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Home My WebLink About201-115ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 2N-302 50103203800000 2011150 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 29, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2N-302 KUPARUK RIV U TARN 2N-302 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2022 2N-302 50-103-20380-00-00 201-115-0 G SPT 5186 2011150 1500 3475 3490 3490 3490 258 263 263 263 4YRTST P Adam Earl 8/1/2022 MIT-IA 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 U TARN 2N-302 Inspection Date: Tubing OA Packer Depth 510 2000 1960 1960IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220803203820 BBL Pumped:1 BBL Returned:1 Monday, August 29, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.29 15:38:40 -08'00' 2. 01 - 11 ' • • aaU-3o„)._ RECEIVED ConocoPhillips APR 0 6 2016 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 4, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 SCANNEV APR Anchorage, AK 99501 0 8 2016 Commissioner Cathy Foerster: 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 cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. No cement was pumped. The corrosion inhibitor/sealant was pumped March 25,2016 &March 28, 2016. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor 0 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 4/4/2016 1D-10,2N-302,2N-331, 2N-335,2N-243&2X-1 Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1D-10 50029228700000 1980490 11" NA 11" NA 4.00 3/25/2016 72N-302 50103203800000 i 2011150 10" NA 10" NA 5.90 3/25/2016 2N-331 50103202650000 1981170 20" NA 20" NA 10.00 3/28/2016 2N-335 50103202740000 1982040 23" NA 23" NA 15.50 3/28/2016 2N-343 50103202600000 1980920 26" NA 26" NA 15.50 3/25/2016 2X-01 50029209630000 1830840 25" NA 25" NA 9.00 3/25/2016 • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r- Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Conductor extension pi 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 201-115 3.Address: Stratigraphic r Service r' 6.API Number: P. 0. Box 100360, Anchorage,Alaska 99510 50-103-20380-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380053 KRU TARN 2N-302 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 10297 feet Plugs(measured) NA true vertical 5938 feet Junk(measured) NA Effective Depth measured 10157 feet Packer(measured) 9253 true vertical 5838 feet (true vertical) 5185 Casing Length Size MD TVD Burst Collapse CONDUCTOR 86 16 121 121' SURFACE 2854 10 2888 2298' PRODUCTION 10252 8 10283 5184' PROD LINER 1015 3.5 10282 5198' �` E EWED MAR 2 9 2016 Perforation depth: Measured depth: 9550-9584 True Vertical Depth: 5402-5426APR 2 1 2016 A OGCC ottimu Tubing(size,grade,MD,and TVD) 3.5, L-80, 9252 MD, 5185 TVD Packers&SSSV(type,MD,and TVD) NIPPLE-CAMCO DS NIPPLE @ 518 MD and 518 TVD SEAL ASSY-BAKER 80-40 SEAL ASSEMBLY @ 9253 MD and 5185 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ r WAG rd GINJ r SUSP r SPLUG r 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: 316-100 Contact MJ Loveland Email: n1878 conocophIIIIps.com Printed Name MJ Loveland Title: NSK Well Integrity Project Supervisor Signature Phone:659-7043 Date ��'v'P----" S—/W-44,/ Vrc. 4/12-l f, Form 10-404 Revised 5/2015 1/Z/�fj RBDMS L- MAR 31 2016 Submit Original Only • • ConocoPh i l l i ps Alaska RECEIVED P.O. BOX 100360 MAR 2 9 2016 ANCHORAGE,ALASKA 99510-0360 AOGCC March 25, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Sundry for ConocoPhillips Alaska, Inc. well 2N-302, PTD 201-115, Sundry#316-100 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, AO/ / MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • 2N-302 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/10/16 Prep and weld 10" long extension on conductor made with 16" .375 wall pipe. • is ' "N, r.-,•,..,:',1,,.'1, , ,,''' ',IV 'ii.,: , ' e ' a. , •a 3 i F T S '4 �v �e '`'4/444-/"1/4 '''',t:V`.4. ''/`/44,‘ 4, '., ' '. ',.'F 4 meg lfi 9 filer4 l K x v "Y 1 a � fi • 'Vt.)i't....7"`", -.1 ----, r. i 2N-302 PTD 201-115 � ��' "Copyright 2016 All rights reserved. This photograph is provided to the 7#,:, jiiiiiAjziki.i, -:.4 AOGCC with permission to copy for its '` � own use. Copying for any other ,1 4,4 ,,,,„„.,,,4,.„":„ ,, .,t#4...4,S.4, i4" .4:1F..0 g.,,, 4440!iitrNi* 14,1* ti� `� purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc." ; x , + " .; •• • �� -:',P,"..41. r?rte •,;40 w MP — a a : � . ,. 'n T � ,�+ ,; ^ 'sa r A _ 4 ,fig,x mow, a k, ° "' y t ''''''''''''%, '•^,xx,��-g 0,_i NF`s`+ � ; his :4:"''':'c . i*: '''' - -. l* ; E :FA - .. .5f' YY '• s ' 1,OF T4 • y\��y/,�s� THE STATE Alaska Oil and Gas ti , o ® Conservation Commission ., f1ZLA s <�A � > }E2 �� 333 West Seventh Avenue ' %� 1' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "� Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. SWIM 17F-ii t ' 4 lilb P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU Tarn 2N-302 Permit to Drill Number: 201-115 Sundry Number: 316-100 Dear Ms. Loveland: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, P941L„,k Cathy P Foerster Chair' DATED this �L day of February, 2016. RBDMS Lt- FEB 1 1 2016 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 5 2016 APPLICATION FOR SUNDRY APPROVALS A�(a :„�b7 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Plug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing F . Other: Conductor extension F- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory r Development r 201-115 , 3.Address: Stratigraphic r Service r . 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20380-00. 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No Jr ✓ KRU TARN 2N-302 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0380053 , Kuparuk River Field/Tarn Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10297 " 5938 • 10157' - 5838' 3400' NA NA Casing Length Size MD TVD Burst Collapse CONDUCTOR 86 16 121' 121' SURFACE 2854 7 5/8 2888' 2298' PRODUCTION 9232 51/2 9267' 5184' PROD LINER 1015 3 1/2 10282' 5198' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9550-9584 \ 5402-5426 3.5 L-809252 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NIPPLE-CAMCO DS NIPPLE ' MD=518 TVD=518 SEAL ASSY-BAKER 80-40 SEAL ASSEMBLY • MD=9253 TVD=5185 12.Attachments: Proposal Summary r WellBore Schematic j,� 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: 02/25/16 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG F GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: MJ Loveland Printed Name MJ Loveland Phone:659-7043 Email: n1878@conocophillips.com / Title: NSK Well Integrity Project Supervisor Signature ' i��1 / �J ..,.,...V3//1(., / Commission Use Only Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\Ct — \00 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: phof-o doe er-Y,rv) 5vla51c1ncec avid re/04i1, Post Initial Injection MIT Req'd? Yes r No V /r, Spacing Exception Required? Yes r No 17/ `'1-" Subsequent Form Required: j D — 40 APPROVED BY Approved by: P' / �(.� COMMISSIOQN�E}R THE COMMISSION Date: 2--/0- (� ATL z i i i i6 • A alp° Submit Form and Form 10-403 Revised 11/2015 ORo1eG1i14A4ii for 12 months from the date of approval. RB,gtM ents in D l'cate1 1 2016 • • • • ConocoPhillips RECEIVED Alaska P.O. BOX 100360 FEB 0 5 2016 ANCHORAGE,ALASKA 99510-0360 AOGCC February 3, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2N-302, PTD 201-115 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor . 0 ConocoPhillips Alaska, Inc. Kuparuk Well 2N-302 (PTD 201-115) SUNDRY NOTICE 10-403 APPROVAL REQUEST 02-03-16 This application for Sundry approval for Kuparuk well 2N-302 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 10". ✓ With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage if it is exposed. 3. Extend the conductor to starter head. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor 11) KUP INJ 2N-302 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,I71C. Wellbore API/UW1 Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Cun[r -ir{n 501032038000 TARN PARTICIPATING AREA INJ 67.18 3,081.96 10,297.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 2N-302,9/22/2014 3:52:55 PM SSSV:NIPPLE Last WO: 40.64 9/2/2001 Vertical schematic(actual Annotation Depth(ttKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,530.0 9/20/2014 Rev Reason:TAG hipshkt 9/22/2014 In-! �I! Casing Strings lli HANGER,28 8 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I Grade Top Thread CONDUCTOR 16 15.062 35.0 121.0 121 0 6258 H 40 WELDED '. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread .4 nom.} . SURFACE 75/8 6.875 34.3 2,888.4 2,298.4 29.70 L-80 BTC-MOD I. j Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION55"o35" 51/2 4.950 31.0 10,282.8 5,927.5 15.50 L-80 BTCM 1 1 @ 9268 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 28.8 9,269.7 5197.8 9.30 L-80 EUE8RDMOD I g Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 28.8 28.8 0.23 HANGER FMC GEN V TUBING HANGER 3.500 .... " .' .. I, U . AWL 518.3 517.8 5.26 NIPPLE CAMCO DS NIPPLE 2.812 9,244.9 5,179.8' 43.53 NIPPLE CAMCO D NIPPLE 2.750 9,251.9 5,184.8 4339 LOCATOR BAKER NO GO LOCATOR 3.000 ,Mi CONDUCTOR;35.0-727.0 .w� 9,252.7 5,185.5 43.37 SEAL ASSY BAKER 80 0 SEAL ASSEMBLY 3.000 IPerforations&Slots eTe NIPPLE;518.3 lib Shot I Gens Top(ND) Btm(ND) Inhabit Top(ftKB) Elm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 9,550.0 9,564.0 5,401.8 5,411.9 S-5,S-3,2N- 9/2/2001 6.0 IPERF 2.5"HC,DP Chgs,60 302 deg ph 9,564.0 9,584.0 5,411.9 5,426.3 S-3,T-2,2N- 9/1/2001 6.0 IPERF 2.5"HC,DP Chgs,60 302 deg ph GAS LIFT;2,317.2 4 Mandrel Inserts I ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Berm Type Type (in) (psi) Run Date Com 1' 2,317.2 2,044.0 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 7/12/2001 9 2 9,201.3 5,148.4 CAMCO KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 8/24/2001 9 Notes:General&Safety End Date Annotation 11/19/2010 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE;34.3-2,888.4 GAS LIFT;9,201.3 NIPPLE;9,244.9 LOCATOR;9251.9 -, SEAL ASSY;9,252.7 ■ ' IPERF;9,550.0-9,564.0 - I PERF;9,564.0-9,584.0 .