.93 N 565768.47 E 3814.65 S 5113.42 E 5955475.84 N 565814.71 E 3873.45 S 5150.46 E 5955417.34 N 565852.22 E 3946.58 S 5195.87 E 5955344.59 N 565898.22 E 4021.45 S 5242.69 E 5955270.10 N 565945.64 E 4092.64 S 5287.02 E 5955199.27 N 565990.55 E Dogleg Rate (°/lOOft) 0.61 1.39 0.81 1.22 1.09 0.99 0.16 0.34 0.39 0.07 1.59 0.29 0.39 1.01 0.48 1.64 0.61 0.34 1.25 0.26 0.11 0.37 0.72 1.10 1.31 Vertical Section 4607.68 4691.57 4773.75 4857.55 4940.34 5024.75 5110.37 5191.38 5274.92 5360.95 5441.24 5527.80 5611.56 5696.99 5781.97 5865.75 5951.37 6036.59 6119.26 6203.68 6287.65 6355.79 644O.O8 6526.61 6608.75 Phillips Alaska Kuparuk 1D Comment Continued... December, 2000 - 6:49 - 5 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for 1D-32 MWD Your Ref: AP15002298200 Surveyed: 30 November, 2000 Kuparuk River Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 9336.40 65.370 150.460 4609.67 4714.12 9428.67 64.870 151.050 4648.49 4752.94 9523.65 65.410 149.030 4688.43 4792.88 9618.29 65.200 148.130 4727.97 4832.42 9712.50 66.360 149.220 4766.62 4871.07 9806.28 66.210 149.010 4804.33 4908.78 9901.24 65.890 148.500 4842.88 4947.33 9994.90 66.280 149.600 4880.85 4985.30 10092.49 65.950 153.140 4920.37 5024.82 10182.21 65.640 151.260 4957.16 5061.61 10279.43 65.370 149.230 4997.47 5101.92 10373.28 65.570 148.700 5036.44 5140.89 10463.80 65.580 151.970 5073.88 5178.33 10558.08 65.850 148.230 5112.66 5217.11 10652.04 67.450 145.750 5149.91 5254.36 10746.39 67.990 147.050 5185.68 5290.13 10843.66 67.580 145.780 5222.46 5326.91 10933.09 67.190 146.830 5256.85 5361.30 11028.78 66.640 145.520 5294.37 5398.82 11121.51 66.210 145.980 5331.46 5435.91 11217.99 65.980 146.840 5370.55 5475.00 11311.41 65.610 145.410 5408.86 5513.31 11402.30 66.080 146.950 5446.05 5550.50 11500.47 66.380 147.560 5485.62 5590.07 11593.11 66.220 149.540 5522.86 5627.31 4166.28 S 5330.23 E 5955125.98 N 566034.35 E 4239.32 S 5371.12 E 5955053.28 N 566075.83 E 4313.97 S 5414.16 E 5954978.97 N 566119.47 E 4387.35 S 5458.98 E 5954905.96 N 566164.89 E 4460.74 S 5503.64 E 5954832.93 N 566210.14 E 4534.43 S 5547.72 E 5954759.60 N 566254.81E 4608.62 S 5592.73 E 5954685.77 N 566300.42 E 4682.05 S 5636.76 E 5954612.70 N 566345.04 E 4760.35 S 5679.51 E 5954534.75 N 566388.42 E 4832.74 S 5717.68 E 5954462.67 N 566427.17 E 4909.54 S 5761.58 E 5954386.23 N 566471.69 E 4982.70 S 5805.60 E 5954313.43 N 566516.30 E 5054.30 S 5846.38 E 5954242.16 N 566557.66 E 5128.78 S 5889.21 E 5954168.03 N 566601.09 E 5201.10 S 5936.21 E 5954096.08 N 566648.67 E 5273.82 S 5984.52 E 5954023.76 N 566697.56 E 5348.84 S 6034.33 E 5953949.15 N 566747.98 E 5417.52 S 6080.13 E 5953880.84 N 566794.33 E 5490.65 S 6129.13 E 5953808.11N 566843.92 E 5560.90 S 6176.96 E 5953738.24 N 566892.32 E 5634.37 S 6225.76 E 5953665.17 N 566941.71E 5705.11S 6273.25 E 5953594.81 N 566989.77 E 5774.01S 6319.40 E 5953526.29 N 567036.48 E 5849.58 S 6368.00 E 5953451.12 N 567085.68 E 5921.94 S 6412.26 E 5953379.12 N 567130.52 E Dogleg Rate (°/'~00ft) 1.67 0.79 2.01 0.89 1.62 0.26 0.60 1.15 3.33 1.94 1.92 0.56 3.29 3.63 2.96 1.40 1.28 1.17 1.38 0.65 0.85 1.45 1.63 0.65 1.96 Vertical Section 6691.89 6773.01 6856.77 6940.84 7024.81 7108.58 7193.38 7276.93 7363.14 7441.90 7527.82 7611.17 7691.17 7774.67 7859.47 7945.46 8034.15 8115.49 8202.25 8286.13 8373.00 8457.00 8538.73 8626.99 87O9.93 Phillips Alaska Kuparuk 1D Comment Continued... 15 December, 2000 - 6:49 - 6 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for rD-32 MWD Your Reft APl 5002298200 Surveyed: 30 November, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 11690.43 65.910 148.530 5562.34 5666.79 11780.55 65.370 148.150 5599.51 5703.96 11878.85 64.900 147.790 5640.85 5745.30 11968.18 64.350 148.470 5679.13 5783.58 12062.35 65.700 149.270 5718.89 5823.34 12155.18 65.230 150.080 5757.44 5861.89 12254.12 64.690 148.780 5799.32 5903.77 12344.26 65.950 150.210 5836.95 5941.40 12438.25 66.210 149.280 5875.06 5979.51 12536.17 66.840 148.770 5914.07 6018.52 12627.33 66.440 148.010 5950.22 6054.67 12721.38 67.450 149.040 5987.05 6091.50 12814.67 67.330 148.760 6022.91 6127.36 12907.22 66.920 149.110 6058.89 6163.34 13002.88 66.730 148.660 6096.54 6200.99 13093.88 66.430 148.540 6132.71 6237.16 13186.42 66.220 149.700 6169.87 6274.32 13260.01 65.890 149.460 6199.73 6304.18 13386.70 65.610 147.850 6251.77 6356.22 13483.11 65.370 148.190 6291.77 6396.22 13578.49 65.470 148.040 6331.44 6435.89 13675.52 64.650 148.030 6372.36 6476.81 13768.22 65.240 148.320 6411.61 6516.06 13865.21 64.390 148.270 6452.89 6557.34 13965.77 63.540 147.920 6497.02 6601.47 5998.21S 6458.02 E 5953303.22 N 567176.90 E 6068.09 S 6501.11E 5953233.69 N 567220.55 E 6143.70 S 6548.41 E 5953158.46 N 567268.46 E 6212.24 S 6591.03 E 5953090.27 N 567311.63 E 6285.31 S 6635.16 E 5953017.55 N 567356.34 E 6358.20 S 6677.79 E 5952945.01 N 567399.57 E 6435.38 S 6723.38 E 5952868.20 N 567445.78 E 6505.95 S 6764.95 E 5952797.97 N 567487.92 E 6580.16 S 6808.24 E 5952724.11 N 567531.80 E 6657.17 S 6854.47 E 5952647.48 N 567578.65 E 6728.44 S 6898.33 E 5952576.56 N 567623.09 E 6802.25 S 6943.51 E 5952503.12 N 567668.86 E 6875.99 S 6987.99 E 5952429.74 N 567713.94 E 6949.03 S 7031.99 E 5952357.06 N 567758.53 E 7024.32 S 7077.44 E 5952282.14 N 567804.58 E 7095.59 S 7120.94 E 5952211.22 N 567848.66 E 7168.33 S 7164.44 E 5952138.84 N 567892.74 E 7226.33 S 7198.49 E 5952081.12 N 567927.26 E 7324.97 S 7258.58 E 5951982.96 N 567988.14 E 7399.38 S 7305.04 E 5951908.93 N 568035.20 E 7473.03 S 7350.85 E 5951835.65 N 568081.61E 7547.67 S 7397.43 E 5951761.39 N 568128.79 E 7619.03 S 7441.71 E 5951690.39 N 568173.64 E 7693.70 S 7487.84 E 5951616.10 N 568220.37 E 7770.40 S 7535.59 E 5951539.78 N 568268.74 E Dogleg Rate (o/.~ooft) 1.00 0.71 0.58 0.92 1.63 0.94 1.31 2.01 0.95 0.80 0.88 1.47 0.31 0.56 O.48 0.35 1.17 0.54 1.18 0.41 0.18 0.85 0.70 0.88 0.90 Vertical Section 8796.74 8877.08 8964.47 9043.51 9126.88 9209.09 9296.44 9376.23 9459.85 9547.51 9629.39 9714.02 9798.11 9881.37 9967.25 10048.89 10131.58 10197.08 10309.98 1O395.92 1O48O.87 10567.06 10649.29 10735.19 10823.69 Phillips Alaska Kuparuk 1D Comment Continued... 15 December, 2000 - 6:49 - 7- DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for 1D-32 MWD Your Reft AP15002298200 Surveyed: 30 November, 2000 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 14062.40 63.120 146.980 6540.40 6644.85 7843.19 S 7582.05 E 14068.73 62.650 147.170 6543.28 6647.73 7847.92 S 7585.11 E 14138.00 62.650 147.170 6575.11 6679.56 7899.62 S 7618.47 E Global Coordinates Northings Eastings (ft) 5951467.37 N 568315.79 E 5951462.67 N 568318.89 E 5951411.24 N 568352.66 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.354° (09-Dec-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 136.460° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14138.00ft., The Bottom Hole Displacement is 10974.74ft., in the Direction of 136.038° (True). Dogleg Rate (°/~OOft) 0.97 7.89 0.00 Vertical Section 10908.45 10913.99 10974.45 Phillips Alaska Kuparuk 1D Comment PROJECTED SURVEY Continued... 15 December, 2000 - 6:49 - 8 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for 1D.32 MWD Your Ref: AP15002298200 Surveyed: 30 November, 2000 Kuparuk River Unit Phillips Alaska Kuparuk 1 D Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 14138.00 6679.56 7899.62 S 7618.47 E Comment PROJECTED SURVEY Survey tool program for 1D-32 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 14138.00 6679.56 Survey Tool Description MWD Magnetic December, 2000 - 6:49 - 9 - DrillQuest 2.00.05 1D_32~ Annular~ injection LOT tI~I' . ~~ ~ ~n ~ ~ ~%O ~~~~~( ' Subject: 1D-32 Annular Injection LOT _ ,~_~ ~..~'-~'-~' r- ,.~"~ ~ Date: ,Mort, 8 Jan 2001 16:3.,,8:23-1000 ~ro,3~~ r.J '~ >,.--¥~'-~-t-'~ t.,,, ~ From: 'Thomas A Brockway <TBROCKW@ppco.com> ~.~.~.~ ~.,.% ~. ~,~,.~.\~ ~.~,,.~(~.~, ~ To: tom_maunder~admin.~ate.ak, us ,, ~e ~~,~~ ~~~ ~ ~~ CC: "James A Trantham" <~NTH~ppco.com>, Todd J Mushovic <TMUSHOV~ppco.com>~ ~' As per our discussion on the 1D-32 reque~ for Annular Disposal, I e to track down the following information: 1) As indicated in Todd Mushovic's e-mail to you dated 1/4/01, there are no wells within 1/4 mile of the 1D-32 casing shoe. The nearest well is 1D-30, located 1525' away. Based on this information, no further data should be needed to satisfy the first five requirements listed in Julia Heusser's 12/29/00 e-mail to James Trantham. 2) After researching the 1D-32 Annular Injection LOT as per point 6 of Ms. Heusser's e-mail, I was able to find the following information: An injection pump was used to perform this LOT, hence the small 0.0197 bbl/stk output. The annular injection LOT which was submitted to the state was the second one performed on this well. The initial LOT was run as per SOP and obtained good results, leaking off at 13.4 ppg. Unfortunately, the company man on location neglected to record the shut-in pressure for the required 10 min. at the end of the test. After displacing the well to an 8.5 ppg annular fluid, he discovered his error and ran a second test. After performing the first LOT and flushing the annulus, a residual 550 psi surface pressure was present at the wellhead prior to beginning the second test. I have attached copies of both LOT tests for your review. (See attached file: 1D-32 ann. inj. LOT#2.xls)(See attached file: 1D-32 ann. inj. LOT CIT.xls) I hope that this answers your questions and will allow you to expedite the 1D-32 permit approval process. If you have any other questions or desire further information, please don't hesitate to contact me. Sincerely, Tom Brockway Drilling Engineer- Phillips Alaska, Inc. Ph: (907) 263-4135 Fax: (907) 265-1535 l [ Name: 1D-32 ann. inj. LOT#2.xIs t LOT#2 xls~ Type: Microsoft Excel Worksheet (application/vnd.ms-excel)1 ~1D-32 ann. inj. '~ Encoding: base64 t .Description' Microsoft Excel 97 ..................... 1 ....... I ......................................... '~'~' ............................................................. ~ 1 of 2 1/9/01 9:00 AM 1 D-32 Annular Injection LOT · ~1D-32 ann. inj. LOT CIT.xIs Name: 1D-32 ann. inj. LOT CIT.xIs Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 Description: Microsoft Excel 97 2 of 2 1/9/01 9:00 AM 1D-32 Annular Disposal · Subject: 1D-32 Annular Disposal Date: Thu, 4 Jan 2001 17:02:15 -1000 From: "Todd J Mushovic" <TMUSHOV@ppco.com> To: tom_maunder@admin.state.ak, us CC: "Thomas A Brockway" <TBROCKW@ppco.com>, "James A Trantham" <JTRANTH@ppco.com>, "Sharon AIIsup-Drake" <SALLSUP@ppco.com> Tom, I have investigated to see if there were any wells within a 1/4 mile radius (1320') of 1D-32s surface casing shoe and have found no wells. The closest well was 1D-30 and it was 1525' away. Please let me know if there is any additional information that you need to approve the 10-403 form for annular disposal. Thanks Todd Mushovic 265-6974 1 of 1 1/8/01 2:37 PM KRU 1D-32 Annular Disposal Subject: KRU ID-32 Annular Disposal Date: Fri, 29 Dec 2000 16:18:19 -0900 From: Julie Heusser <julie_heusser@admin.state.ak. us> To: James Trantham <jtranth@ppco.com>, Brian Noel <bnoel@ppco.com> CC: Tom Maunder <tom_maunder@admin.state.ak. us> Hello Brian and James, Have a safe and happy New Year. We would like to finish the review of KRU 1D-32 form 10-403 for annular disposal. To do this we would like some additional information. 1. A list of all wells within 1/4 mile ofthe surface casing shoe. 2. Annular disposal volumes for these wells including the begin and end date. 3. The excel spread sheets for LOT's and surface casing pressure tests for these same wells, 4. Spider map ofthe 1/4 mile with the disposal volumes identified at the surface casing shoe. 5. Any additional annular disposal information on any of the wells. 6. An evaluation/explanation of any "unusual" LOT information. The use of this information is to help determine whether a well with "unusual" LOT characteristics may need to be monitored more dosely during annular disposal operations. Cheers Julie Heusser 1 of 1 1/8/01 2:38 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other_X Annular Injection 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development _ Exploratory __ Stratigraphic _ Service _X 4. Location of well at surface 417' FNL, 420' FEL, Sec. 23, T11 N, R10E, UM (ASP: 560671,5959249) At top of productive interval 2404' FSL, 1630' FWL, Sec. 30, T11N, R11 E, UM (ASP: 568068, 5951576) At effective depth At total depth 2271' FSL, 1711' FWL, Sec. 30, T11N, R11E, UM (ASP: 568151,5951442) 6. Datum elevation (DF or KB feet) RKB 34' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 D-32 9. Permit number / approval number 200-173 10. APl number 50-029-22982-00 11. Field / Pool Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total depth: measured 14138' true vertical 6679' Effective depth: measured 14068' true vertical 6647' Casing Length Size Conductor 86' 20" Surface 8972' 9.625" Production 13290' 7" Liner 953' 3.5" feet Plugs (measured) feet feet Junk (measured) feet Cemented 15 cu yards ABI, type III 490 sx AS III, 450 sx LiteCRETE 490 sx Class G ~25 sx Class G Measured Depth True vertical Depth 120' 120' 9006' 4576' 13324' 6330' 14136' 6678' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) , ¥ : .. None ' ','~" 3.5", 9.3#, L-80 @ 13255' Baker ZXP pkr @ 13191', No SSSV ORIGINAL RECEIVED DEC 1 5 201 0 Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal_ Detailed operations program m BOP sketch __ Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets _X 14. Estimated date for commencing operation January 10, 2001 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended Service _X 17. I hereby cirtlfy that t~s true and correct to the best of my knowledge. Signed !?~ J. r~antha~n l'~(...~' ~ ~') ~ Title: Drilling Engineering Supervisor FOR COMMISSION USE ONLY Questions? Call Todd Mushovlc 265-6974 Date iff J~eC-.. Prepared by Sharon Al~sup-Drake Plug integrity __ BOP Test. Location clearance _ , Mechanical Integrity Test _~, Subsequent form required 10- . - A__pproved by order of the Commission ORIGINAL SIGNEID BY commissioner Date /"~/~" Of D Taylor t~-n~io~hi Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Phillips Alaska Drilling Cementing Details Well Name: ID-32 Report Date: 11/19/2000 Report Number: 1 Ri~l Name: Nabors 16E AFC No.: AK0106 Field: KRU i i Casing Size Hole Diameter: I Angle thru KRU: Shoe Depth: I LC Depth: % washout: 9.625" 12.25'I N/A 9006'I 8887 Centralizers State type used, intervals covered and spacing Comments: Ran 1 spirogllder per joint to 500' above the shoe (13). Ran I bow spring centralizer every 3 joints f/500' above shoe to surface (69). Mud Weight: PV(prior cond): PV(after cond): [ YP(prior cond): YP(after cond): Comments: 9.8+ 55 20I 59 19 Gels before: Gels after: Total Volume Circulated: 22/29 7112 2067 bbls 1st stage. 770 bbls 2nd stage Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 bbls 8.4 Spacer 0 Type: Volume: Weight: Comments: MUDPUSHXL 50 bbls 10.5 , Lead Cement 0 Type: I Mix wtr temp: .~,No./f~cks:"~ Weight: Yield: Comments:.. ASIIII 75 5/490 I to.7 4.44 ^dd,t,ves: ii o ,i o Class 'G' wi 20.135 gal/sk Fresh water, 30% D053, 0.69~Yo D046, t.5 Yo D079, 1.5 Yo S001, 50% D124, 9% D044 :., ... :: : . LitaCR~TE :'. i:. :: ' Additives: .. Class 'G' wi 8.270 gsl/sk Fresh Water, .650% D065, 0.1% D046, 0.3% D079 DisplaCement 0 ': Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Commentsi.i ' : : .:;6bpm 5bpm N/A , :: ., : ' i' : ' Reciprocation length: Reciprocation speed: Str. Wt. Down: 'i ' .; : :' N/A N/A N/A Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 674 / 159 676 / 161 Calculated top of cement: CP: Bumped plug: Floats held: 2102' Date: 11/19/00 Yes Yes Time:04:$0110:30 Remarks:Casing was stuck for a short while @ 6920'. Once on bottom was unables to reciprocate casing. 