- PRODUCTION 5.Sz3.5'rdi 9268;31.0-10,282.8 Imag( ~roject Well History' File Cover~ .ge 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. ~ ~) ~_- ~ ~_~_ Well History File Identifier DIGITAL DATA OVERSIZED (Scannable) Color items: ~~skettes, No. ~ [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: [] Other: OVERSIZED (Non-Scannable) NOTES: [] Logs of various kinds [] Other BY: BEVERLY~INCENT SHERYL MARIA WINDY Project Proofing BY: BEVERLY,. OBIN~.~INCENT SHERYL MARIA WINDY Scanning Preparation ~-~ x 30 = ' ~ ("") + TOTAL PAGES BY: BEVERLY~NCENT SHERYL MARIA WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: BY: Stage 2 BY; PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ? YES E~EVER~VINcENT SHERYL MARIA WINDY DA TE.~).-,~_.~$/~,,,~... IF NO IN STAGE 1 , PAGE(S) DISCREPANCIES WERE FOUND: YES (SCANNING IS coMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNED B~': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd Regg, James B (DOA) • Page 1 of 1 From: Phillips, Jim (ASRC Energy Services) [Jim.Phillips@contractor.conocophillips.com] Sent: Wednesday, August 25, 2010 3:57 PM .~~~~G~i~'~~~ ~~ ~' - its To: Regg, James B (DOA) "j Subject: RE: State MITIA test results for 2N pad on 8/24/10 iC,ei,,l Zti-?~ ~ Follow Up Flag: Follow up Flag Status: Red Attachments: MIT KRU 2N Pad DRAFT.xIs Jim, I apologize for the mix up I am filling in for Brent this week and by mistake I did not double check the form before sending it off. Therefore I did not notice that it was showing 12 water injectors SI. I have attached the correct copy and again I am sorry about this mistake on my part. If you have any more questions please feel free to contact me. Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659-7224 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, August 25, 2010 2:36 PM To: Phillips, Jim (ASRC Energy Services) Subject: RE: State MITIA test results for 2N pad on 8/24/10 Why were all the wells SI except the gas injector? Jim Re99 `~' ~+:~]t~a~ ;G I,;~ ._ (1 ~(~'=~ AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Phillips, Jim (ASRC Energy Services) [mailto:Jim.Phillips@contractor.conocophillips.com] Sent: Wednesday, August 25, 2010 8:57 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: State MITIA test results for 2N pad on 8/24/10 All, Attached is the MITIA tests for 2N pad that were waived by Chuck Shieve on 08/24/10. Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659-7224 8/26/2010 Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder~alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: ConocoPhillipsAlaska Inc. ~ Gry ~L-,~ I" FIELD /UNIT /PAD: Kuparuk /KRU / 2N ~ ~~ DATE: 08/24/10 OPERATOR REP: Ives/Mouser AES AOGCC REP: • Packer De th Pretest Initial 15 Min. 30 Min. Well 2N-302 T e In'. W ND 5,185' Tubin 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2011150 T etest P Test si 1500 Casin 1,210 2,540 2,520 2,520 P/F P Notes: OA 235 265 260 260 Well 2N-306 T e In'. W ND 5,174' Tubin 2,150 2,150 2,150 2,150 Interval 4 P.T.D. 2040620 T etest P Test si 1500 Casin 1,245 2,820 2,760 2,760 P/F P Notes: OA 375 550 520 520 Well 2N-307 T e In'. W ND 5,141' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 1990170 T etest P Test si 1500 Casin 810 2,180 2,150 2,150 P/F P Notes: OA 250 350 300 300 Well 2N-309 T e In'. W ND 5,042' Tubin 1,600 1,600 1,600 1,600 Interval 4 P.T.D. 1990210 T etest P Test si 1500 Casin 775 2,225 2,100 2,080 P/F P Notes: OA 300 365 340 340 Well 2N-310 T e In'. W ND 5,004' Tubin 1,550 1,550 1,550 1,550 Interval 4 P.T.D. 2070900 T e test P Test si 1500 Casin 440 2,300 2,250 2,250 P/F P Notes: OA 270 390 350 350 Well 2N-314 T e In'. W ND 5,046' Tubin 1,600 1,600 1,600 1,600 Interval 4 P.T.D. 2001930 T e test P Test si 1500 Casin 600 2,300 2,270 2,270 P/F P Notes: OA 225 240 240 240 Well 2N-321A T e In'. W ND 4,915' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 1981730 T e test P Test si 1500 Casin 575 2,280 2,250 2,250 P/F P Notes: OA 250 450 450 450 Well 2N-326 T e In'. W ND 4,821' Tubin 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2001550 T etest P Test si 1500 Casin 1,150 2,760 2,720 2,710 P/F P Notes: OA 360 460 460 460 Well 2N-331 T e In'. W ND 4,770' Tubin 1,460 1,460 1,460 1,460 Interval 4 P.T.D. 1981170 T etest P Test si 1500 Casin 460 2,200 2,150 2,150 P/F P Notes: OA 300 480 480 480 Well 2N-335 T e In'. W ND 4,966' Tubin 1,950 1,950 1,950 1,950 Interval 4 P.T.D. 1982040 T e test P Test si 1500 Casin 560 2,800 2,600 2,590 P/F P Notes: OA 200 430 430 430 Well 2N-343 T e In'. G TVD 4,937' Tubin 3,350 3,350 3,350 3,350 Interval 4 P.T.D. 1980920 T e test P Test si 1500 Casin 850 2,780 2,630 2,620 P/F P Notes: OA 400 420 420 420 Well 2N-348 T e In'. W TVD 4,374' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 2011420 T e test P Test si 1500 Casin 630 2,280 2,240 2,240 P/F P Notes: OA 190 320 320 320 Well 2N-349A T e In'. G ND 5,078' Tubin 1,625 1,625 1,625 1,625 Interval 4 P.T.D. 2001390 T e test P Test si 1500 Casin 280 2,320 2,250 2,250 P/F P Notes: OA 150 250 250 250 Well 2N-325 T e In'. W ND 5015' Tubin 1,975 1,975 1,975 1,975 Interval 4 P.T.D. 1981630 T e test P Test si 1500 Casin 750 2,675 2,630 2,630 P/F P Notes: OA 220 250 240 240 TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Intemal 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 O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2N Pad 08-24-10 Revisedl.xls ~~\ ~, / ~; 01 /08/09 Schlumberger -DCS , 2525 Gambell Street, Suite 400 .9_ l . ~ . ,-, ,- ~,~,., Anchorage, AK 99503-2838 : -. ~ ~, ~..~. - ~~ ~~ I ~~ ~' ~' ~ L~ ~ ~-' ATTN: Beth Well Job # Log Description NO.5035 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD C~ J u Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • ConocoPhiliips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~~~~ N0~ 0 ~ 2007 ~~'~~ ~~ Enclosed please find a (revised 10/3/07)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 inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. This spreadsheet is a revised format for the original submitted on 9!28107 Please call myself at 907-659-7506, or M.J. Loveland at 659-7043 if you have any questions. Sincerely, on Arend ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 9/28/2007 Well Name PTD # Initial top of cement Vol, of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2L-303 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9!16/2007 2L-309 205-210 13' 3" 2 18" 9!9!2007 7.5 9!16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 20" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9!9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n!a 4.5 9/27!2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" nia 9" n/a 2 9/27/2007 2N-311 206-179 12" n/a 12" n/a 10 9/27/2007 2N-313 198-091 18" n/a 18" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n/a 6" n/a 3 9/27(2007 2N-317 198-143 5" n/a 5" n/a 1 9/27{2007 2N-318 200-100 10" n/a 10" n/a 1 9/27!2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 ConocoPhillips a P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~~ NO~~ tl ~ Zti1~i R~C~ oar lV,FQ A/eska DiJ,~ Ga ~ 2 ?Opp A~~~a ~~~ e°mm%ss~ On _.- ~~ ~ _ ~ ~.~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi~. Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself at 907-659-7043, if you have any questions. Sincerely, ~i' M.J. vel d ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 9/28/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2L-i03 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/1612007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 9" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9!9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9/27!2007 2N-304 201-130 10" n!a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n!a 7.5 9!2712007 2N-307 199-017 14" n!a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" nia 2 9!2712007 2N-311 206-179 12" n/a 12" Na 10 9/27/2007 2N-313 19&091 5" n/a 5" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 19&190 6" n/a 6" n/a 3 9/27/2007 2N-317 19&143 5" n!a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/27!2007 2N-319 19&197 5" n/a 5" n/a 9.5 9/27/2007 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ?ÞŽ)I!i/,GC '[--tit DA TE: Wednesday, August 09, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2N-302 KUPARUK RIV U TARN 2N-302 .).0\' \ \~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: '-w--- P.I. Suprv )~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U TARN 2N-302 API Well Number 50-103-20380-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060808184637 Permit Number: 201-115-0 Inspection Date: 8/8/2006 Rellnsp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I ' '--' I . I I I -.- Well 2N-302 ¡Type loj. I G I TVD 5186 IA 890 1850 1840 1840 I I I I I I ITypeTest ¡ SPT : Test psi I --. P.T. i 2011150 1500 i OA I 170 i 200 I 200 200 I __-....L__~~ I , 4YRTST Tubing I 3160 3160 I 3160 I 3160 I Interval PIF p i , Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. SCANNED AUG 2 4 ZGD6 Wednesday, August 09, 2006 Page 1 of 1 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to Drill 2011150 DATA SUBMITTAL COMPLIANCE REPORT 101312003 Well Name/No. KUPARUK RIV U TARN 2N-302 Operator CONOCOPHILLIPS ALASKA INC MD 10279 ,/ TVD 5938 ~-- Completion Date 9/2/2001 ~' Completion Status 1WINJ Current Status WAGIN APl No. 50-'103-20380-00-00 UIC Y REQUIRED INFORMATION Mud Log N._9o Samples N._9o Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Log Log Run Interval OH ! Type Med/Frmt Nu~er Name Scale Media No Start Stop CH Received Comments ,-E-'~'"- C Lis 10463 Por%i!y..ii..::.:~.'.!:.:.'..:.;'.i.:~'.'!~..i'~ final 155 10297 Case 11/13/2001 F.,D"'~C Lis ,..1,0463 '~'~iii~:i~iii::i:i::~:.'i::iii~::~/~:i:::i::iii??i::;:!.::i:iiii!~ final 155 10297 Case 1111312001 <ED~" :?:::i~.ii:i.:!~i:!:?::!.i!i!:?i??!!:?i!::!:!!i!:i'i~.:?:ii!:::::i:~::ii?i.i: Bh'e'E[iOnalSurvey FINAL Case 8/2/2001 R.~-"'"" ?~!~ii!;::i~::ii~ii~:iii;:i!:~?~!i~::?!i!i~:~;ii~i~i:~:ii~i~i:;:;~i:!?:~ii!!i:ii~;!:~?ii~i~!i~::i:i!~?i!~i Directional Survey FINAL Case 8/2/2001 Log ..- ':~!:.'~!i'!i;!i"i':.; ;;.;i ?!:!:. ::::':i';'::;~':i:i':!i!::' ; :?:i?.' ~.::'i::'::::..'::::'.:i'. SBHP Survey 5 FINAL 9396 9592 Rpt .