1st Stage; Begin loosing returns w/5600 stks Into displacement & lost complete returns w/6500 stks. Bumped plugs & opened Stage collar. 2nd Stage; Mud Wt.,9.6, Vis S2, PV 20, YP 19, Gels 7112. Had full returns thru 2nd stage Job. Pumped 30 bbls H20 w/red dye, 378 bbls Lead cement @ 10.7, 10 bbl$ Tall cement @ 15.8, dropped closing plug, 10 bbls H20. Had water to surface wi 311 bbls pumped & good 10.7 cement w/368 bbls Lead cmt pumped. Displace cement w/rig @ 6 bpm. Closed stage collar w/1400 psL Checked for flow back OK. Circulated 170 bbls cement back to surface. ClP @ 10:30 hfs 11119/00 Cement Company: Rig Contractor: Approved By: NABORS Fred Herbert Dowell p, ECE F---O Phillips Alaska lnc casing Detail 9-5/8" surface casing WELL: 1 D-i~2 Date; 11/' 7/00 1 OF I PAGES # ITEMS cOMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH Nabors 16E RKB = 34.10' TOPS , 9 5/8" LANDING JT (RKB) 34.10 9 5/8" FMC GEN V Fluted Mandrel Hanger 1.60 34.10 Jts. 170-2209 5/8" 40~ L-80 BTCM Casing (51 jts.) 2067.07 35.70 Weatherford Model 754 Stage Collar 2.90 2102.77 Jts. 4-169 9-5/8", 40#, ~L-80 BTCM Casing (166 Jts) 6781.87 2105.67 ,, Weatherford Insert Shut Off Baffle 8887.54 Jt. 3 9 5/8" 40~ L80 BTCM Casin~'( 1Jt:! ...... 37:.21 I 8887.54 Gemeco Float Collar 1.53 I 8924.75 Jts. l-2 9 5/8" 40#,L80 BTCM Casing (2J.,ts.) , 78.74 .,J 8926.28 ..... Gerneco Float Shoe ..... 1,70 9005.02 ............. 9006.72 12-,]/4"TD 9017'MD ,,4~0'TVD ......... , ,,,.,,., ., ...... , ,,,.,, ,, ...,.., ................ i" Baker Lock Jts 1-4. M~Ee"~p casing to base o~ triangle; Use Bed-O'-Life'2000 Pipe Dope.' ........................... 2. Run bowsp,ring centralizer over stop ring 10' above shoe. spiraglider.0,n, ~,,,.2,,.'and b°W?pring cen!,...,!n center of jt 3. ' ................ , .......... '[ " 3. Run, aluminum,, ,, ,,. baffle In top of jt 3. , ..................... r 4. The Stage Collar..goes between Jts. 169 & 170. 5. Install bow sPririg centralizers on its. i"69& 170 in the Center .,',, ', of the Joint,'with stop collars. 6. There will be 5 j01nts I~ft in the pipeshed ..... 7. Run' Bow spring centralizers every :~ its. on its 16-218. ' ......... ji 69 Total Remarks; String Weight w/ Blocks, 350k Dn, I0'5~c~ Up, 70k Blocks. Ran 220 Jts of Casin~l. Casing' was Drifted w/ 8.679" Teflon Rabbit. Used Best-O-Life 2000 on all connections. CASING TEST and FORMATION INTEGRITY TEST Well Name: ID-32 Date: 12/5/00 Reason(s) for test: Supervisor: G.R. Whiflock [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9.625", L-80, 40~, BTCM Casing Setting Depth: 9,006' TMD Hole Depth: 9,052' TMD 4,577' TVD 4,596' TVD Mud Weight: 8.5 ppg Length of Open Hole Section: 46' EMW = Leak-off Press. + Mud Weight -- 1,000 psi + 8.5 ppg 0.052 x TVD 0.052 x 4,596' EMW for open hole section = 12.7 ppg Pump output = 0.0197 bps Fluid Pumped = 10.8 bbl 3,200 psl 3,000 psi 2,900 psl . 2,800 psi 2,700 psi 2,600 psi 2,500 psi ....... 2,400 psi / 2.mo ps~ : LEAK-OFF IESI 2,200 psi 2,100 psi --e--CASING TEST 2,000 psi tgoo psi ~ LOT SHUT IN TIME tsoo ps~ I r ~ CASING TEST SHUT IN TIME 1,700 psi ~,6~o ps~ I TIME LINE %500 psi 1,400 psl 1,300 psi 1,2oo ps~ 1,100 psi 8O0 psi 700 psl 600 psi "~ 500 psi 400 psi t 200 ps1 ~oo psi 0 psi STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE 0 stks 550 psi 25 stks 600 psi 50 stks 650 psi 75 stks 700 psi ................. !_O~.s..t.k..s. ....... ~o_.o.p~[ .... t25 stks 750 psi .................. !._s.e___~_~_s. .... ___s_ ?. ?_ _p_ .s_ [ .... .................. !_T.s..?.~_s_ ..... .s_?.?_p.s_[ .... ............. ~...~_o.o__?_~_~_ ...... .s..s.?_ _p_s_L' ~- ................ .2_2_s.?.~_~_ ...... _s__s..o__p..s.[.._~ : 250 stks 900 psi i' ................ '" ............... ~ ............. :'-"l , 275 stks 900 psm , : 300 stks 950 psi ,. ................. .3__z_s___~_~__~ .... ~.s_.o__p_~[ .... , i ~;ost.~ .~o.si ,_ ................ .3.Ls__s_~_s___~ .... ~.s_?__p._s_[ .... , [ -,. 400 stks .. 1,000 psi ! ................................................. ,_ ................. 4._2. s_.s._~_s_ ...... j.,.o..o.o_..p.~!_.. : 450 stks 1,000 psi [ .,. 500 stks , 1,000 psi , 525 stks 1,000 psi r ................ '" ................ ' ............... :'-I , 550 stks 1,000 psm , ! SHUT IN TIME SHUT IN PRESSURE .... _0_ ...O...m.i..n_ ....................... _1_,._0_0_ .0_ _ .p.s. ! _ .. 1.0 min 950 psi .... _2__.o___m. Ln' ........................ ~.s_o._.p__s_[ .... 3.0 min 950 psi CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE 0 stks ; 0 psi 4stks i 75 psi 8stks ! 175psi ................... .1__~_ ~_t.k_ .~___ i.__ .3_ .0..0..P_'j .... 16stks i 475 .................... _2_ _o__~_~ .~_. _ L. J.o..o. ~! .... .................... _2__~j_t~.~...~ .. 7. ~_o. 72! .... ...................... ~.~_~.~_._ ,,' .__~Z.~_?2! .... 32~tk~ i 1,000 40stk$ [ 1,250 .................... ~_~_t~?_._L. J_:_~!L~.?:._. , ................... ~.~_~t~.~...£.j.,_~.o__o__?_?:._. ................. ,.__ ~_2. ~_t~_~_._,[_._%~_o__?~!._ i 56stks | 1,800psi ................. l---i~i~-;ii~;---T--¥;~-~-i,-;¥-~ ..................... _S_.S_~_t.k..~_._ '~_.~:_~?_~_~_?.L_; 72 stks ! 2,350 psi ' .................................. I' .............. '.--'I 76 stks i 2,500 ps~i SHUT IN TIME SHUT IN PRESSURE ....o_:?...m.j.,. ....................... _2.:_5._o.o_._p.?L_ 1.0 min 2,500 psi 2.0 min ; 2,500 psi 3.0 min i 2,500 psi 4.0 min i 2,500 psi ........... ~ ..... , ................................ ~"I .__._5_.o_..m_,_,.___; ................... ~,__s.o_.o___,_?:_..: 6.0 min j 2,475 psi .... ._7__o__.m_j_,_ .................... :___~,__47_.s___p._~!..., 5.0 min 950 psi 6.0 min 925 psi 7.0 min 900 psi 8.0 min 900 psi 9.0 min 900 psi 10.0 min ....................................... ~_o..o.~[ .... 10.0 min i 2,475 psi i ___!.5.:.o_..m_j_,. ................... ,__~,._47__s.._p..s.i..', 20.0 min ! 2,475 psi i ' ................. f ................ .-? ................. ....~.5.:.o...m.j?... I ................. :....z.;.47.?__p._sj..., .... .3_°...°...m_i."_._j ................ i.. ~,__47..s___p.?.i__j NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: t D-32 Date: 12/3100 Reason(s) for test: Supervisor: G.R. Whitlock [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9.625", L-80, 40#, BTCM Hole Depth: 9,052' TMD Casing Setting Depth: 9,006' TMD 4,577' TVD Length of Open Hole Section: Mud Weight: t0.t ppg 4,596' TVD 46' Leak-off Press. + Mud Weight 0.052 x TVD -- 800 psi + 10.1 ppg 0.052x4,5~' EMW for open hole section = 13.4 ppg Pump output = 0.0197 bps Fluid Pumped = t0.1 bbl 3,200 psi 3,~oo,:~1 I I I I I I I 3,ooo ps~: LEAK-OFF TEST 2,900 psi 2,mo ps~ --a--CASING TEST r 2,700 psi 2,6m ps~ -"~'-LOT SHUT IN TIME )NE 2,~pSl ~ CASING TEST SHUT IN TIME 2,~ psi 2,~pSl I TIME LINE 2,~ psi 2,1~ psi ~ 2,~ psi 1,~ psi ~ 1,7~ psi 1,~ psi ~ 1,~ psi 1,~ psi 1,~ psi 1,~ psi 1,1~ psi 1,~ psi ~ ~ psi ~ ~ psi 7~ psi j ~ psi ~ ~ ~ psi ~ ~ ~ ~ psi ~ ps1 J ~ ~ psi opst ~ : ~ TIME LINE STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE L ~_ 0 stks 0 psi .................. .2_s...s_tk__s ........ _o__p_.s_! ..... 50 stks 0 psi ................... . _T s_ ?. t_ _k_~_ ........ .o_~j ...... 100 stks 0 psi ................... !_2_s_._s.~_~. ...... ! o_ .o_ .p_ _s_ [ .... ................. !_Eo_._s._U,__s_ ....... _?_ .o_ .p_ _s_ [ .... ................. !.?_s_.?.~_.~_ ..... .?_s_.pZ .... .................. 2__0._0_ .s_~.s. ....... _3_5_ .0_ .p_ _s_ [ .... .................... _2._2_S__?.~_~_ ...... .3Z.o_.p_~[ .... 250 stks 550 psi .................... .2.~_s.._s.~_s_ ...... .s_5_.o__p__s_[___ .................. _3..0.0__s.t.k_s._ ...... .7_ .s_ .o_ .p_ ~ [ .... ................... _3.2__s___s..U,._s. ....... .7_ .o_ .o_ .p_ _s_ [ .... .................. .3._S.0..?.~ ....... .S__0_.0_.pZ .... ................... _3.?_S___s.t__k~_ ...... Z.s_.o_p_s_[ .... ................... .4..0.0...s_t..k_s_ ...... ~ 2_ .S_ __p _s_ [ .... .................... .4._2_S___s.~_s_ ...... ]_.o..o..p..sL. ................... .4._s_o__?.~_?_ ...... ~o_.o_.p_~[ .... 475 stks 700 psi .................. .S._0_0___~.t__k.s_ ....... .7_ .o_ .o_ .p_ .s_ L _ j 515stks ! 700 psi SHUT IN TIME SHUT IN PRESSURE 0.0 min ....................................... Z_O_.O_.p_~t .... 1.0 min 2.0 min 3.0 min ................ ! .................................... i- -1- 4.0 min 5.0 min 6.0 min ................ i .................. ! r ................ .-r ................ .i .................. 8.0 min [ 9.0 min [ i. .................................. I .................. 10.0 min [ i. ................ .i. ................ j .................. j CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ................ 1 .... ;.--%~ ...... T ..... ~ .... ~' .... I I ' I ; 4stks i 75ps~ 8 stks t 75 psi . _..1_.2_ _s. _t.k_.s_. _, 300 psi ................... 16 stks .... ................ L__.2_lO_.s..t.k_.s_ ...... .6_ _o_ .o_ _p. _s_ L _ i 24 stks 750 psi 32 stks 1,000 psi ................. L__.3._6_~.tk._~_ ..... J_,!.2.Lp..sJ._] .................... ~.o..s.~.s. ..... j.;.2Ao._e.?j_j 44 stks 1,375 psi i ................ ~ ................ ~ ................. -t i 48stks i 1,500psi ................. :'-~';;A;'"T"i';~'~6-~;;,i"! .................. ~ ................ + ................. ~ 56stks [ 1,800psi ................. ~ ............... ~................ ................ :_...6..o. ?..tk.?... ,]...j.,_~.~.~_e.?Lll ................. ................. ]------Z~-- .s..t.k..S__I__i____.2--'__.S~.O.__.P.?j____ i i i 76stks [ 2,500 psi j SHUT IN TIME = SHUT IN PRESSURE 0.0 min ', 2,500 psi i .... ~:2--~J~''''] ................... .2.'I.~.O..O...P.?L. 3.0 min ~ 2,500 psi 4.0 min ~ 2,500 psi 5.0 min ; 2,500 psi 8.0 min I 2,475 psi 9.0 min 2,475 psi 10.0 minj ~_ 2,475 psi ,.Z°.:.°_._m. Ln___i .................... ....2J:.o...m.j.n... ~ .................... .2.,.4Z~..p.?.i..' 30.0 min i 2,475 psi ................. 4 ................ J.- .................. NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1D-32 Date: 11/21/00 Supervisor: Fred Herbert Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9.625', L-80, 40~, BTCM Casing Setting Depth: 9,006' TMD 4,577' TVD Hole Depth: 9,052' TMD 4,596' TVD Mud Weight: 8.4 ppg Length of Open Hole Section: 46' EMW = Leak-off Press. + Mud Weight 0.052 x 'rVD = 1,175 psi + 8.4 ppg 0.052 x 4,596' EMW for open hole section = 13.3 ppg Pump output = 0.04)46 bps Fluid Pumped = 7.3 bbl 3.1oop= --~-LEAK-OFFTEST ' - z~o p~ *"'"a~CASING TEST -' I ZS~0 ps ~=~ l~~-~s~, ...... 1... '. zsmm --~'-CASINGTESTSHbrrlNTIME ~ ':'- ' .... ~ ............. z4~om --+--TIME UNE 2,3~0 ps 1.900 psi L600 p~ ..... ~.~o~ ~,~ ~ ...... 1'~' - ~ J I ~,~ ,,._ l~i ~ J -, ~ ' S1110~S LEAK-OFF DATA MINUTES FOR ........ LOT .......... S3~&( ~ ES ...... P~E. J~.UBE_ = . 44 stks 1,150 46 stks b,_.l.~ 60 stks 1,050 psi ~ 70stks _._l,~~_i__j 86 stks _ 1,050 Es_i~ , ; i ,I I I 0.0 min 1.0rain , ~ 1,000~si ~ 2.0 min ; . 1,000..__/~.!.. 3.0 rain 4.0 rain 5.0 rain : j 975~.i .... 6.0 rain : ; 975 [~.i._. · 7.0mm : : 950 psi 9.0 min 10.0 min T J 950.[:~_i_ CASING TEST DATA MINUTES FOR _.C,S~3~.S~ ....... S'JjBg~S~ ......... I~ESSU~_i;_ ..... .......... 0stks , ...... Opsi . · 4 stks 75 I~.L_~ ~.~..~.~....k.~~..a~ ...... 8 stks 175 psi .......... · 24 stks ~-_ 750 28 stks 875 ~____~ ........... ~2,~ 1,ooo .......... ,?_~__Es__~ 36 slks _1.:.1_2.5_Es_L~. 44 stks 1,375 psi ~s stks [j,~_~j.] 52 stks i 1,650 9si 56 stks 1,800 psi 's4 st~s ,.__2_:.~ZS.j~_=L~ 72 stks ~ 2,350_1~_i 7 ............... ~ll/T IN l'l~E SHUT IN PRE~JURE · 'ri 0.0 rain 2,500 os~ 1.0 min ' ' · 2.0 min 2,500 I~i ~.o rain ............... ~,__s~.. psi___j ~_._4._0 rain ............ 5.0 rain J 2,500 psi ~.o mi, r'~,~%~ 7.0 min ' ' ' 8.0 rain J 2,475 I~.i_j.,' 10.0 rain j 2,475 ~.i ....... ---=~F-- ...... -¢- .......... .--1 15 0 m~n I J 2,475 ps~ '-~-' ..... ~ 1 ....... '~ .... '1 20.0 rain J j 2,475 psi , 25.0 min ,,,_._2.,.4_7~ 30.0 min : ; 2,475.~...i..~ NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Phillips Alaska Drilling Cementing Details Well Name: 1D-32 Report Date: 11/26/2000 Report Number: 19 Rig Name: Nabors 16E AFC No.: AK0106 Field: KRU Casing Size Hole Diameter: I Angle thru KRU: Shoe Depth: LC Depth: % washout: 7 8.5I N/A 13324 13242 Centralizers State type used, intervals covered and spacing Comments: One splrogllder per Joints with stop collars on Joints 1-20. One stand off band every third joint from 2000' TVD to KOP & then one every 5 joints to sudace. Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.9 32 19 25 15 Gels before: Gels after: Total Volume Circulated: 8/10 5/8 1100 Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 8.3 Spacer 0 Type: Volume: Weight: Comments: MUDPUSHXL 30 12.0 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: ' G 80 190I 15.8 1.17 ·. : : ' ' Additives: : · ~ :. . .. Class'G'w/5.104gal/skH20,0.200%D046,0.300%D065,0.150%D800 Tall Cement 0 i:. :: Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments:: ' : . ::: ' Additives: Dlsplaoement 0 Rate(before tail at shoo): Rate{tail around shoo): Str. Wt. Up: Comments: . 6bpm 3 bpm 300k : Reciprocation length: Reciprocation speed: Str. Wt. Down: : :' ~::': : .:" · 20' 20fpm 145k · :: Theoretical Displacement: Actual Displacement: Str. Wt. in mud: .. : · .. 507.1 507.1 Calculated top of cement: CP: Bumped plug: Floats held: 12524' Date:Ill26/00 yes yes Time:02:35 Remarks:Running casing & cementing went good with full returns thru out Job. Reciprocated casing until 10 bbls left In displacement. Pumped 5 bbls preflush, P.T. lines to 3500 psi, 15 bbls preflush, 30 bbls Mudpush XL @ 12.0 ppg, Drop bottom plug, 38 bbls cement @ 15.8 ppg, Drop top plug, 1 bbl cement @ 15.8 ppg, 10 bbls H20, Displace w/rig. Bump plug wi 5865 stks. Check floats OK. Displace cement @ 6 bpm until last 30 bbls drop rate to 3 bpm. Cement Company: Rig Contractor: Approved By: Dowell NABORS Fred Herbert RECEIVED A/aska 0ii & Gas Cons. Commission Casing Detail 7" Intermediate casina WELL: 1 D-32 Phillips Alosko Inc. DATE: 11/22/00 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Nabors .16E RT to LDS = 3'1.80' TOPS 7" Landing Joint (RKB) 32.80 7" FMC GEN V FLUTED MANDREL HANGER 1.58 32.80 jts 3-326 7", 26#, J-55 BTC-M©D (324 jts) 13207.43 34.38 Gemeco Float Collar 1.32 13241.81 jts 1-2 7", 26#, J-55 BTC-MOD (2 jts) 79.79 13243.13 Gemeco Float Shoe 1.45 13322.92 BTTM OF SHOE @ 13324.37 Shoe @ 13324 TD of 8-1/2" hole = 13335' MD 6334' TVD Run 1 spiraglider per joint on joints 1-20 w/stop collars. (Note; joints 1 & 3 will have bow springs due to float equipment) Run 1 centering guide on joints 263,266,269,272,275,278,281,284 287,290,293,296,299,302,305,308,311,314,31 7,320. Fluted Hanger goes on top of jt. 326 There will be 9 joints left in the shed. 327-335 Remarks: String Weights with Blocks: 300k Up, 145k Dn, 70k Blocks. Ran 326 joints of casing. Drifted casing with 6. 151 "plastic rabbit. Used Jet Lube thread compound on connections. Nabors 16E Drilling Supervisor: Fred Herbert CASING TEST and FORMATION INTEGRITY TEST Well Name: 1 D-32 Date: 12/5/00 Supervisor: G.R. Whitlock Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9.625", L-80, 40#, BTCM Casing Setting Depth: 9,006' TMD Hole Depth: 4,577' TVD Mud Weight: 8.5 ppg Length of Open Hole Section: 12,500' TMD 6,000' TVD 3,494' EMW = Leak-off Press. + Mud Weight = 1,000 psi 0.052 x TVD 0.052 x 6,000' EMW for open hole section = 11.7 ppg + 8.5 ppg Pump output = 0.0197 bps Fluid Pumped = 10.8 bbl 3,200 psi 2.900 psi --~--CASING TEST 2,800 psi 2.703 psi ....... i=~"'"' LOT SHUT IN TIME 2,600 psi ONE MINUTE TICKS :; 2.500 psi -~--CASING TEST SHUT IN TIME 2.~psi ~ TIME LINE 2,3~ psi 2,2~ p~ ~: 2,]~ psi 2,~ psi ].~ psi ].8~ psi ].7~ psi 1.~ psi 1,~ psi 1,~ psi 1.3~ psi 1,2~ psi 1,1~ psi ~ psi ~ psi ~ ~ 7~ psi ~ ~ ~si 0 psi STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ................ ~ ................ q. ................. ..[,- ................ r ............... -~ ................. -_. 0stks ] 550 psi ! 0stks 0psi ................ ..,. ................................ ~. ................ ~. ............... .~ ........ .~ ......... 25stks i 600 psi ~ [ 4stks 75 psi ................ d- ............... d. ................. d, , ................ i ............... i ............. ',--- 50stks J 650 psi : : 8stks i 175ps[ ~ ................ J_ ............... .t ................. ! ................. j. ................ ~ .................. ................... !_2__5__s_!_k__s__L__ Z_s_.°___P.S_] ................... !_S_9__s_!_k._s__ L_._8__°__°.._p.s.] ................... _! _7__5__s_!_k__s._j__. ~_0_.0_._P_S.! .... .................. _2_ _0_ _0_ _s_!_k. _s..j ... _8. _S_ _0_ _ _p_s_ ] ................... _2_ _~_ _5_ _s.!_k_?__ j __. _8_ _S_ _0...p_s_ ] .... .................. _2._~__O__s_!_k__s__i._. ~_O__O___P.S_] .... 275stks j 900 psi -i- ............... ~. .................. ................... _3_ _o_9_ _s_!_k_ _s_ _ L _ ~_5_ _0_ _ _P.S_ ] .................. _3_ _2_ _5_ _s_ !.k. _s. . j... ~_5__0._.p.s.] .... 350 stks i 950 psi .................. .4_ _O_ _O_ _s_ !_k_ _s_. ?_,_9_0__0__ R _s.L _. i 16stks 475psi ................. [__.2_.0_..s_t..k.s___. 600 psi i 24 stks 750 psi i 28 stks 875 psi i. ................ ~. ............... a ................. J 32 stks 1,000 psi ~ ................ I' ................................ ~ 36 stks 1,125 psi ~ 40 stks 1,250 psi ................. , J 44 stks [ 48 stks 1,500 psi ~ ................ ["~'~i'~; ..... '~';~'~'~-i;~'i- i i 56 stks 1,800 psi , ................. ~. ............... ~ = 60 stks 1,925 osi ................. F .......................... ~ ..... ~ 64 stks 2,075 psi j 68 stks ";~;~-66'~;~;f-! j 76 stks 2,500 psi .................. !?__S__s_!_k._s..i_.!,__O_O__O__R .sL, 500 stks i 1,000 psi ................. SHUT IN TIME SHUT IN PRESSURE 1.0 min 950 psi ................ /I ................ J, ................. ._._a_-P___m_lp___.' ................... _9_.s_P...P.S.L__j .__ _3_ -_o_ __m_ Ln_ ...................... .9..s_9_._P.S_!___i j i i SHUT IN TIME I SHUT IN PRESSURE .... bT~';~'i-~'"~ ............... l-"~;§b-b-¢k-i"! ..... L' ........... F ............... 4 ................. -I 1.0min j 2,500 psi ! '-'-~'.~';~'i'r;'"[ .................. E~'6'~-i~;F~- 3.0 min J 2,500 psi ,__._4:.o..m_i.n____[ .................. 50min J J 2,500 psi J ...... L' ........... I- ............... t ................. '{, .__..%9...m_j."____~ ............... i._.2_:_4.?~_R.s_[_i 7.0 min J j 2,475 psi i 4.0 min 950 psi j 8.0 min = ! 2,475 psi ................ · .r- ............... .v ................. · l- ................ J- ............... .4 ................. __5_:_o_ __m_lp_ ...................... _9..5_9. ._p.s_L.j .... _9:_o__.m._ i.n____L ............... L _2.,_4__7.5__ p__s_[_ j .... _6_:9___m_lp' ...................... .9_.2_.~_._p.s.L.j . __1.o_ :9...n2j.n.. _ L ............... j__.2_,_4__7.5__ p__s_[_j 7.0 min 900 psi J15.0 min J 2,475 psi ' ................................. ! ................. ! ' ................. I' ................................. 8.0 min ................i 900 psi ~ 20.0 min I 2,475 psi i 9.0 min 900 psi j 25.0 min i 2,475 psi i ................ 'r' ............... T ................. '~ r ................ r ........................ ''' ...... I · I ' , I · I · L__l_9_:g___m_t _n__ ,,_ ............... .~___.9_.o_.o_._p. sj___.~ L.__3.9:.o__.m_ j.n___; .................. _2_,_4._7_5_.R.s_:_~ NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Ic~s~ t~ ~ FOR: ~t~ p~t~d: ~7-~-2~ ~ol Refer~ ~ ~ v~n ~rdlnat~ are In fMl reler~ Trna Vnd{~l ~l~ am Phillips Alaska, Inc. Structure: Pad lO Well: ;52 Field : Kuparuk River Unit Loaation : North Slope, Alaska 100 80 40 (~ 20 (D ¢- 0 0 I ¥ 4O 6O 80 lOO 120 East (feet) -> 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 .300 ,:320 340 / ~31oo J lOO 0 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 2500 900 1000 11 O0 700 .... 500- ..... 800 ~t~500 800 900 1000 1100 1200 1300 1400 1500 e 500 700 800 900 1000 ..... ~--11 O0 1200 1300 1600 e 700 800 gOO 500 700 800 ~ 900 700 800 500 1200 1500 1800 2000 '~--- + 1300 1400 1500 ~2100 ° e-5°° ~ 2600 1 DO0 1100 1100 1000 1100 1200 1300 1200 1300 1200 ,e..-...... 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 200 280 300 320 340 East (feet) -> lOO 8o 4o 20 0 c' o 20 ¥ 40 6O 8O lOO 120 Phillips Alaska, Inc. Structure : Pad 1D Well : 32 Field : Kuporuk River Unit Locofion: North Slope, Alosko East (feet) -> 240 280 320 360 400 440 4BO 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 1080 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 240 2OO 160 120 8O 40 0 4O 80 120 160 200 240 240 200 ' ~ _ _ _ _ _~ 160 ~ ~9oo :::~_.__~21_ 00 ~ 1900 ' .__ _~---------------- ~ 120 _ ....... ~ ~00 ~ 2 ~ O0 4o ~ g~__~ 1500 1500 ~100 ----~~--~ ' ~oo .o 36 0 1500 1700~~~ ~900 · . ~00 ~40 280 320 360 4~ 440 4~ 520 5~ 600 640 ~0 720 760 800 840 880 920 . 960 1000 1040 1 Easf (fooO -> 80 40 Z 0 o Dot~ plotted: 17-~t'2~ ~r~not~ ore In f~t rlflren~ T~ V~col D.pth~ are ~fer~nc. RKB(No~m PhillipS Alaska, Inc. Structure: Pad 1D Well : 52 . Field : Kuparuk River Unit Locoflon : North Slope, Alaska 240 200 160 120 80 0 40 Z 80 120 16o 200 240 East (feet) -> 240 280 320 560 400 440 4BO 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 IOBO 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 1700 500 1500 2300 1900 170__0 ........... 25OO 27OO ~_~_____. ....__~b~_ __17~ . .-. _~7~ . . : . . . 2920 -- .13oo ~ - : ~ 2900 1300 ~ ~~~3oo ~ i~1~ i i i i 240 280 320 360 4~ 440 4~ 520 5~ ~0 640 680 720 760 800 840 BSO g20 g60 1000 1040 IOBO East (feet) 240 200 160 120 ' 80 40 Z 0 o :J' 40 8o 120 160 20O 240 C~ot~ ~ ~ FOR: MUSHOVIC Dotl plotted: 17-0ct-2000 PfoI Reference ~s .~9 Version 1115 . Coordlnot~s =r~ In f~t' ref.mnc~ slot t~32. rru. verticol Depths or. raf~r~nc~ RKB(Nobors 16£). Phillips Alaska, Inc. Structure: Pad 13 Well : 52 Field: Kuparuk Rlver Unit Location: Nor-ih Slope, Alaska 600 500 400 500 200 ~ 100 ..c o I v 200 300 400 500 600 Easf (feet) -> 700 800 900 1000 1100 1200 1500 1400 1500 1600 1700 1800 1900 2000 2100 2200 2500 2400 2500 2600 2700 2800 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 (~00 5500~0 2500 2500 21 O0 2500 1900 "' ~ ~ O0 '"' ~ --.- ... 3500 2300 2300 1900 ~o 2700 2900 -,. 2100 1900 2100 ,,2900 5100 -,. 2500 2300 2500 3300 2100 2700 5700 5900 4100 2500 3700 5900 '--. ~2700 4100 !900 5100 500 400 300 200 lOO 0 .4- 0 --I- 100 200 300 400 500 600 700 800 900 1000 11 O0 1200 1300 1400 1500 1600 1700 1800 1900 20® 21 O0 2200 2500 2400 2500 2600 2700 2800 Easf (feet) -> Phillips Alaska, Inc. 2O0 300 800 900 Structure : Pad 1D Well : 32 Fleld: Kuporuk River Unit Location : North Slope, Alaska East (feet) -> '3 1000 O 1100 2500 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 100 ~ I ~ ~ t ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ s ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 100 ~. 200 '~' ~2700 ~~~ 300 4OO 4500 ~ 400 ,3100 ~ ~ 500 N ~ N 500 500 ~' ~'----..~9 00 6OO \ 6OO x ~3oo \ 35oo ~ 700 \ \ 700 \ f700 ~ 5100 \ 5700 \ 5700 \ 6100 5500 1200 1200 6500 3900 6500 \ 1500 \ 1500 1400 \ 1400 5500 \ \' 1500 \ \ .= 1500 1600 \ 1600 5700 \\ ~ 1700 \ \ 1700 1800 % 1800 2.300 2400 2500 2600 2700 2800 2900 3000 51 O0 3200 3300 3400 3500 3600 3700 ,5800 3900 East (feet) -> 800 O 900 -4- 1 ooo t~ ~oo I V 1700 300 Phillips Alaska, Inc. Structure : Pad 1D Well: 32 Field : Kuparuk River Unit Location : North Slope, Alaska TRUE NORTH 350 0 10 2O 3100 3300 --- ~' 4O 3500 50 6O 290, 7O 280 8O 270 -F 90 260 100 240 110 120 250O l lOo / 1 50 200// 4300 160 2700 a o e Normol Plone Trovelling Cylinder- Feet 140 All depths shown (]re Measured depths on Reference Well 130 Phillips Alaska, Inc. Structure: Pad 1D Well : 32 Fleld: Kuparuk River Unit Location : North Slope, Alaska East (feet) 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 9200 1600 2000 2400 2800 3200 5900 O0 5500 \ \ \ 4300 k3700 \~ 3900 4500 \ \ 3600 \ 5500 4700 4100 4900 5100 4300~ \ 4500% 5300 50O ~5900 ~6300 5300 5500 4000 \ \ 57005700 470u\ 4400 61 O0 \ \ \ 3900 4900\ 6300 ' 3000 4800 - \ 5100%\ 5200 \ 5300 \ 5600 6000 6500 % 5500 \ 300 \ 4100 ~ 5700 \ \ 4500 \ \ \ % 4300 \ \ \ ~ 5900 \ \\ ~ 4500 \ \ \ \%6100 k 4700 \ \ % 6300 ~ 4900 \ \ \ \ \ \ \ 6400 6800 7200 7600 5700 6500 \ 5500% \ 5900 8000 \ 5700~, \ \ 5900'"\ 61oo 6300 \ 0 61 O0 o xx \ \ ~. 6300 \ oo h, 6500 \ \ o Xr~ 1600 2000 2400 2800 3200 3600 - 4000 - 4400 0 r 4800 ,--., 5200 5600 6000 6400 6800 7200 7600 8000 8400 , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , 8400 2800 5200 5600 4000 4400 4800 5200 5600 6000 6400 6800 7200 76008000 8400 BBO0 9200 East (feet) -> ALASI~A OIL AND GAS CONSERVATION CO~IMISSION James Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Kuparuk River Unit 1D-32 Phillips Alaska, Inc. Permit No: 200-173 Sur. Loc. 417' FNL, 420' FEL, Sec. 23, T11N, R10E, UM Btmhole Loc. 2173' FSL, 1770' FWL, Sec. 30, T11N, RI IE, 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 has not been requested as part office Permit to Drill application for Kuparuk River Unit Well No. 1D-32. Please note that m~y disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 1D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the armular space of a single well or to use that well for disposal purposes for a period longer than one year. Thc blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~aniel T..Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION 'DATED this b ~ day of November, 2000 l jr/Enclosures cc: Department ofFish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work:. Drill [] Redrill D I lb. Type o! well. Exploratory D Stratigraphic Test D Development Oil D Re-entry E] Deepen ~]I Service [~ Development Gas 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 ~2J.~"~5.'~. ,,t.,--~ Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 28248 ALK 591 ,¢,~' Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.0251) 417' FNL, 420' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 2440' FSL, 1612' FWL, Sec. 30, T11 N, R11 E, UM 1 D-32 #U-630610 At total depth 9. Approximate spud date Amount 2173' FSL, 1770' FWL, Sec. 30, T11 N, R11E, UM November 3, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1612 @ TargE feetI 1D-30 23.7' @ 540' feet 2560 14097 ' MD / 6644' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 250 MD Maximum hole angle 66° Maximum surface 3470 psig At total depth (TVD) 4177 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of Cement Hole Casin~ Wel~lht Grade couplin~ LenCh MD TVD MD TVD (include sta~le data) 20" 16" 91.5# H-40 Weld 86' 34' 34' 120' 120' 230 sx ASI 12.25" 9.625" 40# L~80 BTCM 8981' 34' 34' 9015' 4577' Stage 1- 490 sx ASLite, 450 sx LiteCRETE. Stage 2:460 sx AS Lite 8.5" 7" 26# J-55 BTCM 13321' 34' 34' 13355' 6342' 170 sx Class G 6.125" 3.5" 9.3# L-80 S H LT 892' 13205' 6281' 14097' 6644' 200 sx Class GasBIok 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) ,,eve,ica, feet Effective Depth: measured feet Junk (measured) ... . ,, true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production ~, ,~ , ,.,,., .; , .... :., Liner OCT 26 2000 Perforation depth: measured Alaska 0il & Gas Cons. Commission true vertical /~ch0m3e 20. Attachments Filing fee r~ Property Plat r-~ BoP Sketch r~ Diver, er Sketch D Drilling program [~] Ddlling fluid program ' r~ Time vs depth plot DRefractlon analysis D Seabed report D 20 AAC 25.050 requirements r-] 21. i hereby certifl; that the foregoing is true and correct to the best of my knowledge Questions? Call Todd Mushovic 265-697, Signed 0, ~ r'~ ~ Title: Drilling Engineering Supervisor Date ~. Trantharn Pret~ared hv Sh'aron Allsut~-Drak~ Commission Use Onl} Permit Number.2..~:~_.~ "' ["7 ~-~ I APl numberc,~_.o('' ,2..~'~___~'Z.. -~) I Approval date, Isee c°verletterother 50- I~ /"] I Q'O Ifor requirements Conditions of approval Samples required D Yes k--1 No Mud log required [~ Yes r'"~' No Hydrogen sulfidemeasures r~l Yes D No Directional surveyrequired [] Yes D No Required working pressure for BOPE r'-12M; E] 3M; r"l (~ E] 10M;[~ D Other: ORIGINAL SIGNED BY D Taylor Seamount by order of / ~ / Approved by Commissioner the commission Date l [ OO Form 10-401 Rev. 12/1/85 · Submit in triplicate GENERAL DRILL AND COMPLETE PROCEDURE EBA INJECTOR KRU 1 D-32 General Procedure: 1. Excavate cellar, install cellar box, set and cement 20" conductor to +/- 150' RKB. Weld landing ring on conductor. 2. Move in / rig up Nabors Rig 16E Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/9015 MD') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Run and cement 9-5/8" 40.0# L-80 BTCM casing to surface using lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with mud. Note: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 5000 psi. Record results. 6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 7. 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 FIT or LOT EMW). 8. Directionally drill 8-1/2" hole to mid-point of the HRZ (13163' 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 at to evaluate long string option. If LOT is adequate to long string, drill to well total depth (14097' MD), run 7" 26.0# J-55 BTCM casing to surface and cement, and continue with step #17. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030 9. If LOT is inadequate to long string, drill to 7" intermediate casing point (13355' MD). 10. Run 7" 26.0# L-80 BTCM casing to surface and cement. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030 11. Nipple up BOPE and test to 5000 psi. Record results. 12. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 13. 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 FIT or LOT EMW). 14. Drill 6-1/8" hole to well total depth (+/- 14097' MD) according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH 15. Run open hole e-line or drill pipe conveyed logs as needed. 16. 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. TJM, 10/23/00, vl 17. RIH with clean out BHA. Scrape casing. Displace well to completion brine. 18. Run and land 3-1/2" tubing with gas lift completion. 19. Pull landing joint. Install BPV. Nipple down BQP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 20. Freeze protect well. Set BPV. Release rig and turn well over to production. 21. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. TJM, 10/23/00, vl DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS KRU 1 D-32 Drillinq Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" Surface Casin~ 8.5-10.2 16-26 25-50 100-200* 10-20 15-40 7-15 9.5-10 6-8% Drill out to 7" Intermediate Casin[I 8.8-9.8 5-25 8-25 35-55 3-10 10-15 5-15 8.5-9.5 6-8% Drill Out to TD 11.3-13.0 25-35 20-30 50-65 4-7 4-8 8-10 8.0-8.5 4-7% Drilling Fluid System - Nabors 16E 3 - Derrick Shale Shakers Desander Desilter Mud Cleaner Centrifuge Degasser Pit Level Indicator (w/visual and audible alarms) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 180-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Two possibilities exist for the possible maximum anticipated surface pressure (MASP) seen by the surface casing string along the 1 D-32 well path. 1) MASP can be calculated using an expected leak-off of 13.1 ppg EMW (0.68 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that,,formation breakdown would occur at a surface pressure of 2609 psi. The leak off EMW was chosen based on an open hole LOT on well, 1 D-34, taken to 13.1 ppg at 4330' TVD (0.68 psi/fi). MASP = (4577 ft)(0.68-0.11) = 2609 psi 2) If surface shoe LOT is higher than expected and the well is drilled out of surface casing to TD, the MASP can be calculated based on a reservoir pressure of 3550 psi at 6506' TVD (0.55 psi/ft) and a gas gradient of 0.11 psi/ft. In this case, MASP would occur at 2863 psi. MASP = (6506 ft)(0.55 - 0.11) - 2863 psi Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of surface casing. In the event that the well has to be topset above the Kuparuk, the maximum anticipated pressure for the intermediate casing string would continue to 2863 psi as calculated previously. Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of intermediate casing if an intermediate string is needed. Based the anticipated pressures shown, a maximum mud weight requirement for this well is established based on the potential charging of the D-shale sands. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 11.0 ppg can be predicted as the maximum mud weight needed to safely conduct rig operations, assuming a TVD of 6426'. MW = [(6426 ft)(0.55)+150]/6426/.052 = 11.0 ppg In order to allow for a long string design, the minimum LOT in the HRZ or surface casing shoe must be greater than ECD (equivalent circulating density) with a 14.0 ppg drilling fluid as modeled or as measured with the Pressure While Drilling (PWD) sub, plus adequate safety margin. Well Proximity Risks: The nearest existing well to 1 D-32 is 1D-30. As designed, the minimum distance between the two wells would be 23.7' at 540' MD. Drilling Area Risks: Risks in the 1D-32 drilling area include surface interval hydrates, lost circulation, and potential borehole instability in and below the permafrost zone as well as through the intermediate shales. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and rheological properties which safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM), reduced circulating rates, and reduced mud weights as needed. Shale instability will be controlled primarily with the planned fluid densities. Additional risk exists with unpredictable charging of the D-shale sands during historic gas injection. These gas pressure risks are mitigated with mid-HRZ LOT's and a top set option above the D- shale based upon those results. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1D-32 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. At the end of drilling operations, a request for 1D-32 to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 1D pad, per regulation 20 AAC 25.080, will be submitted. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade 'Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC 3,090 psi NA 5,750 psi 4,888 psi 7" 26 J-55 3 BTCM 4,320 psi 3,672 psi 4,980 psi 4,233 psi 3Y2"* 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi *ifneeded Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). 1D-32 Kuparuk Well, 2 Stage Surface Cement loads and CemCADE* summary. Use 45 % excess below the Permafrost and 250% above. Drilled with 12 1/4" bit. 9 5/8", 47# casing TMD 9015', Stage Tool at 1975' MD. Tail Slurry TOC is @ 6669' MD ( $00' above the West Sak top). Base of the Permafrost at 1775' MD STAGE 1 Volume Calcs' Pump 20 bbls Arco Preflush, 50 bbls Mudpush XL Spacer @ 10.5ppg. Cement from MD to 6669' with LiteCRETE @ 12.0 ppg and from 6669' to DV tool with ASLite @ 10.7 ppg Lead Slurry Requirements: ASLite @ 10.7 ppg, Class G + 50%D124, 9%D44, 0.4%D46, 30%D53, 1.5%S1, 1.5%D79 -4.44 ft3/sk (6669'-1975') x 0.3132 ft3/ft x 1.45 (45% excess) = 2131.7 ft3/4.44 ft3/sk = 2131.7 ft3 480.1 sks - Round up to 490 sics Tail Slurry Requirements: LiteCRETE @ 12.0 ppg - 2.46 ft3/sk (9015'-6669') x 0.3132 ft3/ft x 1.45 (45% excess) = Shoe Joints: (80') x 0.4110 ft3/ft = 1065.4 ft3 + 32.9 ft3 = 1098.3 ft3/2.46 ft3/sk = 1065.4 ft3 32.9 ft3 1098.3 ft3 446.5 sks - Round up to 450 sks BHST = 80 deg F STAGE 2 Volume Calcs: Pump 30 bbls FW. Cement from 1975' to surface with ASLite @10.7 ppg. Tail in with 60 sks. AS 1 @. 15.8 ppg. Lead Slurry Requirements: ASLite @ 10.7 ppg, Class G + 50%D124, 9%D44, 0.4%D46, 30%D53, 1.5%S1, 1.5%D79 - 4.44 ft3/sk (1975'-1775') x 0.3132 ft3/ft x 1.45 (45% excess) = (1775') x 0.3132 ft3/ft x 3.50 (250% excess) = 90.8 ft3+ 1945.8 ft3 = 2036.6 ft3/4.44 ft3/sk = 90.8 ft3 1945.8 ft3 2036.6 ft3 458.7 sks - Round up to 460 sks Have 260 sks of additional Lead on location for Top Out, if necessary Tail Slurry Requirements: 60 sx, AS 1 @ 15.8 ppg - 0.93 ft3/sk Circulation' Circulation and cementing at or less than 8 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 3 bpm for the last 30 bbls of displacement in stage 1 for bumping the plug as well as maintaining returns. Run dye marker ahead of the stage 2 cement to provide insight into the decision to performing a top job. Expect 10 minutes of u-tubing in stage 1. Recommended Conditioned Mud Properties: 10.0 ppg, Pv -- 20 or under, Ty = 20 or under. 1D-32 Well Intermediate Cement loads and CemCADE* summary. Use 75 % excess. Drilled with 8 U2" bit. 7", 29 #casing TMD 13355'. TOC@ 12555' (800' Shoe Tack). Volume Calcs: Pump 20 bbls Arco Preflush, 30 bbls MudPUSH XL spacer @ 12.0ppg. Cement from 13355' MD to 12555' with Class G + adds @15.8 ppg Slurry Requirements: 15.8 ppg Class G 0.2%D46, 0.3%D65, 0.1%D800- 1.17 ft3/sk (adjust retarder to give 3-4 hours thickening time) 7", 29# x 8 1/2" OH: (13355'-12555') x 0.1268 ft3/ft x 1.75 (75% excess) = 177.5 ft3 Shoe Joints: (80') x 0.2086 ft3/ft = 16.7 ft3 Total Volume = 194.2 ft3. 194.2 ft3 / 1.17 ft3/sk = 166 sks - Round up to 170 sks BHST = 150F (estimated) CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl Arco Preflush, 30 bbls 12.0 ppg MudPUSH XL Spacer, 170 sks (35 bbls) Class G + adds. Displacement is approximately 493 bbls. Circulation: Circulation and cementing at or less than 7 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug. Expected pressure to bump the plug is 1400 psi. At 7 bpm, expect no u,tubing after dropping the top plug. Centralizers: Recommend using at least 1/1 across the entire liner interval to maximize primary success. Recommended Conditioned Mud Properties:' 10.0 ppg, Pv = 20 or under, Ty = 20 or under. Kevin Tanner can be reached at the following numbers regarding this job or any other assistance: 265- 6205(w), 336-0067(h), 230-6628(ce11).. 1D-32 Kuparuk Well, Liner Cement loads and CemCADE* summary. Use 60% excess. Drilled with 6 1/8" bit. 3 1/2", 9.3 #casing TMD 14097'. TOC@ 13005' (200' over top of liner top). Liner Top @ 13205' Previous casing 7", 29#, 13355' TMD. 4", 14# DP, 300' liner lap. Volume Calcs: Pump 20 bbls Arco Preflush, 20 bbls MudPUSH XL @ 13.0ppg. Cement from 14097' MD to 13005' with Class G + adds @15.8 ppg Slurry Requirements: 15.8 ppg GasBLOK w/Class G + D53, D600, D135, D800, D047, D065, per lab testing - 3.5 to 4.5 hour thickening time, Yield = 1.2 ft3/sx 3 1/2", 9.3# x 6 1/8" OH: (14097'-13355') x 0.1378 ft3/ft x 1.60 (60% excess) = 163.6 ft3 3 1/2", 9.3# x 7", 29#: (300') x 0.1418 ft3/ft = 21.3 ft3 7", 29#: (200') x 0.2086 ft3/ft = 41.7 ft3 Shoe Joints: (80') x 0.0488 ft3/ft = 3.9 ftc3 Total Volume = 230.5 ft3. 230.5 ft3 / 1.2 ft3/sk = 192 sks - Round up to 200 sks CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl Arco Preflush, 20 bbls 13.0 ppg MudPUSH XL Spacer, 200 sks (43 bbls) Class G + adds. Displacement is approximately 150 bbls. Circulation: Circulation and cementing at or less than 3 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 2 bpm for the last 20 bbls of displacement for bumping the plug. Expected pressure to bump the plug is 1700 psi. At 3 bpm, expect no u-tubing after dropping the top plug. Centralizers: Recommend using at least 1/1 across the entire liner interval to maximize primary success. Recommended Conditioned Mud Properties: 13.0 ppg (preferably lower), Pv = 20 or under, Ty = 20 or under. 1D-32 Well Longstring Cement loads and CemCADE* summary. Use 75 % excess. Drilled with 8 1/2" bit. 7", 29 #casing TMD 14097'. TOC@ 12561' Volume Calcs: Pump 20 bbls Arco Preflush, 30 bbls MudPUSH XL Spacer @ 12.0ppg. Cement from 14097' MD to 12561' with Class G + adds @15.8 ppg Slurry Requirements: 15.8 ppg GasBLOK w/Class G + D53, D600, D135, DS00, D047, D065, per lab testing 7", 294/x 8 1/2" OH: (14097'-12561') x 0.1268 ft3/ft x 1.75 (75% excess) = 340.8 ft3 Shoe Joint: (80') x 0.2086 ft3/ft = 16.7 ftc3 Total Volume = 357.5 ft3. 357.5 ft3 / 1.2 ft3/sk = 298 sks - Round up to 300 sks BHST = 150F, BHCT = 120F CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl Arco Preflush, 30 bbls 12.0 ppg MudPUSH XL Spacer, 300 sks Class G + adds (64 bbls). Displacement is approximately 521 bbls. Circulation: Circulation and cementing at or less than 7 bpm is within the safe ECD to avoid breaking down the formations. Recommend dropping the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug. Expected pressure to bump the plug is 1500 psi. At 7 bpm, expect 5 min. u-tubing after dropping the top plug. Centralizers: Recommend using at least 1/1 across the entire liner interval to maximize primary success. Recommended Conditioned Mud Properties: 10.0 ppg, Pv = 20 or under, Ty = 20 or under. KRU 1D-32 Inje( Proposed Completion Schematic Topset Base Case P ,-LIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY 20" 91.5# H-40 ,,~ @ +/- 120' MD Weatherford Gemoco 9-5/8" DV Stage Collar Stnd. Grade BTC Threads (+/- 2080' MD / 1817' TVD) Depths are based on Nabors 16E RKB Surface csg. 9-5/8" 40.0# L-80 BTCM (+/- 9015' MD / 4577' TVD) 3-1/2" FMC Gen V 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 w/2.875" No-Go Profile. 3-1/2" x 6' L-80 pup installed above. 3-1/2" x 6' L-80 flow coupling installed below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" x 1" Camco 'KBUG' Mandrels w/DV's and BK latch's (Max. OD 5.390", ID 2.867"), 6' L-80 handling pups installed above and below on GLM Spaced out w/ 3-1/2" 9.3# L-80 EUE8RD tubing as follows: GLM # TVD-RKB MD-RKB GLM Numbers and Spacing To Be Determined Intermediate csg. 7" 26.0# J-55 BTCM (+/- 13355' MD / 6342' TVD) Future Perforations Production Liner 3-1/2" 9.3# L-80 SLHT (+/- 14097' MD / 6644' TVD) 3-1/2" x 1-1/2" Camco 'MMG' mandrel w/shear valve and latch (Max. OD 5.968", ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'DS' nipple w/2.813" No-Go profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below I jt 3-1/2" 9.3# L-80 EUE8RD tubing 5.125" x 3" Baker Iocator sub 4-1/2" Baker GBH-22 casing seal assembly w/12' stroke, 3-1/2" L-80 EUE8RD box up Liner Assembly (run on drillpipe), set @ +/- 13205' MD Baker 7" x 5" 'ZXP' Liner Top Isolation Packer with HR profile Baker 7" x 5" 'Flexlock' Liner Hanger Baker 20' Seal Bore Extension XO Sub, 5" Stub Acme box x 3-1/2" SLHT pin 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Halliburton 'XN' nipple w/2.75" No-Go Profile, 3-1/2" SLHT box x pin 3-1/2" 9.3# L-80 SLHT liner as needed 3-1/2" Baker Landing Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Shoe TJM, 10/23/00, vl KRU 1D-32 Inje0 Proposed Completion Schematic Long String Contingency Case Alaska, Inc. A Subsidiary of PS PETROLEUM COMPANY 20" 91.5# H-40 @ +/- 120' MD Weatherford Gemoco 9-5/8" DV Stage Collar Stnd. Grade BTC Threads (+/- 2080' MD / 1817' TVD) Depths are based on Nabors 16E RKB Surface csg. 9-5/8" 40.0# L-80 BTCM (+/- 9015' MD / 4577' TVD) Future Perforations Production csg. 7" 26.0# J-55 BTCM (+/- 14097' MD / 6644' TVD) 3-1/2" FMC Gen V 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 w/2.875" No-Go Profile. 3-1/2" x 6' L-80 pup installed above. 3-1/2" x 6' L-80 flow coupling installed below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" x 1" Camco 'KBUG' Mandrels w/DV's and BK latch's (Max. OD 5.390", ID 2.867"), 6' L-80 handling pups installed above and below on GLM. Spaced out w/3-1/2" 9.3# L-80 EUE8RD tubing as follows: GLM # TVD-RKB MD-RKB GLM Numbers and Spacing To Be Determined 3-1/2" x 1-1/2" Camco 'MMG' Mandrel w/shear valve and latch (Max. OD 5.968", ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. I jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'DS' nipple w/2.813" No-Go profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below I jt 3-1/2" 9.3# L-80 EUE8RD tubing 7" x 3-1/2" Baker 'SAB-3' permanent packer w/KBH-22 seal assembly, 3-1/2" x 6' L-80 EUE8RD handling pup on top 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'D' nipple w/2.75" No-Go Profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 3-1/2" x 10' L-80 EUE8RD pup joint 3-1/2" Baker Shear Out Ball Seat Sub. Tubing tail +/- 50' above top of proposed perforations TJM, 10/23/00, vl ICreoted by rixse FOI{: MUIgHO¥1C Dote plotted: 17-Oct-2~ I ~ot Referen~ ~ ~ Ve~ ~5 . I ~rdlnot~ ~re in f~ refer~ sl~ ~32, I Tr~ V=~icul Depths ore referen~ RKB(No~m 15E). 600 Phillips Alaska, Inc. 1800 {'- 2400 4- 5000 0 t- 5600 4200 4800 Structure : Pad 10 Well : 52 Field : Kuparuk River Unit Location : North Slope, Alaska KOP Point Begin 5 Deg Build Begin 4 DeE Bu;ld&Tu End Turn/Cont. Bul d PROFILE COMMENT DATA MD Inc Dir TVD North Eost V. Sect DeE/lO0 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 400.00 2.25 88.00 399.96 O. 10 2.94 1.95 1.50 1000.00 20.25 88.00 986.02 4.17 119.45 79.26 5.00 1200.00 28.21 90.00 1168.25 5.38 201.44 134.87 4.00 Begin 2 Deg Build 1500.00 40.21 90.00 1415.90 5.58 569.79 250.86 4.00 A Bose of Permofrost 1774.89 45.71 90.00 1617.00 5.38 557.05 379.86 2.00 0 ~B RKB ELEVATION' 106' Beg;n 2 DeE Bu~ld&Tu 2800 O0 6621 90 O0 2187.81 5.58 1401.96 961.95 2.00 / ' EOC 5750:12 73:70 149:50 5561.80 - 1548.95 5561.12 5451.09 2 ~'~ 10.75 ........ Benin 2 Den Dron 6500 O0 73 70 149.50 3577.89 -1984.51 5958.40 4151.55 C ~5.00 ueg,n o ueg uu,,a EO~ = " 6885104 66:00 149.41 5710.44 -2295.04 4122.55 4505.62 2.uu 600 ~9.00 Top of West Sok 7469.08 66.00 149.41 3948.00 -2754.52 4394.08 5025.60 0.00 ~15.00 DLS: 5.00 dee per 100 fi Bose West Sok 8523.77 66.00 149.41 4377.00 -5585.70 4884.45 5962.59 0.00 ~24 25 Begin 4 Deg Build&Turn 9-5/.8 C. oslng Pt. 9015.47 66.00 149.41 4577.00 -5970.35 5115.07 6400.55 0.00 k' ' End Turn/Cont Build C80 (KIO) 9047.43 66.00 149.41 4590.00 -5995.48 5127.92 6428.80 0.00 1200 'k52.00 ' ' C50 11395.28 66.00 149.41 5545.00 -5841.77 6219.55 8519.10 0.00 ~k40.O0 Begin 2 DeE Build ~40 (K-5) 12032.03 66.00 149.41 5804.00 -6542.49 6515.60 9086.00 0.00 x,.44.00 ~ .... f P=rmnfr~,=* 050 (K-2) 12784 55 66.00 149.41 6110.00 -6954.07 6865.58 9755.77 0.00 ,,% 4~BbOr,On _ ......... ~,20 {HRZ Midpoint) 151 62:94 66.00 149.41 6264.00 -7231.79 7041.41 10092.84 0.00 \ ..... Bose HRZ 15354 70 66.00 149.41 6342.00 -7382.59 7130.57 10263.57 0.00 "X 58.00 K-1 15561'21 66 O0 149 41 6426.00 -7544.99 7226.58 10447.42 0.00 "'K,, 64.=0~0~: Torget-Top C4 15757:89 66:00 149:41 6506.00 -7699.65 7518.05 10622.55 0.00 '~v'~_~OR ~op C5 15819 55 66.00 149.41 6551.00 -7747.98 7546.60 10677.25 0.00 '",~,~'~4T. 75 top C2 15861115 66.00 149.41 6548.00 -7780.85 7566.04 10714.46 0.00 ~ 64.74 [op C1 15875.44 66.00 149.41 6555.00 -7790.51 7571.75 10725.40 0.00 ~65.05 ~OD B Shole 15912 77 66 O0 149 41 6569.00 -7821.44 7590.04 10760.42 0.00 '""--.,~D"- ~o sin g Pt 14097116 66:00 149:41 6644.00 -7966.44 7475.77 10924.58 0.00 ~-,,,,,~68.47 EOC Begin 2 Deg Drop 136.46 AZIMUTH EOC ~ -"'":-~C~o~o,w. stso~ 10693 (TO TARGET) ***Plone of Proposol*** e West Sok ~'~-~' C80 (KIO)~~5/B Coslng Pt. 10-52 17-0ct-00 5400 TANGENT ANGLE ~ c~o C40 (C~)K-~ g 2 6000 K-1 660o Torget-Top C4 ..