~..!:~i:i: i;'i~.' !:': :'.i '!!! ~:i ;';?' i!.: :.!;i ;i. ';; .:; i.i.: !!.' i' ::;::'. LIS Verification FINAL IIFR Survey, Digital Data Directional Survey, Paper Copy Case 8/2/2001 Directional Survey Digital Data Case 8/2/2001 Directional Survey Paper Copy Case 10/4/2001 9396-9592 BL, Sepia Open 10/16/2001 2841-10233 Digital Data Open 10/16/2001 LIS Verification paper copy Well Cores/Samples Information: Interval Name Start Stop Sent Received Sample Set Number Comments Permit to Drill 2011150 DATA SUBMITTAL COMPLIANCE REPORT 101312003 Well Name/No. KUPARUK RIV U TARN 2N-302 Operator CONOCOPHILLIPS ALASKA INC MD 10279 TVD 5938 ADDITIONAL INFORMATION Well Cored? Y/N~ Chips Received? Analysis Received? Completion Date 9/2/2001 Completion Status 1WINJ Current Status WAGIN Daily History Received? ~ / N Formation Tops (~ N APl No. 50-103-20380-00-00 UIC Y Comments: Compliance Reviewed By: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor C°` DATE: January 10, 2002 Chair ._{ SUBJECT: Mechanical Integrity Tests THRU' Tom Maunder ['%~ i.~~ PAl P.I. Supervisor ~ 2N 2N-302, 2N-348 FROM: John H. Spaulding KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellJ 2N-302 ITypelnj. G ] T.V.D. 15186 I Tubingl 2565 I 2560. [2560'[2560 llntervall I P.T.D.I 2011150 ITypetestl S' ITestpsil 1297 ICasing] 1653I 3083[ 3073I 3067I P/F I P Notes: Initial MIT, conversion from producer WellI 2N-34S ]Type,nj.I G I T.V.D. I 4377 I Tubing 13200 [ 3200 I 3175 I 3225 I lntervall I P.T.D.I 2011420 [TypetestI P ITestpsil 1094 ICasingI 2284I 1519I 1527I 1531 I P/F I -P... Notes: Initial MIT: draw down due to high initial IA pressures WellI 2M-35 I Type,nj.I s I T.V.D. (6192 I Tubing 12205 I 2205 12205 12205 [Interval I P.T.D.I 1960800 Type testl P I Testpsil 1548 [CasingI 1025 I 1625 I 1625 I 1625I P/F I P Notes: P.T.D. Notes: P.T.D.[ Notes: 183096 Type testI .. P I Testpsil 1439 ICasingI 1000I 2420I 2350'I 2310I P/F I -P I Type ,nj. I I T.V.D. I I Tubing I I [ '[ I lntervall Type test] ITest pail I Casing J . . I I '1 . I P/F I ,,--.J 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 Valiance W= Test during Workover O= Other (describe in notes) Test's Details Well 2C-07 failed a previous MIT-reported to the AOGCC. MITT with bridge plug set in the tubing @ 6165'. Presurred up the tubing and the IA and held for 3.5 hours. The sharp increase in psi from 2600 psi to 2875 psi was due to a guage change. PAI will be filing a Sundry for continued operations. All other wells noted above passed their respective MIT's and are in comploiance with area injection orders. M.I.T.'s performed: _4 Attachments: none Number of Failures: 0 Total Time during tests: _5 cc: none MIT report form 5/12/00 L.G. MIT KRU cpf-2 1-10-02js.xls 3/7/02 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: , 2. I~lame of Operator Operation shutdown_ Pull' tubi.nQ _ Alaska, Inc. 3. Address P. O. Box 100360 Anchora~le, AK 99510-0360 Slimulate _ 5. Type of Well: Devetapment Exploratory Slrafigmphic Sewice~X 4. Location of well at surface 5272' FNL, 483' FEL, Sec. 34, T10N, R7E, UM .At top of productive intewal 1096' FSL, 2628' FEL, Sec. 26, T10N, R7E, UM .At effective depth (asp's 461108, 5912011) At total depth 3638' FNL, 2390' FEL, Sec; 26, T10N, R7E, UM (asp's 464506, 5918908) Plugging _ Perforate _ Repair,w~,,,_ CNh..er _X WINJ tp W.A~. · 6. Datum elevation (DF or KB feet) RKB 154 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2N-302 9. Permit number / approval number 201-115/ 10. APl number 50-103-20380 11. Field / Pool Tam Oil Pool 12. Present well condition summary Total depth: measured true vertical 10297 5938 feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet Casing Length Size CONDUCTOR 121' 16" SURFACE 2734' 7-5/8" PRODUCTION 9113' 5-1/2" LINER 1016' 3-1/2" LINER Cemented Measured Depth True vertical Depth 9S0sxASl 121' 121' 300 sx AS Lite & 240 sx Class G 2888' 2298' 80 sx Class G & 240 sx CL G Gas 9267' 5196' included above 10283' 5928' Perforation depth: (size, grade, and measured depth) Packers & SSSV (type & measured depth) true vertical S402:~t2;.54,-:i2-~26;; .'... '.:. ;" ::;'.','"' ' ...' "" -' ....... "'"' ':':'": ' ..... " '": ':::..' '"". ' "'"" ':::i.'i ': '.::'":'.:': .... .'; .... .'..'. · ..... ' " '. '.. ".:'":': i:~i.i.:i :". :' . . ':: .'. 3:Ii~;'9.3#,L~80'~.'O'9~"I~tI:):: '.:::':.'-'"':' ' ' " ..... ;'"': :'"' ":': '" ' ..... ' .......... ' .......... ~'::"" '"' :~.'M ; .:.:'..":"..: . :..:"........ ::....': '.'..:..."' . · '. ". '......' ....... :~0 I DS' '~ m ~m~ ~m ~. :..:' I.. :il :m m :m re:m: .:'i:~ .... mm m ~ I m m : : . ;Il :m ::m.:m:~ : ~ ~ ~:~=.., :: ..::.: ;.:. ;: ~ m :,m ~m:m: ' ~:::. I II Ii m :millI mmmmml Im ::: ~,: . i.~. ' ': ,1~1'~11 i'~1~;- .'" ':: i'i"".i '"' i ":": - -' ......... i" lilt'? I1' ' I I "":: '"'"'~" ' ...... '. · · '' : '. :'' '."".'.: ".::. , r:.. .s '.' .'.,'"..' ... ,...:.; ...,, , ,: .-.. ~:, · .. ........... '.::...;;:,t.' . ; .,..:~L.,.. ,',.:..' . 13. Stimulation or cement squeeze summary Intervals treated (measured) '..' · ' ...... :' ":.'i: '.' .' ': :"~A'" :.: ' ':' !:!::'-: Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation · '. · ...... 15. ,Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Representative Daily Average Production or Injection Data. Gas-Md Water-Bbl Casing Pressure Tubing Pressure · .... ::. . ..'. :':~ · .. .. · . .....: .... 'i;. ':' ': ':'.!'.::~'"' :' :'.". '. · ... :.':':' · . . ....... · .. ".. :..'.: .:L':. '~'.::: '::."::..':.: · .. · · -.;3919: . . ......... ...: ..:' '.i.": :.".249' ". :,'.:.::..',.':i:'!::: i'. ii · ii ii i. i i i i .... i '1 · ii i · i ; : · . ': , : · · . · .. .... ~,, ....., .........,. ...... i '. ::.,.:.. 'Oil.:':;:."::': .... · .Gas~_' 'SoSpend~l..'. :...?." .'.'.:.:~n~i~::.x'.wJA~:lnje~;ior.'::.::'i:....:. · '..:..:' .... ii' '" 'f''" ': "~ .... , ' '.. ' ::. '. :;'L .; : '. '... '."7'-~' '.'.' :. :' "· ': ':':: · :: ,' ' "," ~ · · -' ",', ::",~" ·. '~' ~ ,, ':, '~'< "" '. '::....;...: '. ' .": :: BFL Questions? Call Jeff Spencer 659-7226 Prepared b. ~/ Robe~ Chdstensen 65~ 7535 APR 12002 ~ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 2N-302 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary "11/21/2001jcomme.nC.ed,WA..G.EOR Inj.,ection i..' ' ' _ ! WELL LOG TRANSMITTAL To: State of Alaska October 12, 2001 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2N-302, AK-MM-II101 The technical data listed below is being sub~*t~ed herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2N-302: Digital Log Images 1 CD Rom RECEIVED NOV 1 3 2001 OiJ & Gas Cor~$, Co~lBsior~ 10/24/2001 Sch berger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1566 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color lC-117~,~O J.-/,,~ I 21439 USIT 10/06/01 1 1C-119 ~,~0)-1~ 21438 .SCMT ~', 09/20/01 1 2K-27 ~.-.~01~/~ 21440 jscum v,/ 10/03/01 1 2N-302~01_11s 21437 JSCUm V/ 09/01/01 I SIGNED:~ ~ DATE: RECEIVED OCT 50 2001 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317./~l~t~&'Gas Cons. Commi~sior, A~chorage 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 October 11, 2001 RE: MWD Formation Evaluation Logs 2N-302, AK-MM-11101 1 LDWG formatted Disc with verification listing. API#: 50-103-20380-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: RECEIVED OCT 1 6 2001 Alaska Oil & Gas Cons. Commi~ior, ,Anchorage Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1505 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color 1F-18 //~3 -/,,-~ PRODUCTION PROFILE 08119/01 1 1 1G-'16 /(~7~- ! 5~ INJECTION PROFILE 0910310'1 1 1 1R-08 /~ -' ~'~ INJECTION PROFILE 09103/0'1 2M-26 /~oh. '(~ INJECTION PROFILE 081'19101 2M-31 //C~ ~.,-O"77 INJECTION PROFILE 08131101 '1 t 2N-302 ~O~- ~ ,~ SBHP SURVEY 09/02/0t 2T-18 / C:~.~-~'..--O I~ INJECTION PROFILE 09/08101 2W-09 I ~'°~ ~ C~ INJECTION PROFILE 09105101 1 1 3M-24 j~ ~--.1~5 PRESSURE SURVEY 09104101 1 10/412001 DATE: RECEIVED Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. OCT 0 4 2001 Alaska 0il & Gas Cons. Commission STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ~] Gas r-~ suspended r~ Abandoned [~ Service [~]~ Water Injector 2. Name of Operator '~~ 7. Permit Number Phillips Alaska, Inc. ~:IiL"IFI'~D 201-115 / 301-179 3. Address ,~3~.__, 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360.~.~F 50-103-20380-00 · - -~,~ .... .'.~ ..-..7-~ 9. Unit or Lease Name 4. Location o! well at surface ~ ':'~ '~": ~:.~" ! Kuparuk River Unit 4' FSL, 485' FEL, Sec. 34, T10N, R7E, UM (ASP:461108, 5912011) At Top Producing Interval i ~? ......... 10. Well Number 1135' ESL, 2607' FEE, Sec. 26, T10N, R7E, UM (ASP: 464290, 5918405) -- ' 2N-302 At Total Depth { ~~; i; 11. Field and Pool 1639.5' FSL, 2392.5' FEL, Sec. 26 T10N R7E UM (ASP' 464506 5918908) ~ :~,T., Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Tarn River Pool RKB 34' feetI ADL 380053 ALK 4601 12. Date Spuddedjune 28, 2001 13. Date T.D.JulyReached9, 2001 14. Date Comp.,. h ~lv 1~.,~.4~ ~- - r~ 'Susp' Or Aband. 2/ ~Z) Ill 5.N/AWater Depth, feetif OffshOreMSL 16. No. o! Completions1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Surveyv 120. Depth where SSSV set 21. Thickness of Permafrost 10297' M D / 5938' 'I'VD 10157' MD / 5838' TVD YES r~ No DI N/A feet MD 1 2 1 7' (approx) 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 RECORD AMOUNT PULLED 16" 65.5# H-40 Surface 121' 24" 300 sx AS I 7.625" 29.7# L-80 Surface 2888' 9.875" 376 sx AS Lite, 240 sx Class G 5.5" 15.5# L-80 Surface 9267' 6.75" 60 sx Class G & 402 sx Class G 3.5" 9.3# L-80 9267' 10282' 6.75" included above 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9270' 9248' (CSR) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9550' - 9584' MD 5402' - 5426' TVD 6 spt DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST I 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 I GAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') 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 Alaska Oil & Gas Cons. Comrnissio~ Anchorage Form 10-407 Rev. 7-1-80 Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T3.1 9378' 5277' T-3 9430' 5315' T-2 9590' 5431' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. Ih,~y ce~"~a,~he follow~n~ls~and correct to the best of my knowledge. Questions? Brian Noel 265-6979 SignedV, ~C. M~Jry. {~/~j~~ ~j. ~.~/ j]~'~/~t~ Title Driln,qEn.qineerin,qSupervisor Date y/~. '~ ..