~ ~OPToCp~c2 Top B Shole Top Cl TD-Coslng Pt 600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 ~ 0200 10800 1 ~ 400 Vertical Section (feet) -> Azimuth 156.46 with reference 0,00 N, 0.00 E from slot #52 Phillips Alaska, Inc. Structure : Pad 1D Well : 52 Field : Kuparuk River Unit Location : North Slope, Alaska 500 East (feet) -> 0 500 1000 1500 2000 2500 5000 5500 4000 4500 I I I I I I I I I I I I I I I I I I I Begin 5 Deg Build Begin 2 Deg Build&Turn Begin/ Deg Build&Turn _- - End Turn/Cont. Build Beg~n 2 Be~ Build Bose of Permafrost 5000 5500 6000 I I I I I I 6500 7000 I I I 7500 8000 i i i ~ 500 0 500 SURFACE LOCATION: 417' FNL, 420' FEL SEC. 23, T1 1N, RIOE EOC Begin 2 Oeg Drop EOC Top of West Sak 1aa0 1500 2OOO 2500 5000 Base West Sak 9-5/8 Casing Pt. C80 (K 10) 5500 4000 4500 5000 I v C50 5500 C40 TARGET LOCATION: 2440' FSL, 1612' FWL SEC. 50, T11N, Rll C30 (K-2) C20 (HRZ Base HRZ K-1 Target-Top C4 Top B Shale TD-Cosing Pt TD LOCATION: 2173' FSL, 1770' FWL SEC. 50, T11N0 R11E -7000 7500 f8000 8500 9000 c~ot~ ~r r~xs~ FOR: MUSHOVIC Dote plotted: 17-0ct-2~ ~ot Refer~ ~ ~ V~n ~5 . ~rdlnot~ ore In f~t refere~ True Venial D~tha o~ ref~ RKB(No~ Phillips Alaska, Inc. Sfruofure: Pod 1D Well : ;~2 Field : Kuporuk River Unit Looofion : North Slope, Alaska 100 80 60 40 ID 20 0 (23 20 I ¥ ao 60 80 100 120 ~ I I I I I 11/3 1 aa lOO 0 East (feet) -> 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 500 520 540 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 -~ 1300 1200 ....... -- 1100 _ _ --o~ ~ '~ 2500 900 1000 ....... ~.._,.5.00- .... 800 ~500 800 900 1000 1100 1200 1500 1400 1500 500 700 800 900 1000 11 O0 1200 2600 700 800 900 500 700 800 .~. 900 1000 500 700 800 ~ . 900 1000 500 1200 1500 1800 2000 900 1300 1400 1500 ~2100~ ~5oo ~ i i i ~ i i i i i i I i i i i i i i i 20 0 20 4~ 60 8~3 100 120 140 160 East (feet) -> 16O0 1300 -~t-~ 1100 ..... 1200 1300 11 O0 1200 130-~ 1100 1200 100 80 60 4O 20 0 0 20 I v 40 60 80 , 120 i i i i 180 200 220 240 260 280 500 520 540 100 Cre~ed by r;x~e FOR: MUSfHOVIC Dote pl~tted: 17-Oct-2000 Plot Reference ~ 52 Vets{on {~5 . ICoordlnotes ore In feet reference slot ~32. ITru. Vel;co; Depth8 ore reference RKO(Nobom 16E).I I Iii I I I Phillips Alaska, Inc. Structure: Pad 1D Well : 32 Field : Kuparuk River Unit Location : North Slope, Alaska 240 200 160 120 80 O 40 Z 80 120 160 200 240 East (feet) -> '.4D 280 ,520 ,360 400 440 480 §20 560 600 640 680 720 760 800 840 880 920 950 1000 1040 1080 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 1700 1900 ...... -- 2500 1700 .... ---- 1,oo 2soo 1900 24O 200 160 120 80 2700 4O ~-~---~-"~'---,-~1700 .... -~ 1500 1700 ,uuu 2100 ~ 2900 ~':~:~t3oo ~~-- - - - d 700 ~ 17 ~ ~ _ O0 80 ~'"~' ~ 1900 1§0 ~~ 200 I ! I I I I I I I I I I I I I I I I I II I I I I I I I I I I I I I I I I I I I I I 240 240 280 520 360 4~ 440 480 520 5~ H0 640 680 720 760 800 840 880 920 960 1000 1040 1080 East (feet) -> /X I Z Creat~ t~ ~ FOR: MU~ItOVIC Date platted: !7-0ct-2000 Plot Reference ~s 52 Vemian Coordinates are In feet reference slot J52. I True Vertical Depths or~ r~fer~nce RKB(NDb~ra 16E).I I Phillips Alaska, Inc. Sfrucfure : Pad 1D Well : 32 Field : Kuparuk River UnJf Location : North Slope, Alaska East (feet) 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2500 2400 2500 2600 2700 2800 600 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 600 500 400 500 200 100 0 200 5900 ~ 3500 ~ 4300 2500 21~__~~~nn ~~ ~ ~*--" -- ~ -- 2500 500 400 300 2OO ~700 2100 2300 1900 ~ ~ ~ 5500 ~ 2500 ZOO ~300 ~ '2500 ~ ~ 1900 5500 ~ ~ ~L~O 1900 ~ ~ 2500 ~ ~ ~ ~ 200 ~ ~'-,.2700 ~ 2100 3900 ~ Z500 2100 2100 !700 ~ ~ 300 ~ 300 ',2900 4100 ~~ ~ 3100 5300 2900 400 ~ 400 ~ 3900 2500 5700 4100 5100 27D0 \ 500 500 ~3,00 600 ~~-~~ 600 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 700 800 gOO 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 East (feet) -> 100 0 (- 0 --I- 10o Phillips Alaska, Inc. 200 8OO 900 '1 1000 0 Structure : Pad 1D Well : 32 c~t~ w ~,, FOR: MUSHOVIC ~ ~tt~ml: 17-0ct-2000 PSat ~'er~oe lu 32 Vm~on ~5. I East (feet) -> 2500 2400 2500 2600 2700 2800 2900 5000 31 O0 3200 3500 3400 3500 5600 5700 5800 3900 1 O0 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 1 O0 ~ - 200 ~' '-~2700 _ 300 '~... - 500 x 400 4OO 4300 ~ 5~00 500 -"~'~700 500 500 \ 00 600 N 100 §00 \ 3500 700 \ 700 \ \ ~. 3100 1700.3700 \ \ \ \ \ \ \ \ \ \ iO0 \ \ 3700 \ 6 3300 1200 500 3900 \ 1500 \ \ \ 1400 \ \ \ \ 1500 \ \ \ 1600 \ \ 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 2300 2400 2500 2600 2700 2800 2900 5000 3100 5200 3300 5400 3500 3500 3700 3800 3900 East (feet) -> Fleld: Kuparuk River Unit Looaflon : North Slope, Alaska I 1100 V 800 O 900 '~' 1000 $ 1100 I V -- -1200 -1500 1400 1500 1800 1700 1600 2800 5200 5600 4000 1600 3900 2000 2400 2800 5200 5600 400O 4400 4800 5200 5600 \ 6000 6400 6800 7200 7600 8000 8400 , , 2800 5200 \%5 \ 5500 \ \ \ \ Phillips Alaska, Inc. Sfructure : Pod 1D Well : 52 Fleld: Kuporuk River Unlf Loc(afion : Norfh Slope, Alosko 4400 4800 i i i i i 35O0 \ \ \ 4300 X~3700 \ \~ 3900 4500 \ East (feet) -> 5200 5600 6000 6400 6800 7200 7600 8000 . I I I I I I I I I I I I I I I ~ 6500 4700 ~'~ 4100 \ '~900 \\ '~oo 90~X , Xx ~700 ~ ~700 ~70~ ~5~00 610;, '~ 'X ~ 6100 k ~ 3900 .... k ~" 6300,539~__ 4900 ,, ~00 .... 'x 5~oo'. '1~0 %6700 4100 ~ 5700 \ \ \ \ \ \ \ ~ ¢30o \ k~k5900 \ \ ~ 4500 \ \ XX6100 \ \ ~ 4700 \ \ \ \ \ ~ 4900 \ I I I I I I I 3600 4000 4400 \ 5300 \ ¢500 k 4500 \ 57ooR\\ 590o~\\ \ ~ 5100 i i i i i i i i i i i 4800 5200 5600 6000 6400 6800 East (feet) -> \X6100 6300 ~ 6500 i I I I I l 7200 7600 8000 8400 I i 8400 8800 I i 8800 9200 1600 2000 2400 -280O 3200 3600 4000 4400 4800 5200 5600 6000 -- -6400 6800 7200 7600 8000 8400 9200 iO0 700 300 Phillips Alaska, Inc. Structure : Pad 1D Well : 32 Field : Kuparuk River Unit Location : North Slope, Alaska TRUE NORTH 350 0 10 20 3100 3300 ---" 4O 3500 5O 6O 290~ 7O 280 8O 270 9O 260 lO0 2 240 110 120 500 2500 1100 2~0 / / 150 200// ,300 160 2~oo ~ 0 180 170 (~ Normal Plane Travelling Cylinder - Feet 140 All depths shown ore Measured depths on Reference Well 130 Phillips Alaska, Inc. Pad 1D 32 slot #32 Kuparuk River Unit North Slope, A1 aska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 32 Version #5 Our ref : prop2091 License : Date printed : 17-0ct-2000 Date created : 23-Feb-1997 Last revised : 17-0ct-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 57.215,w149 30 31.152 Slot Grid coordinates are N 5959249.170, E 560670.327 Slot local coordinates are 417.00 S 420.00 W Projection. type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. Pad 1D,32 Kuparuk River Unit. North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 32 Version#5 Last revised : 17-0ct-2000 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S Dogleg Vert Deg/lOOft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 250.00 0.00 0.00 250.00 0.00 N 0.00 E 0.00 300.00 0.75 88.00 300.00 0.01 N 0.33 E 1.50 400.00 2.25 88.00 399.96 0.10 N 2.94 E 1.50 425.00 3.00 88.00 424.94 0.14 N 4.09 E 3.00 0.00 0.00 KOP 0.22 1.95 Begin 3 Deg Build 2.71 525.00 6.00 88.00 524.62 0.42 N 11.93 E 3.00 625.00 9.00 88.00 623.75 0.87 N 24.97 E 3.00 725.00 12.00 88.00 722.06 1.51 N 43.18 E 3.00 825.00 15.00 88.00 819.29 2.32 N 66.51 E 3.00 925.00 18.00 88.00 915.16 3.31 N 94.89 E 3.00 7.92 16.57 28.66 44.14 62.97 1000.00 20.25 88.00 986.02 4.17 N 119.45 E 3.00 1100.00 24.23 89.15 1078.56 5.08 N 157.27 E 4.00 1200.00 28.21 90.00 1168.25 5.38 N 201.44 E 4.00 1294.78 32.00 90.00 1250.23 5.38 N 248.97 E 4.00 1394.78 36.00 90.00 1333.12 5.38 N 304.88 E 4.00 79.26 Begin 4 Deg Build&Turn 104.67 134.87 End Turn/Cont. Build 167.62 206.13 1494.78 40.00 90.00 1411.90 5.38 N 366.43 E 4.00 1500.00 40.21 90.00 1415.90 5.38 N 369.79 E 4.00 1589.56 42.00 90.00 1483.38 5.38 N 428.67 E 2.00 1689.56 44.00 90.00 1556.51 5.38 N 496.86 E 2.00 1774.89 45.71 90.00 1617.00 5.38 N 557.05 E 2.00 248.54 250.86 Begin 2 Deg Build 291.42 338.40 379.86 Base of Permafrost 1789.56 46.00 90.00 1627.22 5.38 N 567.57 E 2.00 1889.56 48.00 90.00 1695.41 5.38 N 640.70 E 2.00 1989.56 50.00 90.00 1761.02 5.38 N 716.17 E 2.00 2089.56 52.00 90.00 1823.94 5.38 N 793.88 E 2.00 2189.56 54.00 90.00 1884.12 5.38 N 873.74 E 2.00 387.11 437.49 489.48 543.02 598.03 2289.56 56.00 90.00 1941.48 5.38 N 955.65 E 2.00 2389.56 58.00 90.00 1995.94 5.38 N 1039.51 E 2.00 2489.56 60.00 90.00 2047.44 5.38 N 1125.23 E 2.00 2589.56 62.00 90.00 2095.92 5.38 N 1212.68 E 2.00 2689.56 64.00 90.00 2141.32 5.38 N 1301.78 E 2.00 654.46 712.24 771.29 831.54 892.92 2789.56 66.00 90.00 2183.58 5.38 N 1392.41 E 2.00 2800.00 66.21 90.00 2187.81 5.38 N 1401.96 E 2.00 2900.00 65.92 92.16 2228.38 3.66 N 1493.33 E 2.00 3000.00 65.66 94.34 2269.40 1.51 S 1584.38 E 2.00 3100.00 65.42 96.52 2310.81 10.13 S 1674.99 E 2.00 955.35 961.93 Begin 2 Deg Build&Turn 1026.13 1092.60 1161.27 3200.00 65.23 98.71 2352.56 22.17 S 1765.05 E 2.00 1232.04 3300.00 65.06 100.91 2394.60 37.62 S 1854.45 E 2.00 1304.83 3400.00 64.92 103.11 2436.88 56.48 S 1943.08 E 2.00 1379.56 3500.00 64.82 105.32 2479.35 78.71 S 2030.84 E 2.00 1456.13 3600.00 64.75 107.53 2521.95 104.28 S 2117.62 E 2.00 1534.45 3700.00 64.72 109.74 2564.63 133.17 S 2203.31 E 2.00 1614.42 3800.00 64.71 111.95 2607.35 165.34 S 2287.80 E 2.00 1695.95 3900.00 64.74 114.16 2650.04 200.75 S 2371.00 E 2.00 1778.93 4000.00 64.81 116.37 2692.67 239.35 S 2452.81 E 2.00 1863.27 4100.00 64.90 118.58 2735.17 281.11 S 2533.11 E 2.00 1948.86 4200.00 65.03 120.78 2777.49 325.97 S 2611.82 E 2.00 2035.60 4300.00 65.19 122.98 2819.58 373.87 S 2688.85 E 2.00 2123.39 4400.00 65.38 125.17 2861.40 424.76 S 2764.08 E 2.00 2212.11 4500.00 65.60 127.35 2902.88 478.58 S 2837.45 E 2.00 2301.65 4600.00 65.86 129.53 2943.99 535.25 S 2908.84 E 2.00 2391.92 All data is in feet unless otherwise stated. Coordinates from slot#32 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 10924.80 on azimuth 136.82 degrees from wellhead. Total Dogleg for wellpath is 132.55 degrees. Vertical section is from wellhead on azimuth 136.46 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska. Inc. Pad 1D,32 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 32 VersionS5 Last revised : 17-0ct-2000 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S. Deg/lOOft Sect 4700.00 66.15 131.70 2984.66 594.72 S 2978.19 E 2.00 2482.80 4800.00 66.46 133.85 3024.85 656.90 S 3045.39 E 2.00 2574.17 4900.00 66.81 136.00 3064.52 721.72 S 3110.38 E 2.00 2665.93 5000.00 67.18 138.13 3103.60 789.11 S 3173.08 E 2.00 2757.96 5100.00 67.58 140.26 3142.06 858.98 S 3233.39 E 2.00 2850.16 5200.00 68.01 142.36 3179.85 931.24 S 3291.26 E 2.00 2942.41 5300.00 68.47 144.46 3216.92 1005.81S 3346.61 E 2.00 3034.59 5345.83 68.69 145.42 3233.66 1040.73 S 3371.12 E 2.00 3076.78 5400.00 69.00 146.53 3253.21 1082.60 S 3399.39 E 2.00 3126.61 5500.00 69.60 148.57 3288.56 1161.54 S 3449.58 E 2.00 3218.40 5535.83 69.82 149.30 3300.99 1190.32 S 3466.92 E 2.00 3251.21 5600.00 71.10 149.30 3322.46 1242.32 S 3497.80 E 2.00 3310.17 5700.00 73.10 149.30 3353.19 1324.13 S 3546.38 E 2.00 3402.94 5730.12 73.70 149.30 3361.80 1348.95 S 3561.12 E 2.00 3431.09 EOC 6000.00 73.70 149.30 3437.55 1571.67 S 3693.37 E 0.00 3683.64 6500.00 73.70 149.30 3577.89 1984.31S 3938.40 E 0.00 4151.53 Begin 2 Deg Drop 6600.00 71.70 149.32 3607.63 2066.41 S 3987.13 E 2.00 4244.61 6700.00 69.70 149.35 3640.68 2147.59 S 4035.25 E 2.00 4336.61 6800.00 67.70 149.38 3677.01 2227.75 S 4082.72 E 2.00 4427.42 6885.04 66.00 149.41 3710.44 2295.04 S 4122.53 E 2.00 4503.62 EOC 7000.00 66.00 149.41 3757.20 2385.45 S 4175.98 E 0.00 4605.97 7469.08 66.00 149.41 3948.00 2754.32 S 4394.08 E 0.00 5023.60 Top of West Sak 7500.00 66.00 149.41 3960.58 2778.63 S 4408.46 E 0.00 5051.12 8000.00 66.00 149.41 4163.95 3171.82 S 4640.93 E 0.00 5496.27 8500.00 66.00 149.41 4367.33 3565.00 S 4873.40 E 0.00 5941.42 8523.77 66.00 149.41 4377.00 3583.70 S 4884.45 E 0.00 5962.59 Base West Sak 9000.00 66.00 149.41 4570.71 3958.19 S 5105.87 E 0.00 6386.57 9015.47 66.00 149.41 4577.00 3970.35 S 5113.07 E 0.00 6400.35 9-5/8" Casing Pt. 9047.43 66.00 149.41 4590.00 3995.48 S 5127.92 E 0.00 6428.80 C80 (KiO) 9500.00 66.00 149.41 4774.09 4351.37 S 5338.34 E 0.00 6831.72 10000.00 66.00 149.41 4977.46 4744.56 S 5570.82 E 0.00 7276.88 10500.00 66.00 149.41 5180.84 5137.74 S 5803.29 E 0.00 7722.03 11000.00 66.00 149.41 5384.22 5530.93 S '6035.76 E 0.00 8167.18 11395.28 66.00 149.41 5545.00 5841.77 S 6219.55 E 0.00 8519.10 C50 11500.00 66.00 149.41 5587.59 5924.11 S 6268.23 E 0.00 8612.33 12000.00 66.00 149.41 5790.97 6317.30 S 6500.71 E 0.00 9057.48 12032.03 66.00 149.41 5804.00 6342.49 S 6515.60 E 0.00 9086.00 C40 (K-5) 12500.00 66.00 149.41 5994.35 6710.48 S 6733.18 E 0.00 9502.63 12784.33 66.00 149.41 6110.00 6934.07 S 6865.38 E 0.00 9755.77 C30 (K-2) 13000.00 66.00 149.41 6197.73 7103.67 S 6965.65 E 0.00 9947.78 13162.94 66.00 149.41 6264.00 7231.79 S 7041.41 E 0.00 10092.84 C20 (HRZ Midpoint) 13354.70 66.00 149.41 6342.00 7382.59 S 7130.57 E 0.00 10263.57 Base HRZ 13500.00 66.00 149.41 6401.10 7496.85 S 7198.12 E 0.00 10392.93 13561.21 66.00 149.41 6426.00 7544.99 S 7226.58 E 0.00 10447.42 K-1 13757.89 66.00 149.41 6506.00 7699.65 S 7318.03 E 0.00 10622.53 1D-32 17-0ct-00 13819.35 66.00 149.41 6531.00 7747.98 S 7346.60 E 0.00 10677.25 Top C3 13861.15 66.00 149.41 6548.00 7780.85 S 7366.04 E 0.00 10714.46 Top C2 13873.44 66.00 149.41 6553.00 7790.51 S 7371.75 E 0.00 10725.40 Top C1 13912.77 66.00 149.41 6569.00 7821.44 S 7390.04 E 0.00 10760.42 Top B Shale 14000.00 66.00 149.41 6604.48 7890.04 S 7430.59 E 0.00 10838.08 All data is in feet unless otherwise stated. Coordinates from slot #32 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 10924.80 on azimuth 136.82 degrees from wellhead. Total Dogleg for wel lpath is 132.55 degrees. Vertical section is from wellhead on azimuth 136.46 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad iD, 32 Kuparuk River Unit,North Slope. Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 14097.16 66.00 149.41 6644.00 7966.44 S 7475.77 E PROPOSAL LISTING Page 3 Your ref : 32 Version #5 Last revised : 17-0ct-2000 Dogleg Vert Deg/lOOft Sect 0.00 10924.58 TD-Casing Pt All data is in feet unless otherwise stated. Coordinates from slot#32 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 10924.80 on azimuth 136.82 degrees from wellhead. Total Dogleg for wellpath is 132.55 degrees. Vertical section is from wellhead on azimuth 136.46 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1D,32 Kuparuk River Unit,North Slope. Alaska PROPOSAL LISTING Page 4 Your ref : 32 Version#5 Last revised : 17-0ct-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 400.00 399.96 1000.00 986.02 1200.00 1168.25 1500.00 1415.90 1774.89 1617.00 2800.00 2187.81 5730.12 3361.80 6500.00 3577.89 6885.04 3710.44 7469.08 3948.00 8523.77 4377.00 9015.47 4577.00 9047.43 4590.00 11395.28 5545.00 12032.03 5804.00 12784.33 6110.00 13162.94 6264.00 13354.70 6342.00 13561.21 6426.00 13757.89 6506.00 13819.35 6531.00 13861.15 6548.00 13873.44 6553.00 13912.77 6569.00 14097.16 6644.00 0.00 0.10 4.17 5.38 5.38 5.38 5.38 1348.95 1984.31 2295.04 2754.32 3583.70 3970.35 3995.48 5841.77 6342.49 6934.07 7231 79 7382 59 7544 99 7699 65 7747 98 7780 85 7790 51 7821 44 7966 44 N 0.00 E KOP N 2.94 E Begin 3 Deg Build N 119.45 E Begin 4 Deg Build&Turn N 201.44 E End Turn/Cont. Build N 369.79 E Begin 2 Deg Build N 557.05 E Base of Permafrost N 1401.96 E Begin 2 Deg Build&Turn S 3561.12 E EOC S 3938.40 E Begin 2 Deg Drop S 4122.53 E EOC S 4394.08 E Top of West Sak S 4884.45 E Base West Sak S 5113.07 E 9-5/8" Casing Pt. S 5127.92 E C80 (KiO) S 6219.55 E C50 S 6515.60 E C40 (K-5) S 6865.38 E C30 (K-2) S 7041.41 E C20 (HRZ Midpoint) S 7130.57 E Base HRZ S 7226.58 E K-1 S 7318.03 E 1D-32 17-0ct-00 S 7346.60 E Top C3 S 7366.04 E Top C2 S 7371.75 E Top C1 S 7390.04 E Top B Shale S 7475.77 E TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 9015.47 4577.00 3970.35S 5113.07E 9-5/8" Casing 0.00 0.00 O.OON O.OOE 14097.16 6644.00 7966.44S 7475.77E 7" Longstring Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1D-32 17-0ct-00 568050.000,5951610.000,0.0000 6506.00 7699.65S 7318.03E 12-0ct-2000 Phillips Alaska, Inc, Pad 1D,32 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 32 Version #5 Last revised : 17-0ct-2000 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 0.00 0.00 0,00 0.00 O.OON O.OOE 0,00 0.00 560670.33 5959249,17 250.00 0,00 0,00 250,00 O,OON O.OOE 0,00 0,00 560670,33 5959249,17 300,00 0,75 88,00 300,00 O,01N 0.33E 1,50 0,22 560670,65 5959249,18 400,00 2,25 88,00 399,96 0,10N 2,94E 1.50 1,95 560673,27 5959249,30 425,00 3.00 88.00 424,94 0.14N 4.09E 3.00 2,71 560674,41 5959249,35 525,00 6,00 88,00 524,62 0,42N 11,93E 3,00 7,92 560682,25 5959249,68 625,00 9.00 88,00 623,75 0,87N 24,97E 3,00 16,57 560695,29 5959250,24 725,00 12.00 88,00 722.06 1,51N 43.18E 3,00 28,66 560713.49 5959251.03 825,00 15,00 88,00 819,29 2,32N 66,51E 3,00 44,14 560736,81 5959252,03 925,00 18,00 88,00 915,16 3,31N 94,89E 3.00 62,97 560765,18 5959253,25 1000.00 20.25 88,00 986,02 4,17N 119,45E 3.00 79.26 560789,72 5959254.31 1100,00 24,23 89,15 1078,56 5,08N 157,27E 4,00 104,67 560827,54 5959255,53 1200,00 28,21 90,00 1168,25 5,38N 201,44E 4,00 134,87 560871,70 5959256,19 1294,78 32,00 90,00 1250,23 5,38N 248,97E 4,00 167,62 560919,22 5959256,57 1394.78 36,00 90.00 1333.12 5,38N 304.88E 4,00 206,13 560975.12 5959257,03 1494,78 40,00 90,00 1411,90 5,38N 366,43E 4,00 248,54 561036,67 5959257,53 1500,00 40,21 90,00 1415,90 5,38N 369,79E 4,00 250,86 561040,03 5959257,56 1589,56 42,00 90.00 1483,38 5,38N 428,67E 2,00 291,42 561098,90 5959258,03 1689,56 44,00 90,00 1556,51 5,38N 496,86E 2,00 338,40 561167,08 5959258,59 1774,89 45,71 90,00 1617,00 5,38N 557,05E 2,00 379,86 561227,26 5959259,08 1789,56 46,00 90,00 1627,22 5,38N 567,57E 2.00 387,11 561237,78 5959259,16 1889,56 48,00 90,00 1695,41 5,38N 640,70E 2,00 437,49 561310,90 5959259,76 1989,56 50,00 90,00 1761,02 5,38N 716,17E 2,00 489,48 561386,36 5959260,37 2089,56 52,00 90,00 1823,94 5,38N 793,88E 2,00 543,02 561464,06 5959261,00 2189,56 54,00 90,00 1884,12 5,38N 873,74E 2.00 598,03 561543,91 5959261.65 2289,56 56,00 90,00 1941,48 5,38N 955,65E 2,00 654,46 561625,81 5959262,32 2389,56 58,00 90,00 1995,94 5,38N 1039,51E 2,00 712,24 561709,66 5959263,00 2489,56 60,00 90,00 2047,44 5,38N 1125.23E 2.00 771,29 561795,37 5959263,70 2589,56 62,00 90,00 2095,92 5,38N 1212,68E 2,00 831,54 561882,81 5959264,41 2689,56 64,00 90,00 2141,32 5,38N 1301,78E 2,00 892,92 561971,90 5959265,13 2789.56 66,00 90,00 2183,58 5,38N 1392.41E 2,00 955.35 562062,51 5959265,87 2800,00 66,21 90,00 2187,81 5,38N 1401,96E 2,00 961,93 562072,06 5959265,95 2900,00 65,92 92,16 2228,38 3,66N 1493,33E 2,00 1026,13 562163,44 5959264,96 3000,00 65,66 94,34 2269,40 1,51S 1584,38E 2,00 1092,60 562254,51 5959260,53 3100,00 65,42 96,52 2310,81 10,13S 1674,99E 2.00 1161,27 562345.18 5959252.66 3200,00 65,23 98,71 2352,56 22,17S 1765,05E 2,00 1232,04 562435,33 5959241,35 3300,00 65,06 100,91 2394,60 37,62S 1854,45E 2,00 1304,83 562524,84 5959226,62 3400,00 64,92 103,11 2436,88 56,48S 1943,08E 2,00 1379,56 562613,62 5959208,49 3500,00 64,82 105,32 2479,35 78,71S 2030,84E 2,00 1456,13 562701,55 5959186,98 3600,00 64,75 107,53 2521,95 104,28S 2117,62E 2,00. 1534,45 562788,52 5959162,12 3700.00 64,72 109.74 2564,63 133,17S 2203,31E 2,00 1614,42 562874,43 5959133,93 3800,00 64,71 111,95 2607,35 165,34S 2287,80E 2,00 1695,95 562959,18 5959102,45 3900,00 64,74 114,16 2650,04 200,75S 2371,00E 2,00 1778,93 563042,66 5959067,72 4000,00 64,81 116,37 2692,67 239,35S 2452,81E 2,00 1863,27 563124,76 5959029,79 4100,00 64,90 118,58 2735.17 281.11S 2533.11E 2.00 1948,86 563205.40 5958988.69 4200,00 65,03 120,78 2777,49 325,97S 2611,82E 2,00 2035,60 563284,47 5958944,47 4300,00 65,19 122,98 2819,58 373,87S 2688,85E 2,00 2123,39 563361,87 5958897,20 4400,00 65,38 125,17 2861,40 424.76S 2764.08E 2.00 2212.11 563437.51 5958846,93 4500,00 65,60 127,35 2902,88 478,58S 2837.45E 2,00 2301,65 563511,30 5958793,72 4600,00 65,86 129,53 2943,99 535,25S 2908,84E 2,00 2391,92 563583,15 5958737,63 All data in feet unless otherwise stated, Calculation uses minimum curvature method, Coordinates from slot #32 and TVD from RKB(Nabors 16E) (106,00 Ft above mean sea level), Bottom hole distance is 10924,80 on azimuth 136,82 degrees from wellhead, Total Dogleg for wellpath is 132.55 degrees, Vertical section is from wellhead on azimuth 136,46 degrees, Grid is alaska - Zone 4, Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ( Phillips Alaska, Inc. Pad 1D,32 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 32 Version#5 Last revised : 17-0ct-2000 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 4700.00 66.15 131.70 2984.66 594.72S 2978.19E 2.00 2482.80 563652.96 5958678.74 4800.00 66.46 133.85 3024.85 656.90S 3045.39E 2.00 2574.17 563720.67 5958617.11 4900.00 66.81 136.00 3064.52 721.72S 3110.38E 2.00 2665.93 563786.18 5958552.83 5000.00 67.18 138.13 3103.60 789.11S 3173.08E 2.00 2757.96 563849.41 5958485.96 5100.00 67.58 140.26 3142.06 858.98S 3233.39E 2.00 2850.16 563910.29 5958416.59 5200.00 68.01 142.36 3179.85 931.24S 3291.26E 2.00 2942.41 5300.00 68.47 144.46 3216.92 1005.81S 3346.61E 2.00 3034.59 5345.83 68.69 145.42 3233.66 1040.73S 3371.12E 2.00 3076.78 5400.00 69.00 146.53 3253.21 1082.60S 3399.39E 2.00 3126.61 5500.00 69.60 148.57 3288.56 1161.54S 3449.58E 2.00 3218.40 563968.74 5958344.80 564024.69 5958270.69 564049.47 5958235.98 564078.08 5958194.34 564128.90 5958115.82 5535.83 69.82 149.30 3300.99 1190.32S 3466.92E 2.00 3251.21 5600.00 71.10 149.30 3322.46 1242.32S 3497.80E 2.00 3310.17 5700.00 73.10 149.30 3353.19 1324.13S 3546.38E 2.00 3402.94 5730.12 73.70 149.30 3361.80 1348.95S 3561.12E 2.00 3431.09 6000.00 73.70 149.30 3437.55 1571.67S 3693.37E 0.00 3683.64 564146.48 5958087.18 564177.77 5958035.45 564227.02 5957954.04 564241.95 5957929.34 564376.00 5957707.72 6500.00 73.70 149.30 3577.89 1984.31S 3938.40E 0.00 4151.53 6600.00 71.70 149.32 3607.63 2066.41S 3987.13E 2.00 4244.61 6700.00 69.70 149.35 3640.68 2147.59S 4035.25E 2.00 4336.61 6800.00 67.70 149.38 3677.01 2227.75S 4082.72E 2.00 4427.42 6885.04 66.00 149.41 3710.44 2295.04S 4122.53E 2.00 4503.62 564624.35 5957297.13 564673.74 5957215.44 564722.52 5957134.66 564770.64 5957054.89 564810.98 5956987.93 7000.00 66.00 149.41 3757.20 2385.45S 4175.98E 0.00 4605.97 564865.16 5956897.98 7469.08 66.00 149.41 3948.00 2754.32S 4394.08E 0.00 5023.60 565086.23 5956530.92 7500.00 66.00 149.41 3960.58 2778.63S 4408.46E 0.00 5051.12 565100.80 5956506.73 8000.00 66.00 149.41 4163.95 3171.82S 4640.93E 0.00 5496.27 565336.44 5956115.49 8500.00 66.00 149.41 4367.33 3565.00S 4873.40E 0.00 5941.42 565572.08 5955724.24 8523.77 66.00 149.41 4377.00 3583.70S 4884.45E 0.00 5962.59 565583.28 5955705.64 9000.00 66.00 149.41 4570.71 3958.19S 5105.87E 0.00 6386.57 565807.72 5955333.00 9015.47 66.00 149.41 4577.00 3970.35S 5113.07E 0.00 6400.35 565815.01 5955320.89 9047.43 66.00 149.41 4590.00 3995.48S 5127.92E 0.00 6428.80 565830.07 5955295.88 9500.00 66.00 149.41 4774.09 4351.37S 5338.34E 0.00 6831.72 566043.36 5954941.75 10000.00 66.00 149.41 4977.46 4744.56S 5570.82E 0.00 7276.88 566278.99 5954550.51 10500.00 66.00 149.41 5180.84 5137.74S 5803.29E 0.00 7722.03 566514.63 5954159.26 11000.00 66.00 149.41 5384.22 5530.93S 6035.76E 0.00 8167.18 566750.27 5953768.02 11395.28 66.00 149.41 5545.00 5841.77S 6219.55E 0.00 8519.10 566936.56 5953458.71 11500.00 66.00 149.41 5587.59 5924.11S 6268.23E 0.00 8612.33 566985.91 5953376.77 12000.00 66.00 149.41 5790.97 6317.30S 6500.71E 0.00 9057.48 567221.55 5952985.53 12032.03 66.00 149.41 5804.00 6342.49S 6515.60E 0.00 9086.00 567236.64 5952960.46 12500.00 66.00 149.41 5994.35 6710.48S 6733.18E 0.00 9502.63 567457.19 5952594.28 12784.33 66.00 149.41 6110.00 6934.07S 6865.38E 0.00 9755.77 567591.18 5952371.80 13000.00 66.00 149.41 6197.73 7103.67S 6965.65E 0.00 9947.78 567692.82 5952203.04 13162.94 66.00 149.41 6264.00 7231.79S 7041.41E 0.00 10092.84 567769.61 5952075.54 13354.70 66.00 149.41 6342.00 7382.59S 7130.57E 0.00 10263.57 567859.99 5951925.49 13500.00 66.00 149.41 6401.10 7496.85S 7198.12E 0.00 10392.93 567928.46 5951811.80 13561.21 66.00 149.41 6426.00 7544.99S 7226.58E 0.00 10447.42 567957.31 5951763.90 13757.89 66.00 149.41 6506.00 7699.65S 7318.03E 0.00 10622.53 568050.00 5951610.00 13819.35 66.00 149.41 6531.00 7747.98S 7346.60E 0.00 10677.25 568078.97 5951561.91 13861.15 66.00 149.41 6548.00 7780.85S 7366.04E 0.00 10714.46 568098.66 5951529.20 13873.44 66.00 149.41 6553.00 7790.51S 7371.75E 0.00 10725.40 568104.46 5951519.58 13912.77 66.00 149.41 6569.00 7821.44S 7390.04E 0.00 10760.42 568122.99 5951488.80 14000.00 66.00 149.41 6604.48 7890.04S 7430.59E 0.00 10838.08 568164.10 5951420.55 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot#32 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 10924.80 on azimuth 136.82 degrees from wellhead. Total Dogleg for wellpath is 132.55 degrees. Vertical section is from wellhead on azimuth 136.46 degrees. Grid is alaska - Zone 4. Grid coordinatesin FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska. Inc. Pad 1D,32 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 32 VersionS5 Last revised : 17-0ct-2000 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 14097.16 66.00 149.41 6644.00 7966.44S 7475.77E 0.00 10924.58 568209.89 5951344.52 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #32 and TVD from RKB(Nabors 16E) (106,00 Ft above mean sea level). Bottom hole distance is 10924.80 on azimuth 136.82 degrees from wellhead. Total Dogleg for wellpath is 132.55 degrees. Vertical section is from wellhead on azimuth 136.46 degrees, Grid is alaska - Zone 4, Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ~i Phillips Alaska. Inc. Pad 1D,32 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 4 Your ref : 32 Version Last revised : 17-0ct-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 400.00 399.96 1000.00 986.02 1200.00 1168.25 1500.00 1415.90 1774.89 1617.00 2800.00 2187.81 5730.12 3361.80 6500.00 3577.89 6885.04 3710.44 7469.08 3948.00 8523.77 4377.00 9015.47 4577.00 9047.43 4590.00 11395.28 5545.00 12032.03 5804.00 12784.33 6110.00 13162.94 6264.00 13354.70 6342.00 13561.21 6426.00 13757.89 6506.00 13819.35 6531.00 13861.15 6548.00 13873.44 6553.00 13912.77 6569.00 14097.16 6644.00 000N 0 1ON 4 17N 5 38N 5 38N 5 38N 5 38N 1348 95S 1984 31S 2295 04S 2754 32S 3583 70S 3970 35S 3995 48S 5841.77S 6342.49S 6934.07S 7231.79S 7382.59S 7544.99S 7699.65S 7747.98S 7780.85S 7790.51S 7821.44S 7966.44S O.OOE KOP 2.94E Begin 3 Deg Build 119.45E Begin 4 Deg Build&Turn 201.44E End Turn/Cont. Build 369.79E Begin 2 Deg Build 557.05E Base of Permafrost 1401.96E Begin 2 Deg Build&Turn 3561.12E EOC 3938.40E Begin 2 Deg Drop 4122.53E EOC 4394.08E Top of West Sak 4884.45E Base West Sak 5113.07E 9-5/8" Casing Pt. 5127.92E C80 (KiO) 6219.55E C50 6515.60E C40 (K-5) 6865.38E C30 (K-2) 7041.41E C20 (HRZ Midpoint) 7130.57E Base HRZ 7226.58E K-1 7318.03E 1D-32 17-0ct-00 7346.60E Top C3 7366.04E Top C2 7371.75E Top C1 7390.04E Top B Shale 7475.77E TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 9015.47 4577.00 3970.35S 5113.07E 9-5/8" Casing 0.00 0.00 O.OON O.OOE 14097.16 6644.00 7966.44S 7475.77E 7" Longstring Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1D-32 17-0ct-00 568050.000,5951610.000,0.0000 6506.00 7699.65S 7318.03E 12-0ct-2000 Phillips Alaska. Inc. Pad 1D.32 Kuparuk River Unit,North Slope. Alaska PROPOSAL LISTING Page 1 Your ref : 32 VersionS5 Last revised : 17-0ct-2000 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S Vert Sect Ellipse Semi Axes Minor Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 250.00 0.00 0.00 250.00 0.00 N 0.00 300.00 0,75 88,00 300.00 0.01 N 0.33 400.00 2.25 88.00 399.96 0.10 N 2,94 425.00 3.00 88.00 424.94 0.14 N 4.09 E 0.00 E 0.00 E 0.22 E 1.95 E 2.71 0.00 0.00 0.00 N/A 1.19 1.19 0.65 N/A 1.50 1.43 0.77 358.00 2.34 1.91 1,03 358.00 2.57 2.03 1.10 358.00 525.00 6.00 88.00 524.62 0.42 N 11.93 625.00 9.00 88.00 623.75 0.87 N 24.97 725.00 12.00 88.00 722.06 1.51 N 43.18 825.00 15.00 88.00 819.29 2.32 N 66.51 925.00 18,00 88,00 915.16 3,31 N 94.89 E 7.92 3.52 2.51 1.36 358.00 E 16.57 4.49 3.01 1.64 358.00 E 28.66 5.47 3.52 1.94 358.00 E 44.14 6.45 4.06 2.27 358.00 E 62.97 7.42 4,65 2.63 358,00 1000.00 20.25 88.00 986.02 4.17 N 119.45 1100.00 24.23 89.15 1078.56 5.08 N 157.27 1200.00 28.21 90.00 1168.25 5.38 N 201.44 1294.78 32,00 90.00 1250.23 5.38 N 248.97 1394.78 36.00 90.00 1333.12 5.38 N 304.88 E 79,26 8.14 5.12 2.92 358.00 E 104.67 9.07 5.84 3.36 358.10 E 134.87 9,99 6.69 3.84 358,21 E 167.62 10.83 7.65 4.35 358,23 E 206.13 11.68 8.90 4.95 358.11 1494.78 40.00 90.00 1411.90 5.38 N 366.43 1500.00 40.21 90.00 1415.90 5.38 N 369.79 1589.56 42,00 90.00 1483.38 5.38 N 428.67 1689.56 44,00 90,00 1556.51 5.38 N 496.86 1774.89 45.71 90.00 1617.00 5.38 N 557.05 E 248,54 12.50 10,44 5,60 357.65 E 250,86 12.54 10,52 5.63 357.61 E 291.42 13.26 12.09 6.25 356.16 E 338.40 14.13 13.98 6.96 305.77 E 379.86 15,97 14.66 7.59 277.32 1789.56 46.00 90,00 1627.22 5.38 N 567.57 1889.56 48.00 90.00 1695,41 5.38 N 640.70 1989.56 50.00 90,00 1761.02 5.38 N 716.17 2089,56 52.00 90.00~ 1823.94 5,38 N 793.88 2189.56 54.00 90.00 1884,12 5,38 N 873.74 E 387.11 16.29 14.78 7.70 272.43 E 437.49 18.74 15.51 8,47 271.02 E 489.48 21.47 16,22 9,26 270.56 E 543.02 24,48 16.91 10.07 270,34 E 598.03 27.80 17.57 10.91 270,22 2289.56 56.00 90.00 1941.48 5.38 N 955.65 2389.56 58.00 90.00 1995.94 5.38 N 1039.51 2489.56 60,00 90.00 2047,44 5.38 N 1125.23 2589.56 62.00 90,00 2095.92 5.38 N 1212.68 2689.56 64.00 90.00 2141.32 5.38 N 1301,78 E 654.46 31.47 18.20 11.77 270.15 E 712.24 35.51 18.81 12.65 270.10 E 771.29 39.97 19.40 13.54 270.07 E 831.54 44,90 19,96 14,46 270.04 E 892.92 50,37 20.49 15,39 270.03 2789.56 66.00 90.00 2183,58 5.38 N 1392.41 2800.00 66.21 90.00 2187.81 5.38 N 1401.96 2900.00 65.92 92.16 2228.38 3.66 N 1493.33 3000.00 65,66 94.34 2269.40 1.51S 1584,38 3100.00 65.42 96.52 2310.81 10.13 S 1674.99 E 955.35 56.45 21.00 16.34 270,02 E 961.93 57.09 21.05 16.44 270,01 E 1026,13 63.24 21,56 17.39 270.24 E 1092.60 69,36 22,06 18.34 270.63 E 1161.27 75.43 22.57 19.28 271.13 3200.00 65.23 98.71 2352.56 22.17 S 1765.05 3300.00 65.06 100.91 2394.60 37.62 S 1854,45 3400.00 64.92 103,11 2436.88 56,48 S 1943,08 3500.00 64.82 105.32 2479,35 78.71 S 2030,84 3600.00 64.75 107.53 2521.95 104.28 S 2117.62 E 1232.04 81.41 23.07 20.22 271.72 E 1304.83 87,28 23,58 21,16 272.37 E 1379.56 93.01 24,08 22,10 273.07 E 1456.13 98,57 24.58 23,04 273.79 E 1534.45 103.96 25.08 23,97 274.54 3700.00 64.72 109.74 2564.63 133.17 S 2203.31 E 1614.42 109.15 25.57 24.91 275.30 3800.00 64.71 111.95 2607.35 165.34 S 2287.80 E 1695.95 114.13 26.06 25.84 276.07 3900.00 64.74 114.16 2650.04 200.75 S 2371,00 E 1778,93 118.90 26.55 26.77 276,84 4000.00 64.81 116.37 2692.67 239.35 S 2452.81 E 1863.27 123,46 27.03 27.71 277.60 4100.00 64.90 118.58 2735.17 281.11 S 2533.11 E 1948,86 127,80 27.51 28.64 278~36 4200.00 65,03 120.78 2777.49 325.97 S 2611.82 E 2035.60 131,93 27.98 29.57 279,11 4300,00 65.19 122.98 2819.58 373,87 S 2688.85 E 2123.39 135.85 28,45 30,51 279.85 4400.00 65.38 125.17 2861.40 424.76 S 2764.08 E 2212.11 139.56 28.91 31.45 280.58 4500.00 65.60 127.35 2902.88 478.58 S 2837.45 E 2301.65 143.06 29.36 32.38 281.29 4600.00 65.86 129.53 2943.99 535.25 S 2908.84 E 2391.92 146.37 29.82 33.32 281.99 All data is in feet unless otherwise stated. Coordinates from slot #32 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 10924,80 on azimuth 136,82 degrees from wellhead. Vertical section is from wellhead on azimuth 136.46 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1D,32 Kuparuk River Unit,North Slope. Alaska PROPOSAL LISTING Page 2 Your ref : 32 VersionS5 Last revised : 17-0ct-2000 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth C 0 0 R D I N A T E S Sect Major Minor Vert. Azi. 4700.00 66.15 131.70 2984.66 594.72 S 2978.19 E 2482.80 149.49 30.26 34.27 282.68 4800.00 66.46 133.85 3024.85 656.90 S 3045.39 E 2574.17 152.42 30.70 35.21 283.35 4900.00 66.81 136.00 3064.52 721.72 S 3110.38 E 2665.93 155.17 31.14 36.16 284.00 5000.00 67.18 138.13 3103.60 789.11 S 3173.08 E 2757.96 157.75 31.57 37.10 284.63 5100.00 67.58 140.26 3142.06 858.98 S 3233.39 E 2850.16 160.16 31.99 38.06 285.25 5200.00 68.01 142.36 3179.85 931.24 S 3291.26 E 2942.41 162.41 32.41 39.01 285.85 5300.00 68.47 144.46 3216.92 1005.81S 3346.61 E 3034.59 164.50 32.83 39.97 286.43 5345.83 68.69 145.42 3233.66 1040.73 S 3371.12 E 3076.78 165.43 33.03 40.41 286.69 5400.00 69.00 146.53 3253.21 1082.60 S 3399.39 E 3126.61 166.48 33.25 40.93 286.99 5500.00 69.60 148.57 3288.56 1161.54 S 3449.58 E 3218.40 168.29 33.66 41.89 287.53 5535.83 69.82 149.30 3300.99 1190.32 S 3466.92 E 3251.21 168.92 33.81 42.24 287.72 5600.00 71.10 149.30 3322.46 1242.32 S 3497.80 E 3310.17 170.07 34.07 42.86 288.06 5700.00 73.10 149.30 3353.19 1324.13 S 3546.38 E 3402.94 171.94 34.46 43.85 288.61 5730.12 73.70 149.30 3361.80 1348.95 S 3561.12 E 3431.09 172.51 34.58 44.14 288.77 6000.00 73.70 149.30 3437.55 1571.67 S 3693.37 E 3683.64 177.66 35.63 46.81 290.18 6500.00 73.70 149.30 3577.89 1984.31 S 3938.40 E 4151.53 187.47 37.60 51.75 292.59 6600.00 71.70 149.32 3607.63 2066.41 S 3987.13 E 4244.61 189.42 38.02 52.73 293.03 6700.00 69.70 149.35 3640.68 2147.59 S 4035.25 E 4336.61 191.32 38.46 53.70 293.45 6800.00 67.70 149.38 3677.01 2227.75 S 4082.72 E 4427.42 193.17 38.92 54.65 293.85 6885.04 66.00 149.41 3710.44 2295.04 S 4122.53 E 4503.62 194.70 39.33 55.45 294.17 7000.00 66.00 149.41 3757.20 2385.45 S 4175.98 E 4605.97 196.78 39.88 56.53 294.60 7469.08 66.00 149.41 3948.00 2754.32 S 4394.08 E 5023.60 205.40 42.15 60.93 296.25 7500.00 66.00 149.41 3960.58 2778.63 S 4408.46 E 5051.12 205.96 42.30 61.22 296.36 8000.00 66.00 149.41 4163.95 3171.82 S 4640.93 E 5496.27 215.34 44.73 65.90 297.98 8500.00 66.00 149.41 4367.33 3565.00 S 4873.40 E 5941.42 224.88 47.16 70.59 299.47 8523.77 66.00 149.41 4377.00 3583.70 S 4884.45 E 5962.59 225.34 47.27 70.81 299.53 9000.00 66.00 149.41 4570.71 3958.19 S 5105.87 E 6386.57 234.57 49.58 75.28 300.83 9015.47 66.00 149.41 4577.00 3970.35 S 5113.07 E 6400.35 234.87 49.66 75.42 300.87 9047.43 66.00 149.41 4590.00 3995.48 S 5127.92 E 6428.80 235.50 49.81 75.72 300.95 9500.00 66.00 149.41 4774.09 4351.37 S 5338.34 E 6831.72 244.39 52.01 79.97 302.10 10000.00 66.00 149.41 4977.46 4744.56 S 5570.82 E 7276.88 254.34 54.43 84.65 303.26 10500.00 66.00 149.41 5180.84 5137.74 S 5803.29 E 7722.03 264.38 56.84 89.34 304.34 11000.00 66.00 149.41 5384.22 5530.93 S 6035.76 E 8167.18 274.52 59.24 94.03 305.34 11395.28 66.00 149.41 5545.00 5841.77 S 6219.55 E 8519.10 282.60 61.14 97.73 306.08 11500.00 66.00 149.41 5587.59 5924.11 S 6268.23 E 8612.33 284.75 61.64 98.71 306.27 12000.00 66.00 149.41 5790.97 6317.30 S 6500.71 E 9057.48 295.04 64.03 103.40 307.14 12032.03 66.00 149.41 5804.00 6342.49 S 6515.60 E 9086.00 295.71 64.18 103.70 307.19 12500.00 66.00 149.41 5994.35 6710.48 S 6733.18 E 9502.63 305.41 66.42 108.09 307.95 12784.33 66.00 149.41 6110.00 6934.07 S 6865.38 E 9755.77 311.34 67.77 110.75 308.37 13000.00 66.00 149.41 6197.73 7103.67 S 6965.65 E 9947.78 315.83 68.80 112.77 308.70 13162.94 66.00 149.41 6264.00 7231.79 S 7041.41 E 10092.84 319.25 69.57 114.30 308.93 13354.70 66.00 149.41 6342.00 7382.59 S 7130.57 E 10263.57 323.27 70.49 116.10 309.20 13500.00 66.00 149.41 6401.10 7496.85 S 7198.12 E 10392.93 326.32 '71.18 117.46 309.41 13561.21 66.00 149.41 6426.00 7544.99 S 7226.58 E 10447.42 327.60 71.47 118.03 309.49 13757.89 66.00 149.41 6506.00 7699.65 S 7318.03 E 10622.53 331.74 72.40 119.88 309.75 13819.35 66.00 149.41 6531.00 7747.98 S 7346.60 E 10677.25 333.04 72.69 120.45 309.83 13861.15 66.00 149.41 6548.00 7780.85 S 7366.04 E 10714.46 333.92 72.89 120.85 309.89 13873.44 66.00 149.41 6553.00 7790.51 S 7371.75 E 10725.40 334.18 72.95 120.96 309.90 13912.77 66.00 149.41 6569.00 7821.44 S 7390.04 E 10760.42 335.01 73.14 121.33 309.95 14000.00 66.00 149.41 6604.48 7890.04 S 7430.59 E 10838.08 336.85 73.55 122.15 310.07 All data is in feet unless otherwise stated. Coordinates from slot#32 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 10924.80 on azimuth 136.82 degrees from wellhead. Vertical section is from wellhead on azimuth 136.46 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1D,32 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 32 VersionS5 Last revised : 17-0ct-2000 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Sect Ellipse Semi Axes Minor Major Minor Vert. Azi. 14097.16 66.00 149.41 6644.00 7966.44 S 7475.77 E 10924.58 338.90 74.01 123.06 310.19 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 14097 MWD + IFR (Alaska) - Corrected Dat User specified 338.90 74.01 123.06 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. All data is in feet unless otherwise stated. Coordinates from slot#32 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 10924.80 on azimuth 136.82 degrees from wellhead. Vertical section is from wellhead on azimuth 136.46 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1D,32 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 4 Your ref : 32 Version#5 Last revised : 17-0ct-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 400.00 1000.00 1200.00 1500.00 1774.89 2800.00 5730.12 6500.00 6885.04 7469.08 8523.77 9015.47 9047.43 11395.28 12032.03 12784.33 13162.94 13354.70 13561.21 13757.89 13819.35 13861.15 13873.44 13912.77 14097.16 250.00 399.96 986.02 1168.25 1415.90 1617.00 2187.81 3361.80 3577.89 3710.44 3948.00 4377.00 4577.00 4590.00 5545 O0 5804 O0 6110 O0 6264 O0 6342 O0 6426 O0 6506 O0 6531 O0 6548 O0 6553 O0 6569 O0 6644 O0 0.00 N O. 0.10 N 2 4.17 N 119 5.38 N 201 5.38 N 369 5.38 N 557 5.38 N 1401 1348.95 S 3561 1984.31 S 3938 2295.04 S 4122 2754.32 S 4394 3583.70 S 4884 3970.35 S 5113 3995.48 S 5127 5841.77 S 6219 6342.49 S 6515 6934.07 S 6865 7231.79 S 7041 7382.59 S 7130 7544.99 S 7226 7699.65 S 7318 7747.98 S 7346 7780.85 S 7366 7790.51 S 7371 7821.44 S 7390 7966.44 S 7475 O0 E KOP 94 E Begin 3 Deg Build 45 E Begin 4 Deg Build&Turn 44 E End Turn/Cont. Build 79 E Begin 2 Deg Build 05 E Base of Permafrost 96 E Begin 2 Deg Build&Turn 12 EEOC 40 E Begin 2 Deg Drop 53 E EOC 08 E Top of West Sak 45 E Base West Sak 07 E 9-5/8" Casing Pt. 92 E C80 (KiO) 55 E C50 60 E C40 (K-5) 38 E C30 (K-2) 41 E C20 (HRZ Midpoint) 57 E Base HRZ 58 E K-1 03 E 1D-32 17-0ct-00 60 E Top~C3 04 E Top C2 75 E Top C1 04 E Top B Shale 77 E TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 9015.47 4577.00 3970.35S 5113.07E 9-5/8" Casing 0.00 0.00 O.OON O.OOE 14097.16 6644.00 7966.44S 7475.77E 7" Longstring Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1D-32 17-0ct-00 568050.000,5951610.000,0.0000 6506.00 7699.65S 7318.03E 12-0ct-2000 Phillips Alaska, Inc. Pad iD 32 slot #32 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 32 Version #5 Our ref : prop2091 License : Date printed : 18-0ct-2000 Date created : 23-Feb-1997 Last revised : 17-0ct-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 57.215,w149 30 31.152 Slot Grid coordinates are N 5959249.170, E 560670.327 Slot local coordinates are 417.00 S 420.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 1000 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath 140PB1 PMSS IFR <0-6937>,,140PB1,Pad iD 141L1 PMSS<5475'-9480'>,,141L1,Pad iD 141 PMSS <0-9550'>,,141,Pad iD 136 PMSS <519 - 5680'>,,136,Pad 1D PMSS <0-5015'>,,135,Pad iD PMSS <256 - 5973'>,,l10,Pad 1D 137 PMSS <0 - 5615'>,,137,Pad 1D PMSS <0-3252'>,,133PB1,Pad 1D PMSS <1957-5265'>,,133,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <0-6543'>,,138,Pad 1D PMSS <0-1288'>,,138PB1,Pad 1D PMSS <0-4414'>,,121,Pad 1D PMSS <377 - 6224'>,,134,Pad 1D PMSS <6527-7378'>,,102,Pad 1D L1 PMSS <4338-7400'> Sperry,,102L1,Pad ID PMSS <6143-6767'>,,102PB3,Pad iD PMSS <5181-6454'>,,102PB2,Pad 1D PMSS <0-5354'>,,102PBl,Pad iD PMSS <0-11234'>,,il,Pad ID Closest approach with 3-D Minimum Distance method Last revised Distance 6-0ct-2000 26-Sep-2000 6-Sep-2000 5-Jun-2000 2-Jun-1998 24-Apr-2000 2-Jun-2000 21-Sep-2000 2-Jun-1998 6-Nov-1997 18-May-2000 18-May-2000 2-Jun-1998 3-Aug-1998 28-Jul-2000 27-Jul-2000 27-Jul-2000 27-Jul-2000 28-Jul-2000 30-Dec-1999 182 4 172 4 136 1 266 5 208 9 492 2 278 9 182 1 182 1 188 0 291 5 291 5 294 0 200 4 614 8 614 8 614 8 614 8 614 8 244 1 220 0 6380 0 2489 6 314 3 314 3 160 0 280 0 160 0 160 0 328 6 120 0 120 0 275 0 280 0 625 0 625 0 625 0 625 0 625 0 380 0 Diverging from M.D. 14080.0 13861.1 8760.0 5500.0 314.3 5720.1 6360.0 9020.0 5475.0 328.6 12440.0 5662.5 275.0 6920.0 7260.0 8500.0 12860.0 13180.0 13980.0 11540.0 PGMS <O-8610'>,,6,Pad iD 139 <PMSS 515 - 4838'>,,139,Pad ID PMSS <5155'- 5905'>,,l10A, Pad 1D PMSS <0-4590'>,,l18,Pad 1D PGMS <0-8930'>,,5,Pad 1D PMSS <O-5126'>,,106,Pad 1D PMSS <381-6092'>,,105,Pad 1D PGMS <0-9783'>,,2,Pad 1D PMSS <467 - 5802'>,,132,Pad 1D PMSS <0 - 6472'>,,131,Pad 1D PMSS <0-4778'>,,130,Pad 1D PMSS <0-5462'>,,129,Pad 1D PMSS <0-4515'>,,llg,Pad 1D PGMS <0-8070'>,,3,Pad 1D PMSS <0-4530'>,,120,Pad 1D PMSS <0 - 6716'>,,126,Pad iD PMSS <0 - 7432'>,,127,Pad iD PMSS <0 - 6580'>,,128,Pad 1D PMSS <0 - 5445'>,,122,Pad 1D GSS <0-173'>,,123,Pad 1D PMSS <287-6055'>,,123,Pad 1D GSS <0-175'>,,l16,Pad iD PMSS <290-6245'>,,l16,Pad 1D PMSS <0-5047'>,,124,Pad ID PMSS <291 - 5795'>,,125,Pad 1D PGMS <0-8365'>,,1,Pad ID PMSS <0 - 7150'>,,108,Pad ID PMSS <0-4850'>,,109,Pad 1D PMSS<0-7045'>,,lll,Pad iD PMSS <0-9250'>,,12,Pad 1D PMSS <0-8702'>,,14,Pad iD PMSS <556-7024'>,,9,Pad 1D PMSS <294 - 8250'>,,l12,Pad 1D PMSS <293 - 6866'>,,l13,Pad 1D PMSS <0 - 6270'>,,l14,Pad iD PMSS <0-5142'>,,l15,Pad 1D PGMS <0-8850'> 28-May-81,,MP 1 17-ii-ii,Pad 1D PMSS <4674'-5639'>,,125A, Pad 1D PMSS <0-5205'>,,l17,Pad 1D PMSS <0 - 7340'>,,10,Pad iD PGMS <0 - 6400'>,,WS-8,Pad iD PGMS <0-7502'>,,4 Pad iD PMSS IFR <0-12225'>, 40,Pad 1D PMSS IFR <0-14324'>, 38,Pad 1D PMSS IFR <0-11660'>, 36,Pad 1D PMSS IFR <0-12044'>, 30,Pad 1D PMSS IFR <1465-????'> ,34,Pad 1D 13-Nov-1997 18-May-2000 17-May-2000 2-Jun-1998 13-Nov-1997 2-Jun-1998 2-Jun-1998 4-Aug-1992 6-Aug-1998 23-Ju1-1998 2-Jun-1998 2-Jun-1998 2-Jun-1998 13-Aug-1998 2-Jun-1998 1-Ju1-1998 6-Ju1-1998 17-Aug-1998 29-Aug-1998 4-SED-1998 13-Sep-1998 8-Sep-1998 17-Sep-1998 2-Jun-1998 19-Au~-1998 10-Dec-1997 28-Oct-1998 2-Jun-1998 3-Sep-1998 21-Jan-2000 6-Oct-1999 29-Apr-1998 21-Sep-1998 22-SED-1998 2-SED-1998 2-Jun-1998 186.2 301.4 492.3 355.3 247.2 548.4 575.8 560.2 179.7 179.0 178.0 180.0 317.6 448.7 306.1 212.0 204.6 197.1 282.2 270.4 268.8 382.9 382.9 229.0 220.5 674.9 520.5 506.1 477.6 657.4 648.7 331.0 436.5 423.3 408.6 396.2 23-Apr-1999 )5237.2 24-Apr-2000 2-Jun-1998 28-Apr-1998 27-Apr-2000 4-Au~-1992 2-Oct-2000 2-Oct-2000 2-Oct-2000 2-Oct-2000 15-0ct-2000 220.8 369.1 227.1 256.3 341.7 114.3 88.0 56.2 23.7 24.3 287 5 262 5 160 0 328 6 340 0 200 0 328 6 400 0 160 0 160 0 300 0 220 0 340 0 371.4 262.5 200.0 140.0 262.5 280.0 160.0 280.0 160.0 160.0 287.5 160.0 425.0 160.0 250.0 320.0 547.2 260.0 280.0 180.0 180.0 342.9 200.0 6200.0 160.0 328.6 180.0 320.0 360.0 558.3 400.0 502.8 540.0 525.0 287 262 160 328 340 200 328 400 8180 10580 7260 9340 340 371 262 20O 12400 262 280 160 12060 160 4840 6562 160 425 5440 250 5320 11940 260 28O 4462 180 342 4762 6660 160 328 647 320 360 558 11820 10600 7960 14097 Phillips Alaska, Inc. Pad 1D 32 slot #32 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 32 Version #5 Our ref : prop2091 License : Date printed : 18-0ct-2000 Date created : 23-Feb-1997 Last revised : 17-0ct-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 57.215,w149 30 31.152 Slot Grid coordinates are N 5959249.170, E 560670.327 Slot local coordinates are 417.00 S 420.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel 1 path 140PB1 PMSS IFR <0-6937>,,140PB1,Pad 1D 141L1 PMSS<5475'-9480'>,,141L1,Pad 1D 141 PMSS <0-9550'>,,141,Pad 1D 136 PMSS <519 - 5680'>,,136,Pad 1D PMSS <O-5015'>,,135,Pad 1D PMSS <256 - 5973'>,,1lO,Pad 1D 137 PMSS <0 - 5615'>,,137,Pad 1D PMSS <0-3252'>,,133PB1,Pad 1D PMSS <1957~5265'>,,133,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <O-6543'>,,138,Pad 1D PMSS <O-1288'>,,138PB1,Pad 1D PMSS <O-4414'>,,121,Pad 1D PMSS <377 - 6224'>,,134,Pad 1D PMSS <6527-7378'>,,102,Pad 1D L1PMSS <4338-7400'> Sperry,,lO2L1,Pad 1D PMSS <6143-6767'>,,102PB3,Pad 1D PMSS <5181-6454'>,,102PB2,Pad 1D PMSS <O-5354'>,,102PB1,Pad 1D PMSS <0-11234'>,,11,Pad 1D PGMS <0-8610'>,,6,Pad 1D 139 <PMSS 515 - 4838'>,,139,Pad 1D PMSS <5155'- 5905'>,,110A,Pad 1D PMSS <O-4590'>,,118,Pad 1D PGMS <O-8930'>,,5,Pad 1D PMSS <O-5126'>,,106,Pad 1D PMSS <381-6092'>,,105,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance 6-0ct-2000 183.6 26-Sep-2000 246.9 6-Sep-2000 179.2 5-Jun-2000 268.8 2-Jun-1998 211.0 24-Apr-2000 493.5 2-Jun-2000 280.8 21-Sep-2000 183.2 2-Jun-1998 183.2 6-Nov-1997 192.7 18-May-2000 291.9 18-May-2000 291.9 2-~un-1998 295.6 3-Aug-1998 203.3 28-Jul-2000 619.9 27-~ul-2000 619.9 27-~ul-2000 619.9 27-~ul-2000 619.9 28-~ul-2000 619.9 30-Dec-1999 246.8 13-Nov-1997 188.7 18-May-2000 303.9 17-May-2000 493.5 2-~un-1998 357.5 13-Nov-1997 250.0 2-Jun-1998 549.6 2-~un-1998 577.5 M.D, 20.0 6360.0 2380.0 20.0 262 5 100 0 200 0 100 0 100 0 250 0 20 0 20 0 100 0 260 0 602 8 602 8 602 8 602 8 602 8 314 3 200 0 140 0 100 0 260 0 275 0 100 0 287 5 Diverging from M.D. 14080 6360 6400 5662 262 100 200 100 lO0 25O 7380 20 100 260 5462. 4440. 5462. 5462. 5462. 5487. 200. 140. 100. 260. 275. 100. 287. PGMS <0-9783'>,,2,i 1D PMSS <467 - 5802'>,,132,Pad 1D PMSS <0 - 6472'>,,131,Pad 1D PMSS <0-4778'>,,130,Pad 1D PMSS <0-5462'>,.129,Pad 1D PMSS <O-4515'>,,119,Pad 1D PGMS <O-8070'>,,3,Pad 1D PMSS <0-4530'>,,120,Pad 1D PMSS <0 - 6716'>,,126,Pad 1D PMSS <0 - 7432'>,,127,Pad 1D PMSS <0 - 6580'>,,128,Pad 1D PMSS <0 - 5445'>,,122,Pad 1D GSS <0-173'>,,123,Pad 1D PMSS <287-6055'>,,123,Pad 1D GSS <O-175'>,,116,Pad 1D PMSS <290-6245'>,,116,Pad 1D PMSS <O-5047'>,,124,Pad 1D PMSS <291 - 5795'>,.125,Pad 1D PGMS <0-8365'>,,1,Pad 1D PMSS <0 - 7150'>,,108,pad 1D PMSS <O-4850'>,,109,Pad 1D PMSS<O-7045'>,,111,Pad 1D PMSS <O-9250'>,,12,Pad 1D PMSS <O-8702'>,,14,Pad 1D PMSS <556-7024'>,,9,Pad 1D PMSS <294 - 8250'>,,112,Pad 1D PMSS <293 - 6866'>,,113,Pad 1D PMSS <0 - 6270'>,,114,Pad 1D PMSS <O-5142'>,,115,Pad 1D PGMS <0-8850'> 28-May-81,,MP 1 17-ii-ii,Pad 1D PMSS <4674'-5639'>,,125A,Pad 1D PMSS <0-5205'>,,117,Pad 1D PMSS <0 - 7340'>,,lO,Pad 1D PGMS <0 - 6400'>,,WS-8,Pad 1D PGMS <O-7502'>,,4,Pad 1D PMSS IFR <O-12225'>,,40,Pad 1D PMSS IFR <O-14324'>,,38,Pad 1D PMSS IFR <O-11660'>,,36,Pad 1D PMSS IFR <0-12044'>,,30,Pad 1D PMSS IFR <1465-????'