~ 7~~_ "~_ / _ Prepared by Sharon AIIsup-Dralce 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 I PHILLIPS ALASKA INC. Page I of 8 i Operations Summary Report Legal Well Name: 2N-302 Common Well Name: 2N-302 Spud Date: 6/28/2001 Event Name: ROT- DRILLING Start: 6/15/2001 End'. Contractor Name: Nabors Rig Release: Group: Rig Name: Nabors 16E Rig Number: 16E Sub Phase Description of Operations Date From - To Hours Code Code 6/13/2001 12:00 - 19:00 7.00 MOVE DMOB DEMOB Clear & clean rig floor, Blow down all lines, Prepair floor for skiding, Cattle shute for removal, Pits to moved 19:00 - 00:00 5.00 MOVE DMOB DEMOB Remove Cattle shute, Skid rig floor over rig, Move pits, Pick up matts & position for moving, Move rockover tank to Q Pad, Move Ball Mill to 2L Pad, Move sub off of hole, remove matts, Remove diverter out of cellar 6/14/2001 00:00 - 08:30 8.50 MOVE DMOB !MOBMIR Position Sub, Remove BOP's & Place on stand, Install rear booster wheel assembly, Load misc. rig equip, into pipeshed, complete misc. tasks for rig move 08:30 - 00:00 15.50 MOVE MOVE i MOBMIR Begin 31.4 mile rig move f/3K Pad to 2N Pad at 1/2 M PH 6/15/2001 00:00 - 05:00 5.00 MOVE MOB MOBMIR i Moving Sub & Motor modules to f/3K to 2N Pad 05:00 - 09:00 4.00 MOVE MOB MOBMIR i Right rear wheel of Motor module off road & stuck (By 2C Pad), Free same 09:00 - 00:00 15.00 MOVE MOB 'MOBMIR Moving Sub & Motor modules to f/3K to 2N Pad, Note; Road getting softer after four corners past CPF-2 6/16/2001 00:00 - 02:30 2.50 MOVE MOVE MOBMIR . Moving Sub & Motor modules, Between 4-Cornes & 2M Pad, Motor module which was behind Sub module Fell thru when a culvert gave way, Move Sub module to 2M Pad 02:30 - 10:30 8.00 MOVE MOB MOBMIR Motor module stuck, Filling holes with dunnage & plywood, Call out 4 Cat's & Welder, cut out matts blocking wheels 10:30 - 19:00 8.50 MOVE MOVE MOBMIR Move Motor module back to 4-Corners so Roads & Pads can repair road 19:00 - 00:00 5.00 MOVE MOVE MOBMIR Remove dunnage & plywood from hole, Repair road 6/17/2001 00:00 - 10:00 10.00 MOVE MOVE MOBMIR Repair Road while Sub module at 2M Pad and Motor module at 4- Corners, Set matts & plywood on road and culverts f/4- Corners to 2M Pad 10:00 - 18:00 8.00 MOVE MOVE MOBMIR Move motor module to 2M Pad next to Sub module- OK 18:00 - 00:00 6.00 MOVE MOVE MOBMIR Service rig moving systems, Move & set all matts & plywood ahead of rig on road, culverts and bridges, Stage 2 cats ahead of rig 6/18/2001 00:00 - 01:00 1.00 MOVE MOVE MOBMIR Lay matts & plywood from 2M Pad to pullout 2 miles down the road 01:00 - 05:00 4.00 MOVE MOVE MOBMIR Move Sub module to pullout-Note; Road cracking & showing signs of deterioration after Sub module travels road 05:00 - 14:00 9.00 MOVE MOVE MOBMIR Move matts & plywood to deteriorated sections of road, Wait on tool house crew change & more matts from Deadhorse 14:00 - 19:00 5.00 MOVE MOVE MOBMIR Move motor module to pullout next to Sub module- Road blew out twice 19:00 - 00:00 5.00 MOVE MOVE MOBMIR Move matts & plywood from pullout to 2L Pad 6/19/2001 00:00 - 06:00 6.00 MOVE MOVE MOBMIR Sub & Power Modules are 2.5 miles past 2M pad going towards 2N pad, laying mats and boards as needed and across all conduits. 06:00 - 07:30 1.50 MOVE MOVE MOBMIR Continued moving rig towards 2N pad. 07:30- 09:30 2.00 MOVE MOVE MOBMIR Power Module stuck, soft shoulder. 09:30- 20:00 10.50 MOVE MOVE MOBMIR Moved Sub & Utility/Power Modules to 4.3 miles past 2M pad. Over the past 4 hrs, we moved +/- 1/4 mile. The road is breaking out on both sides with the Utility Module. (( Both modules currently +/- 6 miles from 2N pad )). 20:00 - 00:00 4.00 MOVE MOVE MOBMIR Decided to focus on getting the Sub / Main Rig module to 2N and then come back and use all the boards & mats to get the Utility Module to 2N. 6/20/2001 00:00 - 02:00 2.00 MOVE MOVE MOBMIR Moved sub module across pipeline @ 2L pad. Fueled sub module. 02:00 - 04:00 2.00 MOVE MOVE MOBMIR Blew tire on APC on matting boards in front of sub module. Waited for new tire. 04:00 - 05:00 1.00 MOVE MOVE MOBMIR Moved sub module towards 2N pad. 05:00 - 07:30 2.50 MOVE MOVE MOBMIR Sub module stuck in soft shoulder @ =/- 7.2 miles from 2M pad. Laid plywood & timbers. 07:30 - 12:00 4.50 MOVE MOVE MOBMIR Moved sub module from mile 7.2 to 10, onto 2N pad. Printed: 7/27/2001 2:03:24 PM PHILLIPS ALASKA INC. Page 2 of 8 Operations Summa Report Legal Well Name: 2N-302 Common Well Name: 2N-302 Spud Date: 6/28/2001 Event Name: ROT - DRILLING Start: 6/15/2001 End: Contractor Name: Nabors Rig Release: Group: Rig Name: Nabors 16E Rig Number: 16E Sub Date From - To Hours Code Code Phase Description of Operations 6/20/2001 12:00 - 00:00 12.00 MOVE MOVE MOBMIR Moved power module f/mile 4 to mile 5 from 2M pad. Please NOTE: Rig went on non-standard rig move at 02:30 hrs 16 June when it fell into the culvert. The costs have been adjusted down on the $5000/mile rate and then the $36,000/day rate from that point applied. 6/21/2001 00:00 - 00:00 24.00 MOVE MOVE i MOBMIR Continued moving the utility module down the gravel road between 2M & 2L pads by leap frogging 92 mats (8 messed up so far). We are moving roughly 0.9 miles/24 hrs. We are still +/- 5 miles from 2N pad. 6/22/2001 00:00 - 00:00 24.00 MOVE MOVE MOBMIR Continued moving utility/power module from 5.8 marker to +/- 6.5 mile marker past 2M pad. Current moving rate +/- 1.2 miles/24 hrs. Once we get to 2L pad entrance, we have to let eqpt around us for other depts. In addition, roads & pads needs to fill in the big holes on the shoulder for the last 3 miles in order not to ruin additional mats. Rig will have to wait at 2L while this occurs. 6/23/2001 00:00 - 08:45 8.75 MOVE MOVE MOBMIR Moved utility/power module from 6.5 to 6.9 mi marker from 2M pad (3.1 mi f/2N pad). This put the module at the entrance to 2L pad, double boarded flowline crossing and coordinated with 2L DSLT and CPF-2, OK. 08:45 - 13:00 4.25 MOVE MOVE MOBMIR Let the eqpt that was needing to get to 2P pad thru (track hoe & roller). Let roads & pads thru to fill the holes in the shoulders between 2L and 2N pads and then waited for them to get back behind the module. 13:00 - 00:00 11.00 MOVE MOVE MOBMIR Continued moving utility module f/6.9 to 7.4 mi marker (+/- 2.5 mi from 2N pad). Still leap frogging mats. '6/24/2001 00:00 - 00:00 24.00 MOVE MOVE MOBMIR Continued moving utility module by leap frogging mats from mile marker 7.4 to 8.3. This leaves 1.6+ miles to go to 2N pad. Roads & pads continue to work on road from 2L to 2M, in preparation for camp move. 6/25/2001 00:00 - 00:00 24.00 MOVE MOVE MOBMIR Moved utility module from mile marker 8.3 to 9.4 (0.5+ miles to go). 6/26/2001 00:00 - 09:00 9.00 MOVE MOVE MOBMIR Finished moving utility/power module from mile marker 9.5 - 9.9+. Arrived at 2N pad, leap frogging mats. 09:00 - 13:00 4.00 MOVE RURD MOBMIR Moved sub module back so power module could get byt. Moved sub module up behind power module so grader could level pad area in front of conductor f/2N-302 (conductor triple chk'd, it is numbered correctly and has landing ring & 2 ports @ 45 deg). Removed front boogie wheel' f/sub module and mounted on left rear auxiliary axle. Drive pins out on rear boogie wheel. Removed matting boards f/road and moved them to 2L pad. Finished removing rear boogie wheel. 13:00 - 14:30 1.50 MOVE RURD MOBMIR Skidded rig floor out. 14:30 - 20:30 6.00 MOVE RURD MOBMIR Put BOP on stump, P/U surface hydril, put cattle chute in place & pin, R/D eqpt for skidding floor. R/D booster tire assy and put tires on sub. 20:30 - 00:00 3.50 MOVE POSN MOBMIR Put Herculite down for cellar & spotted sub module over 2N-302 !conductor. Moved power module over to sub & pinned same. 6/27/2001 00:00 - 02:30 2.50 MOVE POSN MOBMIR Spot power module & connect to sub module. Set mats. 02:30 - 07:00 4.50 MOVE RURD MOBMIR Hooked up service lines in stair tower & under rig floor, energized drawworks, enclosed cellar, build berm around cellar & between modules, start boiler & glycol pumps. 07:00 - 11:00 4.00 DRILL RIRD SURFAC I N/U surface diverter, start taking on water in pits @ 08:00 hrs. 11:00 - 15:30 4.50 DRILL RIRD SURFAC P/U pipe handler & attached to topdrive. P/U bails. 15:30 - 19:00 3.50 DRILL RIRD SURFAC Grease/service rig - derrick & crown inspection. Spotted cement silos & took on 1st Icad of cement. Installed injection line to 2N-318. Spotted satelite system in SW corner of pad. Printed: 7/27/2001 2:03:24 PM PHILLIPS ALASKA INC. Page 3 of 8 Operations Summa Report Legal Well Name: 2N-302 Common Well Name: 2N-302 Spud Date: 6/28/2001 Event Name: ROT - DRILLING Start: 6/15/2001 End: Contractor Name: Nabors Rig Release: Group: Rig Name: Nabors 16E Rig Number: 16E Sub Date From - To Hours Code Code Phase Description of Operations 6/27/2001 19:00 - 00:00 5.00 DRILL =ULD SURFAC P/U drillpipe and stand back in derrick. Please note that we have about 20-24' of clearance around the end of the rig and so pipe must be moved to pipe shed area by truck. During picking up of dp, moved ball mill into position from 2L pad after changing a tire & working on back-left wheel bearing. Held PRESPUD meeting for each tour during each tours safety meeting. 6/28/2001 00:00- 02:30 2.50 DRILL RIRD SURFAC Loaded 28 jts HWDP in pipe shed, level derrick, finished putting ~njection line together & testing & establishing injection rate w/diesel, OK. Got ball mill ready for spud and finished adding last section of diverter line & blocking back roadway around pad that goes by diverter line. P/U subs, crossovers & conducted pre-Spud walkaround. Pre-Spud refresher for tour. 02:30 - 04:00 1.50 DRILL PULD SURFAC P/U 28 jts of HWDP + jar + accelerator & stand in derrick. Mix mud. 04:00 - 05:00 1.00 DRILL TRIP SURFAC M/U UBHO sub and RIH on HWDP and tagged fill @ 134' (bottom of 16" conductor @ 151' RKB / 117' from pad level ). RKB = 34.33' 05:00 - 06:30 1.50 DRILL TRIP SURFAC Gyro survey @ 143' = 1.15 deg on 254 azimuth. POOH w/UBHO assy. 06:30 - 08:30 2.00 DRILL PULD SURFAC P/U BHA & changed bend in mud motor. 08:30 - 09:00 0.50 DRILL ClRC SURFAC Circ'd and checked diverter line, flowlines & shakers for any leaks, all OK. 09:00 - 18:30 9.50 DRILL DRLG SURFAC Cleaned out 17' in conductor. Drld new 9-7/8" hole f/151' - 677'. AST= 2.4 hrs ART=3.0 hrs 18:30 - 19:30 1.00 DRILL TRIP SURFAC Circ'd bottoms up & had a few feet of fill.., circ'd bottoms up again and less fill. Laid back 1 single and'conducted Gyro survey & flow checked while while gyroing. POOH on trip tank, OK. (The survey showed the azimuth coming back to the left when the motor was turned to 48 deg right. Projected to bottom and showed us getting close to 2N-303 but still outside hard lines. Spent quite a bit of time confirming with Sperry in town that things were OK. 19:30 - 22:00 2.50 DRILL ~ULD SURFAC Picked up MWD and lined up with UBHO. 22:00 - 23:00 1.00 DRILL TRIP SURFAC TIH & had bridge @ 463'. Washed thru bridge & cont'd TIH to TD. 23:00- 00:00 1.00 DRILL DRLG SURFAC Drld f/677' - 704'. AST=0.25 hrs ART=0 hrs. Still having to gyro survey as we are still getting magnetic interference from 2N-303 well. ( Once on bottom, turned motor 90 degrees right in order to hold angle and get more clearance from 2N-303 producer. We were ahead of plan on angle anyway & by holding angle...at this TVD the 2N-303 well was building 3-3.6 DLS and thus rapidly giving us more clearance. ) 6/29/2001 00:00 - 00:00 24.00 DRILL DRLG SURFAC Drld 9-7/8" hole f/704 - 2296'. AST=11.25 hrs & ART=9 hrs. 6/30/2001 00:00 - 06:30 6.50 DRILL DRLG SURFAC Drld 9-7/8" hole f/2296 - 2903', TD. ART=3 hrs & AST=2 hrs. 06:30- 08:00 1.50 DRILL ClRC SURFAC Circulated & pumped 2 hi-density sweeps around in stages. P/U and S/O wt cleaned up to 125k up & down. Rotated @ 80 rpm & worked pipe throughout. 08:00- 08:30 0.50 WELCTL OBSV SURFAC Flow chkd well, OK. Pumped slug (dry job). 08:30- 13:30 5.00 DRILL iTRIP SURFAC POOH slowlyto avoid any swabbing of formation. Hole looks good. 13:30- 16:00 2.50 DRILL PULD SURFAC L/D motor + mwd and directional eqpt. P/U hole opener & stabilizer. 16:00 - 18:00 2.00 DRILL TRIP SURFAC TIH with porcupine hole opener with stab +/- 30' up. Hole looked fine, ~ had one spot @ 1584' & cleaned up good. 18:00 - 20:30 2.50 DRILL ClRC SURFAC Staged circulation rate up to drilling gpm & rotating pipe. Got a lot of hole wipings across shaker initially and had to slow pumps down. Circ'd 2 hi density sweeps around and worked on mud rheology. Lowered vis some more and YP. Flow chkd well, OK. Pumped dry job. Printed: 7/27/2001 2:03:24 PM PHILLIPS A ,I~ASKA INC. Page 4 of 8 Operations Summa Report Legal Well Name: 2N-302 Common Well Name: 2N-302 Spud Date: 6/28/2001 Event Name: ROT- DRILLING Start: 6/15/2001 End: Contractor Name: Nabors Rig Release: Group: Rig Name: Nabors 16E Rig Number: 16E Sub Phase Description of OperatiOns Date From To Hours Code Code 6/30/2001 20:30 - 00:00 3.50 DRILL REAM SURFAC Started pulling the first stand and tending to swab with some drag (not slug settling). Decided to pump/rotate out due to the design of the porcupine hole opener (design is bad about swabbing). Hole looks good and no packing off tendencies at all. 7/1/2001 00:00 - 02:00 2.00 DRILL REAM SURFAC Finished reaming/washing out of hole. Hole looked OK and no packing off tendencies at all. 02:00 - 04:30 2.50 CASE RURD SURFAC Held PJSM, with special discussion concerning the fillup tool. This rig will us a safety clamp above the donut prior to laying it down. R/U casing running eqpt & fillup tool. 04:30 - 06:15 1.75 CASE RUNC SURFAC Ran 7-5/8" casing to 450', hit bridge in hole. 06:15- 09:15 3.00 CASE DRVJ SURFAC Worked thru bridge from 450-453'. Worked/slammed pipe onto bridge with pumps and using up to 50,000 lbs of TDS weight. All of a sudden worked thru bridge while preparing to POOH. 09:15 - 09:30 0.25 CASE RUNC SURFAC Ran 7-5/8" casing to 676' (16 jts) and hit another bridge. 09:30 - 12:30 3.00 CASE DRVJ SURFAC Worked on bridge and over 3 hrs was able to very slowly work the casing down from 676' - 691' (15 ft). Unable to break thru bridge. Decided to POOH w/casing. 12:30 - 13:30 1.00 CASE RURD SURFAC PJSM about pulling & laying down casing. R/D fill up tool and spider & P/U 150 ton side door. 13:30 - 17:30 4.00 CASE OTHR SURFAC Laid down jt 17, which was the last one made up and above rotary when we hit the 2nd bridge. Pulled and laid down 16 jts of 7-5/8" casing, including the float shoe and collar joints. No centralizers or stop collars were left in the hole. All of the centralizers that were below the conductor had large pieces of rock / coal under the blades. This makes them inflexible and rather rigid. 17:30- 19:00 1.50 CASE RURD SURFAC R/D casing running eqpt. 19:00 - 00:00 5.00 DRILL TRIP SURFAC Tripped in the hole w/new 9-7/8" hole opener. Precautionarily reamed 450' area. TIH to 618'. Washed/reamed f/618 - 836' using 10-30k weight and 300-450 gpm. TIH to 1950'. Had to clear with topdrive & 3umps. TIH to 2340'. Washed f/2246-2340'. TIH to 2653' & hit bridge. Washed to 2712' at midnight. 7/2/2001 00:00 - 00:30 0.50 DRILL REAM SURFAC TIH & reamed tight spot at 2340'. Finish TIH to bottom with no other 3roblems. 00:30 - 03:00 2.50 DRILL CIRC SURFAC Circ bottoms up and leet shakers clean up, no bottoms up gas. Pumped 2 separate hi density/vis sweeps. 03:00 - 06:30 3.50 DRILL TRIP SURFAC Flow checked well, static. Pumped slug & POOH to 368' (above any spots we had ever seen in this wellbore). Had tight spots that needed 'to be worked @ 1208-1275' & 1743' & 1870' & 1930' & 2060'. Worked them clean. 06:30 - 09:30 3.00 DRILL TRIP SURFAC TIH and had to work spots in the 1700 - 1950' area. POOH to 1500'.. no problems. Tripped back in the hole to TD and these spots were clear. 09:30- 12:30 3.00 DRILL CIRC SURFAC !Circ'd and conditioned mud. Pumped additonal 2 hi density/viscosity sweeps. Flow chkd well, static. Pumped slug. 12:30 - 17:00 4.50 DRILL TRIP SURFAC POOH and hole in good shape. Did not have to work any spots. L/D hole opener and stab. 17:00 - 20:00 3.00 CASE RURD SURFAC R/U fill up tool & casing running eqpt. Changed out short bails for long bails, to accomodate the fillup tool. 20:00 - 00:00 4.00 CASE RUNC SURFAC Ran 7-5/8" 29.7 ppf L-80 BTC Modified casing to 2673'. Had spots in the 1700-1900' interval, but did not need to work them. 7/3/2001 00:00 - 00:30 0.50 CASE RUNC SURFAC Finished running 66 jts + 2 pup joints of 7-5/8" 29.7 ppf L-80 BTC Mod casing. 00:30 - 01:15 0.75 CASE RUNC SURFAC M/U landing joint and land on landing ring, no fill. (13' of rathole). M/U Printed: 7/27/2001 2:03:24 PM PHILLIPS ALASKA INC. Page 5 of 8 Operations Summa Report Legal Well Name: 2N-302 Common Well Name: 2N-302 Spud Date: 6/28/2001 Event Name: ROT - DRILLING Start: 6/15/2001 End: Contractor Name: Nabors Rig Release: Group: Rig Name: Nabors 16E Rig Number: 16E Date: From-To Hours Code Sub Phase Description of Operations Code 7/3/2001 00:30- 01:15 0.75 CASE RUNC SURFAC 2 plug cmtg head. 01:15 - 03:30 2.25 CEMEN-[ CIRC SURFAC Circulated & conditioned mud rheology down for cement job. 03:30 - 04:00 0.50 CEMEN'[ SFTY SURFAC PJSM & pressure tested cmt line & cmt head valves to 3500 psi - 5rain, OK. 04:00 - 05:45 1.75 CEMEN'I'PUMP SURFAC Mixed & pumped (RCM 6 bbl mixer) 40 bbls flush. Released bttm plug. Pumped 50 bbls MudPush @ 10.2 ppg + 298 bbls (376 sxs) of Arctic Set-Lite @ 10.7 ppg + 50 bbls (240 sxs) Class G @ 15.8 ppg. Released Top Plug. Left 5 bbls of cement to go behind top plug. Throughout cement mixing, casing was reciprocated +/- 10 ft up and down & tagging landing ring periodically to keep it flushed out. P/U wt 140-150k & S/O wt 120-115k. 05:45 - 06:15 0.50 CEMEN'I'DISP SURFAC Released Top Plug & displaced cement with 10.2 ppg mud @ 8 - 3 bpm. Could not move the casing after releasing the top plug. Prior to this, opened both annular valves to the vacuum trucks in order to avoid bridging the fluted hanger when cement hits. Can not go back down & hanger is 1.2' high, still have 100% returns. Slowed rat down in last 350 strokes. Total displacement was 1480 strokes & had red dye back at +/- 750 strokes. During displacement pressure rose from 310-510 psi prior to bumping plug. Bumped plug & pressured csg to 1000 psi, held OK. Bled pressure off & floats holding OK. 06:15 - 09:00 2.75 CASE NUND SURFAC Worked casing & could not get it to go deeper. Measured & positioned 7-5/8" hanger to proper position to allow emergency slip placement. Landing shoulder on hgr is now 1.5' above landing ring with 120,000 lbs. N/D diverter line & raise surface stack. Cleaned out landing ring area & set emergency slips... 50,000 lbs on slips. 09:00 - 11:30 2.50 CASE RURD SURFAC R/D cmt head + lines. R/D long bails & P/U drlg bails. Made rough cut on 7-5/8" csg & removed 7-5/8" landing jt + hanger. Hung surface stack. 11:30 - 21:00 9.50 CASE NUND SURFAC While waiting on hot head + GBR welder the rig slipped & cut drlg line + serviced rig & TDS + C/O saver sub for 4" dp + P/U 4" handling tools. Welder made final cut & prep'd for adaptor nipple. Placed nipple on 7-5/8" stub & performed LEL test, OK. Installed HotHed. Ignited HotHed and shortly after heating the adaptor we started getting intermittent flaming from the 7-5/8" slip area. Pulled the HotHed & put out same & flames. Checked LEL's and intermittend from 0 - 10-20%. With the assistance of 2N prod op's & KOC safety.., the 7-5/8" hanger was sealed with silicon & barite. LEL's were checked for 30min and : reading=0%. Maintained steady purge of N2 from one 16" conductor outlet to the other with a 30' hose clearing the N2 & other gas away from the cellar area. Pre-Heated adaptor to 400deg-F & checked LEL's=0%. Leveled !adaptor & welded to stub with 2 passes internally & 2 passes externally. Tested welds with N2 to 1400 psi, OK. Waited for adaptor to cool slowly with insulation over adaptor, for 3 hrs. 21:00 - 22:30 1.50 CASE NUND SURFAC Dressed off welding slag inside of adaptor. Installed wellhead. 22:30- 00:00 1.50 WELCTL NUND SURFAC Installed 13-5/8" BOP stack. 7/4/2001 00:00- 02:00 2.00 WELCTL NUND SURFAC N/U BOP's and choke system 02:00 - 03:00 1.00 WELCTL EQRP SURFAC Change lower pipe rams to 4" 03:00 - 04:00 1.00 WELCTL BOPE SURFAC Set test plug in well head and rig up to test BOP's 04:00 - 07:30 3.50 WELCTL BOPE SURFAC Test BOP's,choke manifold and floor valves to 250 psi Iow and 5000 psi high, Hydril to 3500 psi 07:30 - 17:30 10.00 DRILL PULD SURFAC Hold pre-job meeting, P/U and stand back in derrick, 231 jts of 4" drill pipe, 77 stands. Printed: 7/27/2001 2:03:24 PM PHILLIPS ALASKA INC. Page 6 of 8 Operations Summa RePort :Legal Well Name: 2N-302 Common Well Name: 2N-302 Spud Date: 6/28/2001 Event Name: ROT - DRILLING Start: 6/15/2001 End: Contractor Name: Nabors Rig Release: Group: Rig Name: Nabors 16E Rig Number: 16E Sub' Date From - To Hours Code COde Phase Description of Operations 7/4/2001 17:30 - 22:30 5.00 DRILL PULD SURFAC Load pipe shed with BHA, P/U Bit,Motor,MWD and flex its, RIH to 300+ ft., test MWD and Icad sources. 