>,,34,Pad 1D 4-Aug-1992 6-Aug-1998 23-2u1-1998 2-Jun-1998 2-Jun-1998 2-Jun-1998 13-Aug-1998 2-Jun-1998 1-Ju1-1998 6-Ju1-1998 17-Aug-1998 29-Aug-1998 4-Sep-1998 13-Sep-1998 8-Sep-1998 17-Sep-1998 2-Jun-1998 19-Aug-1998 10-Dec-1997 28-0ct-1998 2-Jun-1998 3-Sep-1998 21-Jan-2000 6-0ct-1999 29-Apr-1998 21-Sep-1998 22-Sep-1998 2-Sep-1998 2-Jun-1998 23-Apr-1999 24-Apr-2000 2-Jun-1998 28-Apr-1998 27-Apr-2000 4-Aug-1992 2-0ct-2000 2-0ct-2000 2-0ct-2000 2-0ct-2000 15-0ct-2000 563.8 181.0 180.0 180.1 181.7 319.9 451.8 307.7 213.3 205.5 198.6 283.8 272.0 271.2 384.2 384.2 231.0 221.8 678.3 521.6 507.5 479.5 661.5 650.0 332.6 437.9 424.6 410.9 397.6 5597.0 221.8 371.0 228.2 259.0 345.1 119.3 90.0 59.6 28.7 28.9 lO0.u 100.0 262.5 200.0 262.5 0.0 100 0 100 0 100 0 100 0 100 0 160 0 260.0 100.0 100.0 100.0 100.0 287.5 100.0 100.0 100.0 513.9 100.0 100.0 100.0 100 0 262 5 160 0 5800 0 100 0 100 0 100.0 260.0 262.5 491.7 100.0 250.0 480.0 480.0 262.5 100.0 100.0 262.5 200.0 262.5 262.5 100.0 100.0 100.0 5175.0 100.0 160.0 13700.0 100.0 100.0 100.0 100.0 287.5 100.0 100.0 100.0 513.9 100.0 100.0 100.0 100.0 262.5 160.0 5800.0 100.0 100.0 100 0 260 0 262 5 491 7 100 0 250 0 7720 0 7860 0 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY October 25, 2000 Daniel T. Seamount, Jr., Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 1 D-32 Surface Location: 417' FNL 420' FEL Sec 23 T11N R10E, UM Target Location: 2440' FSL, 1612' FWL Sec. 30, T11 N, R11 E, UM Bottom Hole Location: 2173' FSL, 1770' FWI Sec. 30, T11 N, R11 E, UM Dear Commissioner Seamount, Phillips Alaska, Inc. hereby files this Application for Permit to Drill the development well KRU 1 D-32 Nabors Rig 16e will drill and complete this well. 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 1D, or hauled to an approved Prudhoe or GKA Class II disposal well. This well will be an injector in the Kuparuk River formation. Phillips Alaska, Inc. requests an exemption from the U2S requirements. However, Phillips Alaska, Inc. will monitor all operations for H2S. The following are Phillips' designated contacts for reporting responsibilities to the Commission: 1) Completion Report Sharon AIIsup-Drake, Drilling Technologist 263-4612 (20 AAC 25.070) 2) Geologic Data and Logs StaceyWaggoner, Geologist 265-1391 (20 AAC 25.071) If you have questions or require additional information, please contact Todd Mushovic at 265- 6974 or me at 265-6434 in our Anchorage office. Sincerely, _ -- 3-ames Trantham Drilling Engineering Supervisor Attachments cc: KRU 1D-32Well File OCT 26 2000 Alaska 0il & Gas 00ns. 60m,~issi0n /~ch0rS!;le Am~r~;an Express® OA~ ~ 6-- ~5'-oo ~-.o,,o~: PAY TO THE : . I~U~ by In~ pay~nt Sy~ In~ ~ DOLLARS En~lewo~, ~1o~o ~ / .~a~le '~No~t B~k of G~d Jun~n - Down~wn, N~ NOT VALID FOR AHOUNT OVER $ 1000 ..._ -_. -.. :WELL PERMIT CHECKLIST COMPANY FIELD & POOL 4./~'~/~.~ ADMINISTRATION APPR DATE ,2,~ lo, · ENGINEERING DATE · WELL NAME /Z~ -.~ ~ PROGRAM: exp ~ dev ~ reddl ~ serv __ wellbore seg ann. disposal para req ~ INIT CLASS '~c- 1/' //_.c)/.,n,L./ GEOL AREA ?~('~ UNIT# (~././'/~" ("-'~ ON/OFF SHORE 1. Permit fee attached ...................... 2. Lease number appropriate.~<. ...~L.. ~,._~.~/~.-/~. ~.-~t, ; ./O-:~.~/ 3. Unique well name and,number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... N N 14. Conductor string provided ~ N 15. Surface casing protects all known USDWs ........... ~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... N 17. CMT vol adequate to tie-in long string to surf csg .... . .... Y N 18. CMT will cover all known productive horizons .......... N , 19. Casing designs adequate for C, T, B & permafrost ....... N 20. Adequate tankage or reserve pit ................. N 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 ................ (.~Y~N 26. BOPE press rating appropriate; test to 5'O~O psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... ~'~ N 29. Is presence of H2S gas probable ................. ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... .Y. ~ 31. Data presented on potential overpressure zones ..... . . . 32. Seismic analysis of shallow gas zones .......... . '.., ~ ~ ~"~Y N IIAP~R DATE 33. Seabed condition survey (if.off-shore) ....... '..~.<-'...~" ' Y N II/D /O,"~0'~c) 34. Contact name/phone for weekly progress reports~oratory only] Y N II'ANNULAR DISPOSAL35. With proper cementing records, this plan · II (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 GEOLOG't': ENGINEERING: UICIAnnular COMMISSION: WM Comments/Instructions: Z ..-.I -1- c:\msoffice\wordian\diana\checklist (rev. 02117/00) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No'special'effort has been made to chronologically organize this category of information. · : . .. ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ~Version Information VERSo WRAP. ~Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 8407.0000: STOP.FT 10300.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NUMBER: ~Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 Description Starting Depth Ending Depth Level Spacing Absent Value ConocoPhillips Alaska, Inc. 1D-42L1PBl Kuparuk River Unit 70 deg 17' 56.740"N 149 deg 30' 31.173" W North Slope Borough Alaska Baker Hughes INTEQ 2.375" CTK 10-Jul-05 500292297970 ------------------------------- Information CWLS log ASCII Standard -VERSION 1.20 One line per frame () O()- r93 :tï {d 7-D3 23 IIN 10E MSL o RKB 106 KB 106 N/A o N/A DIRECTIONAL SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSl . ~Remarks ------------------------------- 1.20: NO: Remark File Version 1.000 Extract File: ldwg.las SCANNED OCT 3 0 2000 -,-" *** *** LIS COMMENT RECORD 2.375" CTK 932692 01 **** TAPE HEADER **** MWD 05/07/10 LIS Customer Format Tape BHI 01 **** REEL HEADER **** MWD 06/10/06 -- .............' ~ (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bi t) , a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control) log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from ID-42 through a milled window in 3 1/2" liner. Top of Window 8415 ft.MD (6130 ft.SSTVD) Bottom of Window 8421 ft.MD (6134 ft.SSTVD) (8) The interval from 10276 ft. to 10300 ft.MD (6170 ft. to 6174 ft.SSTVD) was not logged due to sensor bit offset. (9) Tied to ID-42 at 8294 ft.MD (6051 ft.SSTVD) (10) The well ID-42Ll was kicked off this plugback wellbore ID-42LIPBI at 9750 MNEMONICS: GRAX -> ROPS -> TVD -> ft.MD (6137.34 ft.SSTVD) Gamma Ray MWD-AAPI [MWD] (MWD-API units) Rate of Penetration, feet/hour Subsea True vertical Depth, feet Tape Subfile: 1 67 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN LCC CN WN FN COUN STAT 1D-42LIPBl 5.xtf 150 ConocoPhillips Alaska Inc. ID-42LIPB1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted c_ ~- *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 8 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 127 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 ------- 4 Total Data Records: 30 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 8407.500000 10300.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 38 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN 1D-42LIPBl.xtf 150 ConocoPhil1ips Alaska In 932692 01 **** TAPE TRAILER **** MWD 05/07/10 54 bytes 4124 bytes Minimum record length: Maximum record length: 68 records... Tape Subfile: 3 **** FILE TRAILER **** feet Tape File start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 8407.250000 10300.000000 0.250000 60 Total Data Records: 4 ------- 4 4 AAPI 1 68 GRAX MWD 1 Size Length Name Tool Code Samples Units 1 Curves: Tape depth ID: F ONE DEPTH PER FRAME 0.250 * F FRAME SPACE = Data record type is: 0 Datum Frame Size is: 8 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 127 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 * FORMAT RECORD (TYPE# 64) 0.0 GRAX GRAX GRAX ---------------------------------------------------- ODEP *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM !!! !! !! ! !! !! ! !! !!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** LIS COMMENT RECORD *** 1D-42L1PBl Kuparuk River Unit North Slope Alaska WN FN COUN STAT ,,-,- **** REEL TRAILER **** MWD 06/10/06 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: ---- 2 records... 132 bytes 132 bytes _J '- Tape Subfile 1 is type: LIS Tape Subfile 2 is DEPTH 8407.5000 8408.0000 8500.0000 8600.0000 8700.0000 8800.0000 8900.0000 9000.0000 9100.0000 9200.0000 9300.0000 9400.0000 9500.0000 9600.0000 9700.0000 9800.0000 9900.0000 10000.0000 10100.0000 10200.0000 10300.0000 -- type: LIS GR 134.7300 110.4000 112.3800 99.8400 88.8600 88.6000 66.6500 81.5500 76.5800 70.0500 69.5300 68.7400 70.8300 84.1600 75.5400 84.6800 92.0000 85.7300 71.0900 71.0900 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units ----- 8407.500000 10300.000000 0.500000 feet Tape Subfile 3 is DEPTH 8407.2500 8407.5000 8500.0000 8600.0000 8700.0000 8800.0000 8900.0000 9000.0000 9100.0000 9200.0000 9300.0000 9400.0000 9500.0000 9600.0000 9700.0000 9800.0000 9900.0000 10000.0000 10100.0000 10200.0000 10300.0000 -- type: LIS GRAX 144.2200 134.7300 112.3800 99.8400 88.8600 88.6000 66.6500 81.5500 76.5800 70.0500 69.5300 68.7400 70.8300 84.1600 75.5400 84.6800 92.0000 85.7300 71.0900 71.0900 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units ~-,/ 8407.250000 10300.000000 0.250000 feet --- Tape Subfile 4 is type: LIS Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Sep 13 15:27:10 2001 oo-173 Reel Header Service name ............. LISTPE Date ..................... 01/09/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/09/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS'Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE 1ST STRING 12.250 2ND STRING 8.500 MWD RUN 3 AK-MM-00259 P. SMITH F. HERBERT (IN) 1D-32 500292298200 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 13-SEP-01 MWD RUN 5 AK-MM-00259 T. MCGUIRE G. WHITLOCK 23 lin 10E 417 420 .00 104.45 70.90 CASING SIZE (IN) 16.000 9.625 DRILLERS DEPTH (FT) 120.0 9007.0 3RD STRING 6.125 7.000 13323.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY AND ARE NOT PRESENTED. NO DATA WERE ACQUIRED ON RUN 4 DUE TO PULSER FAILURE. 4. MWD RUN 3 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). 5. MWD RUN 5 WAS DIRECTIONAL WITH DGR, EWR4, PWD, COMPENSATED THERMAL NEUTRON (CTN),AND STABILIZED LITHO-DENSITY (SLD) . THERE WAS NO SLIDING DURING RUN 5 6. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHWARTZ, PHILLIPS ALASKA, DATED 01/30/01. 7. MWD RUNS 3 & 5 REPRESENT WELL 1D-32 WITH API#:50-029-22982-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14138'MD / 6679.48'TVD. File Header SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SST MATRIX, FIXED HOLE SIZE). SBD2 = SMOOTHED BULK DENSITY - COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) PARAMETERS USED IN POROSITY-LOG PROCESSING HOLE SIZE: MUD WEIGHT: MUD SALINITY: FORMATION WATER SALINITY: FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: $ 6.125" 11.3 ppg 800-900 ppm C1- 13,000 ppm 1.0 g/cc 2.65 g/cc SANDSTONE Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NLrMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SEIMMARY PBU TOOL CODE START RPX 8975 RPS 8975 RPM 8975 RPD 8975 FET 8975 ROP 8975 GR 8976 FCNT 13244 NCNT 13244 NPHI 13244 PEF 13259 RHOB 13319 DRHO 13319 $ BASELINE CURVE FOR SHIFTS: DEPTH 0 0 0 0 0 0 5 0 5 5 0 0 0 CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 14089 0 14089 0 14089 0 14089 0 14089 0 14140 0 14082 0 14045 5 14045 5 14045 5 14061 0 14061 0 14061 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 8975.0 13333.5 5 13333.5 14140.0 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 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 8975 14140 ROP MWD FT/H 0 980.03 GR MWD API 23.45 432.08 RPX MWD OHMM 1.07 1238.01 RPS MWD OHMM 1.22 1656.38 RPM MWD OHMM 0.43 2000 RPD MWD OHMM 0.58 2000 FET MWD HOUR 0.2 136.03 NPHI MWD PU-S 23.46 60.32 FCNT MWD CNTS 129.42 671.34 NCNT MWD CNTS 15232.7 32903.4 RHOB MWD G/CM 2.19 3.16 DRHO MWD G/CM -0.14 0.43 PEF MWD BARN 3.92 17.17 Mean Nsam 11557.5 10331 151.447 10331 143.166 10212 3.97669 10229 4.52676 10229 13.6135 10229 17.0197 10229 2.97187 10229 41.0529 1.603 262.319 1604 20890.3 1603 2.4602 1485 0.0584377 1485 7.75958 1605 First Reading 8975 8975 8976.5 8975 8975 8975 8975 8975 13244.5 13244 13244.5 13319 13319 13259 Last Reading 14140 14140 14082 14089 14089 14089 14089 14089 14045.5 14045.5 14045.5 14061 14061 14061 First Reading For Entire File .......... 8975 Last Reading For Entire File ........... 14140 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/13 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 8975.0 13285 5 RPS 8975.0 13285 5 FET 8975.0 13285 5 RPD 8975.0 13285 5 ROP 8975.0 13333 5 RPM 8975.0 13285 5 GR 8976.5 13293 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ 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 23-NOV-00 Insite 65.41 Memory 13335.0 64.3 67.4 TOOL NUMBER PBO1727HWRG6 PBO1727HWRG6 8.500 LSND 9.00 42.0 8.5 900 8.7 2.200 1.350 1.900 1.500 68.0 115.0 68.0 68.0 Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD030 FT/H 4 1 68 MWD030 API 4 1 68 MWD030 OHMM 4 1 68 MWD030 OHMM 4 1 68 MWD030 OHMM 4 1 68 MWD030 OHMM 4 1 68 MWD030 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 8975 13333.5 ROP MWD030 FT/H 0 980.03 GR MWD030 API 23.45 432.08 RPX MWD030 OHMM 1.07 1238.01 RPS MWD030 OHMM 1.22 16.78 RPM MWD030 OHMM 0.43 91.86 RPD MWD030 OHMM 0.58 2000 FET MWD030 HOUR 0.2 115.77 Mean 11154.3 162.653 147.226 3.84035 3.96885 4.86385 11.7315 1.76377 N s am 8718 8718 8634 8622 8622 8622 8622 8622 First Reading 8975 8975 8976.5 8975 8975 8975 8975 8975 Last Reading 13333.5 13333.5 13293 13285.5 13285.5 13285.5 13285.5 13285.5 First Reading For Entire File .......... 8975 Last Reading For Entire File ........... 13333.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/13 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FCNT NPHI NCNT PEF RPD RPX RPM FET RPS GR RHOB DRHO ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 13244 0 13244 5 13244 5 13259 0 13286 0 13286 0 13286 0 13286 0 13286 0 13293 5 13319 0 13319 0 13334 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR EWR4 SLD CTN $ DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON 14045 5 14045 5 14045 5 14061 0 14089 0 14089 0 14089.0 14089.0 14089.0 14082.0 14061.0 14061.0 14140.0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS 30-NOV-00 Insite 4.15 Memory 14138.0 62.7 65.6 TOOL NUMBER 1744/1705 1744/1705 1744/1705 1744/1705 6.125 LSND 11.30 44.0 10.5 90O 4.4 .450 .230 1.200 .800 65.0 135.3 65.0 65.0 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 DEPT FT 4 1 68 ROP MWD050 FT/H 4 1 68 GR MWD050 API 4 1 68 RPX MWD050 OHMM 4 1 68 RPS MWD050 OHFIM 4 1 68 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1 68 FET MWD050 HOUR 4 1 68 NPHI MWD050 PU-S 4 1 68 FCNT MWD050 CNTS 4 1 68 NCNT MWD050 CNTS 4 1 68 RHOB MWD050 G/CM 4 1 68 DRH0 MWD050 G/CM 4 1 68 PEF MWD050 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 13244 14140 ROP MWD050 FT/H 1.38 213.12 GR MWD050 API 44.62 235.12 RPX MWD050 OHMM 1.45 19.33 RPS MWD050 0HMM 1.44 1656.38 RPM MWD050 OHMM 1.27 2000 RPD MWD050 OHMM 1.5 2000 FET MWD050 HOUR 0.39 136.03 NPHI MWD050 PU-S 23.46 60.32 FCNT MWD050 CNTS 129.42 671.34 NCNT MWD050 CNTS 15232.7 32903.4 RHOB MWD050 G/CM 2.19 3.16 DRHO MWD050 G/CM -0.14 0.43 PEF MWD050 BARN 3.92 17.17 Mean 13692 90.8816 120.948 4.70823 7.5201 60.5578 45.3923 9.45371 41.0529 262.319 20890.3 2.4602 0.0584377 7.75958 Nsam 1793 1613 1578 1607 1607 1607 1607 1607 1603 1604 1603 1485 1485 1605 First Reading 13244 13334 13293.5 13286 13286 13286 13286 13286 13244.5 13244 13244.5 13319 13319 13259 Last Reading 14140 14140 14082 14089 14089 14089 14089 14089 14045.5 14045.5 14045.5 14061 14061 14061 First Reading For Entire File .......... 13244 Last Reading For Entire File ........... 14140 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/09/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/09/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File