22:30 - 00:00 1.50 DRILL SFTY SURFAC Hold pre-drill meeting, circ bottoms up, conduct a Well Kill Drill, followed with a Stripping in hole drill 7/5/2001 00:00 - 02:00 2.00 WELCTL SFTY SURFAC Perform stripping drill with 2nd crew, Pull back out of hole and retrieve safety valve and inside gray 02:00 - 03:00 1.00 DRILL PULD SURFAC P/U 4" DP and RIH 03:00 - 07:00 4.00 RIGMNT RGRP SURFAC Had hydraulic leak in top drive and had to repair failed seal 07:00 - 09:00 2.00 DRILL PULD SURFAC P/U 4" DP and RIH to2662' 09:00 - 10:00 1.00 DRILL CIRC SURFAC Circ. thick mud out of hole and cond. mud 10:00 - 11:30 1.50 CASE DEQT SURFAC Rig up and test casing to 2500 psi for 30 mins. held OK. 11:30 - 13:00 1.50 CEMEN'I DSHO SURFAC Wash from 2662' to top of cement at 2800' 13:00 - 15:00 2.00 CEMEN'] DSHO SURFAC Drill wiper plugs, float collar, cement, float shoe, rat hole and 20' of new formation to 2923' 15:00 - 17:30 2.50 CEMEN'] CIRC SURFAC Circ and cond. mud for FIT test 17:30 - 18:30 1.00 CEMEN'] FIT SURFAC Perform FIT test to 16 ppg. 18:30 - 19:00 0.50 DRILL DEQT PROD Establish PWD base line 19:00 - 00:00 5.00 DRILL DRLG PROD Drill from 2923' to 3483' 7/6/2001 00:00 - 19:00 19.00 DRILL DRLG PROD Drill from 3483' to 5402' with no torque or drag 19:00 - 20:30 1.50 DRILL CIRC PROD Pump sweep, circ. bottoms up, pump sweep, circ. bottoms up, check for flow, pump slug 20:30 - 22:00 1.50 DRILL WlPR PROD Make wiper trip to the shoe, 2888', no excess drag or swabbing, and hole took good fill, check for flow 22:00 - 23:00 1.00 DRILL WlPR PROD TIH to bottom, hole slick all the way in 23:00 - 23:30 0.50 DRILL CIRC PROD Break circ. and wash last stand to bottom, no fill 23:30 - 00:00 0.50 DRILL DRLG PROD Drill from 5402' to 5498' 7/7/2001 00:00 - 11:00 11.00 DRILL DRLG PROD Drill from 5498' to 6650', seeing high ECD's 11:00 - 12:00 1.00 DRILL CIRC PROD Pump sweep's and circ. bottoms up to clean hole and lower ECD 12:00 - 00:00 12.00 DRILL DRLG PROD Drill from 6650' to 7514' MD, 4264' TVD 7/8/2001 00:00 - 13:30 13.50 DRILL DRLG PROD Drill from 7514' to 8668' MD, 4810 TVD 13:30 - 16:00 2.50 DRILL CIRC PROD Circ. and cond, pump sweeps, circ. bottoms up 16:00 - 20:00 4.00 DRILL Wl PR PROD Make wper trip to 4347', 44 stands. Hole in good shape, no drag 20:00 - 20:30 0.50 DRILL CIRC PROD Break circ., wash to bottom, no fill 20:30 - 00:00 3.50 DRILL DRLG PROD Drill from 8668' to 8859' MD, 4921' TVD 7/9/2001 00:00 - 05:30 5.50 DRILL DRLG PROD Drill from 8859' to 9339' MD, 5250 TVD 05:30 - 12:00 6.50 DRILL DRLG PROD Control drill though pay to pick markers on MWD Icg from 9339' to 9786' MD, 5572' TVD 12:00 - 19:30 7.50 DRILL DRLG PROD Drill from 9786' to 10297' MD, 5938' TVD, Total depth of well 19:30 - 22:00 2.50 DRILL CIRC PROD Circ. and cond. mud and hole, pump sweep and circ. hole clean, check flow, pump dry job 22:00 - 00:00 2.00 DRILL TRIP PROD POOH, presently at 7000' and have seen no swabbing or hole drag. 7/10/2001 00:00 - 02:30 2.50 DRILL TRIP PROD POOH to run casing, pull to shoe, flow check 02:30 - 03:30 1.00 RIGMNT RURD PROD Slip and cut drill line 03:30 - 04:30 1.00 DRILL TRIP PROD POOH to BHA 04:30 - 06:00 1.50 DRILL RIRD PROD Down Icad MDW info., pull radioactive sources 06:00 - 08:00 2.00 DRILL PULD PROD L/D BHA 08:00 - 09:00 1.00 CASE RURD PROD Pull wear bushing and R/U to run 3 1/2" casing 09:00 - 09:30 0.50 CASE SFTY PROD Pre-job safety meeting 09:30 - 12:00 2.50 CASE RUNC PROD RIH with 3 1/2" casing, 32 jts 12:00 - 14:00 2.00 CASE RURD PROD R/U to run 5 1/2" casing, longer bales,elevators, spider and Baker seal bore receptical 14:00 - 16:30 2.50 CASE RUNC PROD RIH with 5 1/2" casing to the 7 5/8" shoe, 2880' 16:30 - 17:30 1.00 CASE RURD PROD Install casing fill up tool to top drive Printed: 7/27/2001 2:03:24 PM PHILLIPS ALASKA INC. Page 7 of 8 Operations Summar Report Legal Well Name: 2N-302 Common Well Name: 2N-302 Spud Date: 6/28/2001 Event Name: ROT - DRILLING Start: 6/15/2001 End: Contractor Name: Nabors Rig Release: Group: Rig Name: Nabors 16E Rig Number: 16E Sub Date From - To Hours Code Code Phase DesCription of Operations 7/10/2001 17:30 - 18:00 0.50 CASE ClRC PROD Circ hole at 40 spm, 142 gpm 18:00 - 22:00 4.00 CASE RUNC PROD RIH with 5 1/2" casing to 6400', wasn't seeing the right amount of displacement the last 5 jts. 22:00 - 00:00 2.00 CASE ClRC PROD Break circulation at a slow rate, 20 spin. losing partial returns. Work pipe and attempt to regain full returns. Mud going in was 9.6 ppg 43 vis and mud out was 10.1 ppg 90+ vis. At midnight we were losing 100 +- bph at 30 spm. 7/11/2001 00:00 - 03:30 3.50 CASE ClRC PROD Circ. at 40 spm with gain-loss stable, anything over 40 spin and we start loosing up to +- 100 bbl. per hr. with pumps down the well flows, but slows down with time. Total losses to hole approx. 200 bbls. 03:30 - 06:00 2.50 CASE RUNC PROD RIH W/casing to 8205', tag bridge, or tight spot, well flowing back at 30 bbls per hr. the first hr. then steadily decreased 06:00 - 13:00 7.00 CASE RUNC PROD Circ. at 30 spm through fill up tool and wash through tight area from 8205' to 8600', continue to wash casing down at 30 spm, but from this point on casing went to bottom with no problem. Total casing run was 32 jts. 3 1/2" 9.3# L-80 8rd and 216 jts. 5 1/2" 15.5# L-80 BTC-MOD, set at 10282' MD 13:00 - 16:30 3.50 CEMEN'] ClRC PROD Circ. and cond. hole for cement. Broke circ. at 30 spm and brought pump up to 58 spm, 210 gpm, with no losses. 16:30 - 17:00 0.50 CEMEN'] RURD PROD L/D fill up tool, R/U cementing head 17:00 - 18:30 1.50 CEMEN'] ClRC PROD Circ. hole while batch mixing cement, held pre-job meeting 18:30 - 20:30 2.00 CEMEN'I PUMP PROD Pump 10 bbls. CW100, Test lines to 3500 psi, pump 30 bbls. CW100, Drop bottom plug, Mix and pump 47 bbls. 11.0 ppg. Mud Push, 60 sacks lead cement 21.2 bbls. at 13.0 ppg, followed by 402 sacks tail 86.0 bbls. at 15.8 ppg. Drop top blug, displace with 12.0 bbls high vis perf. pill and 213.9 bbls fresh water. Bump plug, pressure climbed steady up until plug bumped. Pressure before plug bumped was 1500 psi, pressured up to 2000 psi and held for 5 mins. Release pressure and floats held. Reciprocated pipe in a 10' stroke until cement rounded shoe. Had good returns through out job. 20:30 - 00:00 3.50 WALTON CMT PROD Annulus flowing back, shut in well with annular while waiting on cement cure time. Shut in pressure came up to 106 psi and gradually fell back to 60 psi 7/12/2001 00:00 - 01:00 1.00 CMPLTI~ OBSV PROD Well had 60 psi on it, open well and bleed off pressure, L/D casing landing jt., well flowed back 2 bbls mud and slowed to a trickle 01:00 - 02:00 1.00 CMPLTI~ NUND PROD Install tubing head packoff, test to 5000 psi 02:00 - 02:30 0.50 CMPLTI',I SFTY PROD Hold pre-job safety meeting, prepare to run tubing 02:30 - 10:30 8.00 CMPLTk RUNT PROD P/U and run 3 1/2" production tubing to top of liner, 9246'. Total tubing run 292 Jts. 3 1/2" 9.3# L-80 EUE 8rd 10:30 - 13:00 2.50 CMPLTI~ ClRC PROD Circ. clean fresh water and balance fluid in hole 13:00 - 14:00 1.00 CMPLTk DEQT PROD Test casing to 3500 psi for 30 mins., perform leak off test with 9.6 ppg mud down 5 1/2 x 7 5/8" annulus, leakoff was at 480 psi, shut down and in 10 mins. pressure bled to 280 psi. Pump 100 bbls water and 30 bbls diesel to freeze protect. 14:00 - 15:00 1.00 CMPLTI~ SOHO PROD P/U hanger and landing jt., space out seal assembly in seal bore, land tubing in hanger 15:00 - 17:00 2.00 CMPLTI~ DEQT PROD test tubing to 3500 psi for 15 mins. and then annulus to 3500 psi for 15 mins., shear Camco shear valve, bleed off well. 17:00 - 19:00 2.00 CMPLTI~ FRZP PROD Freeze protect tbg. and csg. by pumping 55 bbls diesel down 3 1/2"x5 1/2" annulus and U-tubing back to tubing 19:00 - 19:30 0.50 CMPLTI~ NUND PROD L/D tubing landing jt., install 2-way back pressure valve 19:30- 22:30 3.00 CMPLTI~ NUND PROD N/D BOP's 22:30 - 00:00 1.50 CMPLTI',J SEQT PROD N/U Tree Printed: 7/27/2001 2:03:24 PM PHILLIPS ALASKA INC. Page 8 of 8 Operations Summary Report Legal Well Name: 2N-302 Common Well Name: 2N-302 Spud Date: 6/28/2001 Event Name: ROT - DRILLING Start: 6/15/2001 End: Contractor Name: Nabors Rig Release: Group: Rig Name: Nabors 16E Rig Number: 16E Sub Date From - To Hours Code Code Phase Description of Operations 7/13/2001 00:00 - 01:0o 1 .o0 CMPLTI'q SEQT PROD Test tree seals to 5000 psi, test body of tree and valves to 5000 psi. 01:00 - 03:00 2.00 MOVE DMOB PROD Change out Top Drive saver sub to 5" DP, change out kelly hose, finish cleaning fluid out of mud pits Release rig at 0300 hrs. 07/13/2001 Printed: 7/27/2001 2:03:24 PM Date Comment 2N-302 Event History 08/23/01 TAGGED FILL @ 10,135' WLM, DRIFTED W/22'-7" OF 2.65" DUMMY GUNS TO 10,000' WLM, IN PROGRESS [TAG] 08/24/01 REPLACED SOV W/DV @ 9201' RKB [GLV] 08/25/01 PT TBG & CASING TO 3000# [PT TBG-CSG] 09/01/01 COMPLETED CEMENT BOND LOG W/SCMT, GOOD CEMENT FROM 10134' TO 9270' WITH SMALL VOID AT 9635' TO 9614'. PERFORATED 9564' - 9584', USING 20' OF 2-1/2" HC, DP CHGS, 6 SPF, 60 DEG PHASING. [PERF] 09/02/01 PERFORATED: 9550'-9564', W/2-1/2" HSD, 6 SPF, DP CHGS, 60 DEG PHASING. OBTAINED INTIAI_ SBHP @ 9567'= 2411.5 PSI W/A GRADIENT STOP @ 9429'= 2364.1 PSI. [PERF, PRESSURE DATA] Page 1 of I 9/10/01 DEFINITIV Kuparuk River Unit North Slope, Alaska Kuparuk 2N, Slot 2N-302 Plan 2N-302 Job No. AKZZ11101, Surveyed: 9 July, 2001 S UR VEY REPORT 23 July, 2001 Your Reh 501032038000 sUrface Coordinates: 5912010.81 N, 461107.86 E (70° 10' 14.0043" N, 150° 18' 46.8382" W) Kelly Bushing: 153.63ft above Mean Sea Level DRiLI'iN A Halliburton Company S~rvey Ref: svyg585 Sperry-Sun Drilling Services Survey Report for 2N-302 Your Ref: 50'1032038000 Job No. AKZZ11101, Surveyed: 9 July, 2001 DEFINITIVE Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) fit) (ft) (ft) (ft) Dogleg Rate (°l'~OOft) North Slope, Alaska Kuparuk 2N Vertical Section Comment 2N-302 Gyros 0.00 143.00 175.00 260.00 349.00 443.00 534.00 621.00 658.00 746.88 0.000 1.150 1.200 1.400 1.900 4.100 5,500 7.400 7.700 7.810 0.000 254.000 251.000 250.000 6.000 22.000 24.000 28.000 35.000 44.520 -153.63 -10.64 21.35 106.33 195.31 289.18 379.86 466.30 502.98 591.05 0.00 142.99 174.98 259.96 348.94 442.81 533.49 619.93 656.61 744.68 0.00 N 0.00 E 5912010.81 N 461107.86 E 0.40 S 1.38W 5912010.42 N 461106.48 E 0.59 S 2.00W 5912010.23 N 461105.85 E 1.24 S 3.82W 5912009.59 N 461104.03 E '0.14 S 4,69W 5912010.69 N 461103.17 E 4.52 N 3.27W 5912015.35 N 11.52 N 0.28W 5912022.34 N 20.28 N 4.05 E 5912031.07 N 24.42 N 6.59 E 5912035.19 N 33.60 N 14.24 E 5912044,34 N 461104.62 E 461107.64 E 461112.02 E 461114.58 E 461122.27 E 0.804 0.248 0.237 3.158 2.482 1.549 2.243 2.613 1.449 0.00 -0.96 -1.42 -2.80 -2.19 2.62 10.22 19,99 24.82 36.44 Tolerable Gyro 2N-302 838.00 9.584 35.744 838.31 9.590 35.720 937:02 11.410 38.180 1028.28 13.190 36.240 1119.41 15;120 33.790 1216.33 18.070 1309.34 20.950 1404.61 25.090 1498.53 29.310 1592.95 33.060 1686.69 36.440 !781.83 39.970 1875.15 42.950 1969.30 46.070 2064.68 49.260 , 23 July, 2001.1:59 32.74O 31.000 31.620 29.860 26,450 25.690 28.300 27.840 29.190 27.310 681.13 681.43 778.49 867.65 ' 956.01 1048.88 1136.54 1224.21 1307.72 1388.49 1465.50 1540.26 1610.18 1677.32 1741.55 834.76 835.06 932.12 1021.28 1109.64 1202.51 1290.17 1377.84 1461.35 1542.12 1619:13 1693.89 1763.81 1830.95 1895,18 44.17 N 23.01E 5912054.86 N 44,21N 23.04 E 5912054.90 N 58.56 N 33.88 E 5912069.20 N 74.06 N 45.62 E 5912084.63 N 92.32 N 58.37 E 5912102.83 N 115.48 N 73.54E 5912125.91N 141.87 N 89.91E 5912152.22 N 173.68 N 109.28 E 5912183.93 N 210.59 N 131.17E 5912220.73 N 253.71N 154.16 E 5912263.73 N 301.71N 177.63 E 5912311.60 N 354.10 N 204.37 E 5912363.85 N 408.61N 233.44 E 5912418.22 N 466.59 N 264.96 E 5912476.03 N 528.70 N 298.30 E 5912537.97 N Page 2 of 6 461131.10 E 461131.13 E 461142.04 E 461153.86 E 461166.71E 461181.99 E 461198.49 E 461218.03 E , 461240.11E 461263.32 E 461287.03 E 461314.05 E 461343.39 E 461375.21E 461408.87 E 2.426 2.426 1.898 2.002 2.217 3.059 3.159 ' 4.353 4,574 4.388 3.635 4.079 3.210 3.463 3.648 49.79 49.84 67.50 86.58 108.60 136.07 166.97 204.06 246.85 295.68 349.11 407.92 469.66 535.60 606.04 IFR Tie On to Gyros DrillQue.~t 2,00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-302 Your Ref: 501032038000 Job No. AKZZ11101, Surveyed: 9 July, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Depth Depth (ft) (ft) 2156.68 52.680 26.230 1799.48 1953.11 2248.25 55.850 24.240 1852,95 2006,58 2342.69 59.320 24.790 1903.57 2057,20 2436,41 62.440 23.970 1949.17 2102,80 2529,69 62,190 23,840 1992.51 2146,14 2625.71 66.140 2719,57 65,100 2814,15 64.740 2851.30 64,680 2891.23 65.220 23.940 2034.35 2187.98 23.720 2073.09 2226.72 23.750 2113.18 2266.81 22.970 2129.05 2282.68 23.890 2145.96 2299.59 26.050 2184,19 2337,82 25.830 2222,40 2376,03 27,110 2272,02 2425,65 28.730 2311,42 2465,05 28,510 2350.32 2503,95 2984.77 66.530 3081.97 67.180 3209,15 66.890 3307.26 65,760 3399.99 64.630 3495.10 63,330 28.650' 2392.04 2545,67 3591.21 63.990 27.640 2434,69 '2588,32 3687.58 63.820 26,130 2477,08 2630,71 3783.37 631280 26,670 2519,75 2673,38 3877.67 63,840 27.430 2561,74 2715,37 3973,21 64.350 26,900 2603.48 2757,11 4070.69 65.280 25.400 2644,96 2798,59 4165,30 64.720 25.510. 2684,94 2838,57 4263.37 65.190 25.370 2726.46 2880,09 4359.25 65.700 24.670 2766.30 2919,93 24.210 2805.48 2959,11 23,410 2845,24 2998,87 22,980 2884,97 3038,60 24,280 2925.08 3078,71 25.030 2965.33 3118,96 4455,61 66,320 4551.90 64.900 4646,71 65.560 4743.42 65.430 4841.33 66,020 23 July, 200f - 1:59 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 592,50 N 330,47 E 5912601,61 N 461441.37 E 659,73 N 362,13 E 5912668.67 N 461473.37 E 732,26 N 395,21E 5912741.03 N 461506,83 E 806,82 N 428,99 E 5912815,42 N 461540,99 E 882.34 N 462,46 E 5912890,76 N. 461574,85 E 961,34 N 497,46 E 5912969,58 N 461610.25 E 1039,54 N 532,00 E 5913047,61N 461645,19 E 1117,96 N 566,48 E 5913125,84 N 461680,07 E 1148,80 N 579,80 E 5913156,61N 461693.55 E 1181,99 N 594,18 E 5913189,73 N 461708,11 E 1259,37 N 630,22 E 5913266,92 N 461744,55 E 1339,74 N 669,32 E 5913347,09 N 461784,05 E 1444,56 N 721.51 E 5913451,64 N 461'836.78 E 1523,95N 763,57 E 5913530,82 N 461879,26 E 1597,84 N 803,89 E 5913604,50 N 461919,95 E 1672.89 N 844.78 E 5913679.34 N 461961.23 E 1748.84 N 885.41E 5913755.08 N 462002.24 E 1826.03 N 924.54 E 5913832.06 N 462041.77 E 1902.85 N 962.67 E 5913908.68 N 462080.30 E 1978.05 N 1001.07 E 5913983.68 N 462119.09 E 2054,51N 2133,69 N 2211.11N 2291,34 N 2370,37 N 1040,31 E 5914059,94 N 462158.71 E 1079,18 E 5914138,92 N 462197,99 E 1116,03 E '5914216,15 N 462235,24 E 1154,20 E 5914296,19 N 462273,82 E 1191,08 E 5914375.03 N 462311,11E 2450.52 2530.74 2609,87 2690,49 2771,61 1227,51 E 5914454,98 N 462347,94 E 1262,91E 5914535,03 N 462383,76 E 1296,82 E 5914613,98 N ,462418,07 E 1332,09 E 5914694,42 N 462453,76 E 1369.32 E 5914775,34 N 462491.41'E Page 3 of 6 Dogleg Rate (°ll00ft) 3.828 3.885 3.707 3.416 0.295 4,115 1.128 0.382 1.905 2.487 2,530 0,700 0.954 1.901 1,237 1.373 1.166 1.418 0.757 0.935 0,731 1,688 0.601 0,496 0.851 0.777 1.657 0.809 1.231 0.922 North Slope, Alaska Kuparuk 2N Vertical Section Comment 677.49 751.80 831.48 913.30 995.84 1082.18 1167.60 1253,19 1286.74 1322.87 1408.21 1497.59 1614.68 1704.49 1788.58 1873.97 1960.05 2046.58 2132.35 2216.77 2302.70 2390.90 2476.64 2565.49 2652.68 2740.67 2828.30 2914.27 3002.18 3091,40 DrillQuesf 2.00,0~1.005 Sperry-Sun Drilling Services Survey Report for 2N-302 Your Ref: 501032038000 Job No. AKZZlf101, Surveyed: 9 July, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings Northings (ft) (ft) (ft) (ft) (ft) 4938.60 65.560 25.470 3005.22 3158.85 5033.38 63.650 26.920 3045.87 3199.50 5135.49 63.110 28.170 3091.62 3245.25 5227.78 62.840 29.120 3133.56 3287.19 5324.58 63.310 28,590 3177.39 3331.02 2851.84 N 1407.16 E 2928.67 N 1444.95 E 3009.61 N 1487.16 E 3081.76 N 1526.57 E 3157.35 N 1568.22 E 5421.04 63.620 5515.73 64.250 5613.07 64.450 5708.10 64.640 5803.38 65.030 Global Coordinates Eastings (ft) 5914855.38 N 462529.66 E 5914932.01 N 462567.84 E 5915012.73 N 462610.47 E 5915084.68 N 462650.25 E 5915160.06 N 462692.28 E 27.910 3220.48 3374.11 3233.37 N 1609.06 E 5915235.86 N 462733.52 E 28.160 3262.09 3415.72 3308.44 N 1649.04 E 5915310.74 N 462773.88 E 27.330 3304.23 3457.86 3386.10 N 1689.89 E 5915388.18 N 462815.13 E 26.160 3345.07 3498.70 3462.73 N 1728.50 E 5915464.61 N 462854.14 E 25.620 3385.59 3539.22 3540.31N 1766.16 E 5915541.99 N 462892.19 E 5898.32 65.300 25.230 3425.46 3579.09 5995.22 64.860 25.700 3466.29 3619.92 6092.12 64.970 26.400 3507.37 3661.00 6187.48 65.280 25.810 3547.49 3701.12 6282.99 65.400 26.210 3587.34 3740.97 6379.27 63.960 26.350 6473.46 63.290 25.390 6569.97 63.600 24.700 6666.55 63.660 24.290 6762.46 64.030 24.870 3618.12 N 1803.15 E 3697.46 N 1840.93 E 3776.31N 1879.47 E 3854.00 N 1917.54 E 3932.00 N 1955.60 E 3628.51 3782.14 4010.04 N 1994.14 E 3670.36 3823.99 4085.96 N 2030.96 E 3713.50 3867.13 4164,'17 N 2067.50 E 3756.40 3910.03 4242.92 N 2103.38 E 3798.68 3952.31 4321.20 N 2139.19 E 3840.49 3880.99 3920.92 3961.10 4002.29 3994.12 4O34.62 4O74.55 4114.73 4155.92 4194.06 4232.69 .4270.95 4309.62 4350.00 6858.80 64.530 6953.81 65.000 7048.99 65.400 7145.10 65.170 7244.25 65.740 4040.43 4079.06 4117.32 4155.99 4196.37 44OO.22 N 4478,86 N 4557.97 N 4637.10 N 4718.46 N 2175.09 E 2209.76 E 2244.51 E 2281.38 E 23~0.30 ,E 4796.55 N 4875.63N 4954.06 N 5032.71N 5109.80 N 2356.76 E ,2395.13 E 2434.26 E 2473.99 E 2514.04 E 24.000 23.590 23.830 26.140 25.000' 25,040 26.740 26,29O 27.310 27.610 5915619.62 N 462929.58 E 5915698.76 N 462967.77 E 5915777.41N 463006.72 E 5915854.90 N 463045.18 E 5915932,71 N 463083.64 E 7338.50 · 66.520 7434.51 66,030 7530.'15 66.810 7626.38 65.810 7722.18 64.320 5916010.55 N 5916086.28 N 5916164.3O N 5916242.86 N 5916320.96 N Dogleg Vertical Rate Section (°/100ft) 5916399.80 N 5916478.26 N 5916557.18 N 5916636.12 N 5916717.28 N 5916795.19N 5916874.06 N 5916952.29 N 5917O3O.74 N 5917107.62 N 0.628 3180.11 2.444 3265.72 1.215 3356.98 0.963 3439.11 0.689 3525.32 0.708 3611.56 0.706 3696.57 0.796 3784.28 1.130 3870.08 0.656 3956.32 North Slope, Alaska Kuparuk 2N 0.469 4042.47 0.632 4130.34 01664 4218.10 0.649 4304.61 0.401 4391.41 463122.58 E 1.501 4478.44 463159.79 E 1.157 4562.82 463196.73 E 0.716 4649.13 463233.01 E 0.385 4735.63 463269.23 E 0.666 4821.69 463305.53 463340.61 463375,76 463413.04 ,463452.38 Comment 463489.23 463528.02 463567.55 463607.68 463648.13 0.965 4908.44 0.630 4994.31 0.479 5080.64 2.196 5167.92 1.193 5258.10 0.828 5344.27 1.699 5432.16 0.923 5519.81 1.422 5607.93 1.581 5694.77 23 July, 2001 - 1:59 Page 4 of 6 DrillQ,est 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-302 Your Ref: 501032038000 Job No. AKZZ11101, Surveyed: 9 July, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth fit) Vertical Depth (ft) 7817.52 64.550 27.060 4237.52 4391.15 7912.72 63.210 26.200 4279.43 4433.06 8011.04 63.340 26.160 4323.64 4477.27 8109.50 62.250 26.560 4368.66 4522.29 8204.71 61.380. 25.010 4413.63 4567.26 8301.40 61.910 24.680 4459.55 4613.18 8396.94 59.980 24.850 4505.95 4659.58 8492.78 58.180 26.130 4555.19 4708.82 8591.18 55.540 26.120 4608.98 4762.61 8684.54 54.260 26.880 4662.66 4816.29 8780.33 53.040 26.470 4719.44 4873.07' 8876.35 51.820 27.350 4777.98 4931.61 8972.36 .49.740 26.440 4838.69 4992.32 9068.39 47.380 26.240 4902.24 5055.87 9165.75 45.170 26.720 4969.53 5123.16 9261.40 43.190 25.320 5038.13 5191.76 9357.29 42.950 24.810 '5108.18 5261.81 9454.16 43.550 24.430 5178.73 5332.36 9548.39 43.660 24.290 5246.97 5400.60 9644.85 43.790 23.480 5316.67 5470.30 5386.38 5455.39 5525.03 5594.O7 5661.17 9741.11 43.410 22.620 9836.11 43.420 23.160 9932.67 44.270 22,420 10029.45 44.710 22.880 10124.04 44.930 23.000 10219.29 44.690 22.120 5728.74 10297.00 44.690 22.120 5783.99 5540.01 5609.02 5678.66 5747.70 5814.80 5882.37 5937.62 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5186.20 N 2553.54 E 5917183.82 N 463688.02 E 5262.60 N 2591.85 E 5917260.02 N 463726.72 E 5341.41 N 2630.60 E 5917338.63 N 463765.87 E 5419.87 N 2669.48 E 5917416.89 N 463805.15 E 5495.43 N 2705.98 E 5917492.26 N 463842.05 E 5572.65 N 2741.73 E 5917569.29 N 463878.20 E 5648.48 N 2776.72 E 5917644.94 N 463913.57 E 5722.69 N 2812.09 E 5917718.98 N 463949.32 E 5796.66 N 2848.37 E 5917792.76 N 463985.98 E 5865.02 N 2882.44 E 5917860.94N 464020.41E 5933.96 N 2917.08 E 5917929.70 N 464055.40 E 6001.82 N 2951.52 E 5917997.38 N' 464090.18 E 6068.15 N 2985.17 E 5918063.54 N 464124,18 E 6132.66 N 3017.11E 5918127.88 N 464156.45 E 6195.63 N 3048.48 E 5918190.70 N 464188.14 E 6255.52 N 3077.73 E 5918250.44 N 464217.70 E 6314.84 N 3105.47 E 5918309.61N 464245.74 E 6375.18 N 3133.12 E 5918369.80 N 464273.70 E 6434.38 N 3159.93 E 5918428.87 N 464300.81 E 6495.34 N 3186.92 E 5918489.69 N 464328.12 E 6556.43 N 3212.91E 5918550.64 N 464354.43 E 6616.58 N 3238.31E 5918610.66 N 464380.13 E 6678.24 N 3264.22 E 5918672.19 N 464406.35 E 6740.83 N 3290.34 E 5918734.64 N 464432.79 E 6802.23 N 3316.32 E 5918795.91 N 464459.10 E 6864.22 N 3342.08 E 5918857.77 N 464485.17 E 6914.85 N 3362.66 E 5918908.29 N 464506.01 E Dogleg Rate (°llOOft) O.574 1.625 0.137 1.165 1.701 0.625 2.026 2.200 2.683 1.524 1.319 1.464 2.287 2.463 2.298 2.308 0.441 0.675 0.155 0.596 0.732 0.391 1.028 0.564 0.249 0.698 0.000 North Slope, Alaska Kuparuk 2N Vertical Section Comment 5780.76 5866.23 5954.04 6041.61 6125.52 6210.59 6294.08 6376.29 6458.68 6535.05 6612.20 6688.30 6762.67 6834.65 6905.00 6971.65 7037.12 7103.47 7168.43 7235.05 7301.34 7366.52 7433.29 7500.99 7567.56 7634.56 7689.07 Projected Survey 23 July, 2001- 1:59 Page 5 of 6 DrillQuesf 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-302 Your Reft 501032038000 Job No. AKZZf1101, Surveyed: 9 July, 2001 Kuparuk River Unit North Slope, Alaska Kuparuk 2N All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 153.9' MSL. Northings and Eastings are relative to 5' FSL & 484' FEL. Magnetic Declination at Surface is 25.662° (13-Jun-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 5' FSL & 484' FEL and calculated along an Azimuth of 26.140° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10297.00ft., The Bottom Hole Displacement is 7689.12ft., in the Direction of 25.933° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 838.31 835.06 44.21 N 23.04 E 10297.00 5937.62 ' 6914.85 N 3362.66 E Comment Tie On to Gyros Projected Survey Survey tool program for 2N.302 From To Measured, Vertical Measured Depth Depth Depth (rt) (ft) (ft) '0 00 0.00 838.00 838.00 834..76 ;I 0297.00 Vertical Depth (ft) 834,76 5937.62 Survey Tool Description Tolerable Gyro (2N-302 Gyros) IFR (2N-302) 23 July, 200f - 1:59 Page 6 of 6 DrillQ.est 2.00.08.005 Kuparuk River Unit North Slope, Alaska Kuparuk 2N, Slot 2N-302 Plan 2N-302 MWD Job No. AKMMfllOl, Surveyed: 9 July, 200~ S UR VEY REPORT 23 July, 2001 Your Ref: 501032038000 Surface Coordinates: 59120~0.8I N, 461107.86 E (70° 10' 14.0043" N, 150° ~8'46.8382" W) Kelly Bushing: 153.63ft above Mean Sea Level A Halliburton Company Sperry-Sun Drilling Services Survey Report for 2N-302 Your Ref: 501032038000 Job No, AKMM11101, Surveyed: 9 July, 2001 Kuparuk River Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) Dogleg Rate (°/100ft) North Slope, Alaska Kuparuk 2N Vertical Section Comment 2N-302 Gyros 0.00 0.000 0.000 -153.63 0.00 143.00 1.150 254.000 -10.64 142.99 175.00 1.200 251.000 21.35 174.98 260.00 1.400 250.000 106.33 259.96 349.00 1900 6.000 195.31 348.94 443,00 4.100 22.000 289.18 442.81 534.00 5.500 24.000 379.86 533.49 621.00 7.400 28.000 466.30 619.93 658.00 7,700 35.000 502.98 656.61 746.88 7.810 44.520 591.05 744.68 0.00 N 0.00 E 5912010.81 N 461107.86 E 0.40 S 1.38W 5912010.42 N 461106.48 E 0.59 S 2.00W 5912010.23 N 461105.85 E 1.24 S 3.82W 5912009.59 N 461104.03 E 0.14 S 4.69W 5912010.69 N 461103.17 E 4.52 N 3.27W 5912015,35 N 461104.62 E 11.52 N 0.28W 5912022.34 N 461107.64 E 20.28 N 4.05 E 5912031.07 N 461112.02 E 24.42 N 6.59 E 5912035.19 N 461114.58 E 33.60 N 14.24 E 5912044.34 N 461122.27 E 0.804 0.248 0.237 3.158 2.482 1.549 2.243 2.613 1.449 0.00 -0.96 -1.42 -2.80 -2.19 2.62 10.22 19.99 24.82 36.44 Tolerable Gyro 2N-302 MWD 838.31 9.590 35.600 681.43 835.06 937.02 11.410 37.910 778.49 932.12 1028.28 13.190 36,020 867.65 1021.28 1119.41 15.120 33.490 956.01 1109.64 1216.33 18.070 32.460 1048.88 t202.51 1309.34 20.950 30.720 1136.54 1290.17 1404.61 25.090 31.300 1224.21 1377.84 1498.53 29.310 29.630 1307.72 1461.35 1592.95 33.060 26.340 1388.49 1542.12 1686.69 36,440 25.680 1465.50 1619.13 44.22 N 23.03 E 5912054.91 N 461131.12 E 58.61 N 33.82 E 5912069.25 N 461141.98 E 74.16 N 45.49 E 5912084.73 N 461153.73 E 92.48 N 58.16 E 5912102.99 N 461166.50 E 115.71N 73.21 E 5912126.14 N 461181.66 E 142.18 N 89.45 E 5912152,53 N 461198.04 E 174.10 N 108.65 E 5912184.35 N 461217.40 E 211.11 N 130.37 E 5912221.25 N 461239.31 E 254.30 N 153.23 E 5912264.32 N 461262.40 E 302.32 N 176.65 E 5912312.22 N 461286.06 E 2.437' 1.892 1,999 2,224 3,059 3.159 4.352 4,566 4,361 3.628 49.85 67.52 86.61 108.65 136.13 167.05 204,16 246.96 295,80 349.22 Tie On to Gyros MWD Magnetic Page 2 of 7 23 July, 2001 - 1:40 DriltOues! 2.00,08.005 Sperry-Sun Drilling Services Survey Report for 2N-302 Your Ref: 501032038000 Job No. AKMM11'lO1, Surveyed: 9 July, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 1781.83 39.970 28.250 1540.25 1693.88 1875.15 42.950 27.750 1610.18 1763.81 1969.30 46.070 28.910 1677.32 1830.95 2064.68 49.260 27.200 1741,55 1895.18 2156.68 52.680 26.060 1799.47 1953.10 2248.26 55.850 24.150 1852.95 2006.58 2342.69 59.320 24.870 1903.57 2057.20 2436.41 62.440 24.150 1949.17 2102.80 2529.69 62.190 24.170 1992.51 2146.14 2625.71 66.140 23.990 2034.34 2187.97 2719.57 65.100 23.540 2073.09 2226.72 2814.15 64.740 23.900 2113.18 2266.81 2851.30 64.680 22.960 2129.05 2282.68 2891.23 65.220 23.890 2145.96 2299.59 2984.77 66.530 26.060 2184.19 2337.82 3081.97 67.180 25.720 2222.40 2376.03 3209.15 66.890 26.970 2272.02 2425.65 3307.26 65.760 28.480 2311.42 2465.05 3399.99 64.630 28.200 2350,32 2503.95 3495.10 63.330 28.650 2392.04 2545.67 3591.21 63.990 27.780 2434.69 2588.32 3687.58 63.820 26.230 2477.08 2630.71 3783.37 63.280 26.550 2519.75 2673.38 3877.67 63.840 27.210 2561.73 2715.36 3973.21 64.350 26.860 2603.47 2757.10 4070.69 65.280 25.200 2644.96 2798,59 4165.30 64.720 25.330 2684.94 2838.57 4263.37 65.190 25.030 2726.46 2880.09 4359.25 65.700 24.330 2766.30 2919.93 4455.61 66,320 24.190 2805.48 2959.11 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 354.72 N 203.37 E 5912364.48 N 461313.05 E 409.27 N 232.36 E 5912418,88 N 461342.33 E 467.35 N 263.70 E 5912476.80 N 461373.96 E 529.57 N 296.83 E 5912538.85 N 461407.41 E 593.46 N 328.84 E 5912602.57 N 461439.75 E 660.77 N 360.35 E 5912669.72 N 461471.60 E 733,29 N 393,43 E 5912742.06 N 461505.05 E 807.77 N 427,38 E 5912816,38 N 461539.39 E 883.14 N 461,19 E 5912891,57 N 461573.58 E 962.03 N 496.44 E 5912970.27 N 461609.24 E 1040,27 N 530.89 E 5913048.34 N 461644.09 E 1118.69 N 565,35 E 5913126.58 N 461678.95 E 1149.51 N 578.71 E 5913157.33 N 461692.47 E 1182.70 N 593.09 E 5913190.45 N 461707.02 E 1260.08 N 629.14 E 5913267.64 N 461743.46 E 1340.49'N 668.16 E 5913347.84 N 461782.90 E 1445.42 N 720.13 E 5913452.51 N 461835.40 E 1524.96 N 761.92 E 5913531.83 N 461877.61 E 1599.04 N 801.88 E 5913605.71N 461917.95 E 1674.21N 842.56 E 5913680.66 N 461959.01 E 1750.10 N 883.28 E 5913756.35 N 462000.12 E 1827.21N 922.58 E 5913833,25 N 462039.81E 1904.03 N 960.70 E 5913909.88 N 462078.33 E 1979.35 N 998.87 E 5913985.00 N 462116.89 E 2055.90 N 1037,93 E 5914061.34 N 462156.35 E 2135.16 N 1076.64 E 5914140.41 N 462195.46 E 2212.70 N 1113.24 E 5914217.76 N 462232.45 E 2293.11 N 1151.04 E 5914297.97 N 462270.67 E 2372.35 N 1187.45 E 5914377.03 N 462307.49 E 2452.61 N 1223.62 E 5914457.10 N 462344.07 E Dogleg Rate (°llOOft) 4.068 3.213 3.424 3.597 3.840 3.853 3.731 3.396 0.269 4.117 1.191 0.514 2.293 2.506 2.538 0.742 0.933 1.820 1.249 1.431 1.063 1.455 0.638 0.863 0.627 1.812 0,605 0.554 0.851 0.657 North Slope, Alaska Kuparuk 2N Vertical Section Comment 408.04 469.78 535.73 606.18 677.63 751.94 831.61 913,44 996.00 1082,35 1'167.76 1253.35 1286.90 1323.03 1408.38 1497.75 1614.85 1704.66 1788.77 1874.17 1960.25 2046.78 2132.54 2216.97 2302.90 2391.11 2476.84 2565.68 2652.86 2740,84 23 July, 2001 - 1:40 Page 3 of 7 DrillQ,est 2,0~.08.005 Sperry-Sun Drilling Services Survey Report for 2N-302 Your Ref: 501032038000 Job No. AKMM'I1101, Surveyed: 9 July, 2001 Kuparuk River Unit Measured Depth (ft) Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings Northings (ft) (ft) (ft) (ft) 4551.90 64.900 23.150 2845.24 2998.87 4646.71 65.560 22.950 2884.96 3038.59 4743.42 65.430 24,210 2925.08 3078.71 4841.33 66.020 25.130 2965.33 3118.96 4938.60 65.560 25.550 3005.22 3158.85 5033.38 63.650 26,900 3045.87 3199.50 5135,49 63.110 28.070 3091.62 3245.25 5227.78 62,840 29.010 3133.56 3287.19 5324.58 63,310 28.420 3177.39 3331.02 5421.04 63,620 27.660 3220.48 3374.11 5515.73 64,250 27.960 3262.09 3415.72 5613.07 64.450 27.160 3304.23 3457,86 5708.10 64,640 26.090 3345.07 3498.70 5803.38 65.030 25,330 3385.59 3539.22 5898.32 65.300 25.090 3425.46 3579.09 5995.22 64.860 25.630 3466.29 3619,92 6092,12 64.970 26.320 3507.37 3661,00 6187.48 65.280 25.570 3547.49 3701.12 6282,99 65.400 25,930 3587.34 3740.97 6379.27 63.960 26,030 3628.51 3782.14 6473.46 63.290 24.910 3670.36 3823.99 6569.97 63.600 24.310 3713.50 3867.13 6666.55 63.660 23,930 3756.40 3910.03 6762.46 64.030 24.790 3798,68 3952,31 6858.80 64.530 23.880 3840.49 3994.12 6953.81 65.000 23.470 3880.99 4034.62 7048.99 65.400 23.750 3920.92 4074.55 7145,10 65,170 26.110 3961.10 4114.73 7244.25 65.740 24.840 4002.29 4155.92 7338.50 66.520 24.890 4040.43 4194.06 Global Coordinates 2532.93 N 1258.83 E 5914537.23 N 2612.14 N 1292.54 E 5914616.27 N 2692.79 N 1327.74 E 5914696,74 N 2773.89 N 1364.99 E 5914777.65 N 2854.07 N 1402.96 E 5914857.63 N 2930.88 N 1440.79 E 5914934.24 N 3011.86 N 1482,91 E 5915015.01 N 3084.08 N 1522.19 E 5915087,03 N 3159.77 N 1563.66 E 5915162.51N 3235.94 N 1604.22 E 5915238.47 N 3311.18 N 1643.91E 5915313,49 N 3388.97 N 1684.50 E 5915391.07 N 3465.67 N 1722.96 E 5915467.58 N 3543.37 N 1760.37 E 5915545.09 N 3621.32 N 1797.06 E 5915622.85 N 3700.73 N 1834.70 E 5915702.07 N 3779.63 N 1873.14 E 5915780.76 N 3857.42 N 1910.99 E 5915858.36 N 3935.60 N 1948.70 E 5915936.34 N 4013.84 N 1986.82 E 5916014.38 N 4090.02 N 2023.11E 5916090.37 N 4168.50 N 2059.06 E 5916168.68 N 4247.48 N 2094.42 E 5916247.47 N 4325.90 N 2129,93 E 5916325.71 N 4404.98 N 2165.69 E 5916404.61 N 4483.69 N 2200.20 E 5916483.14 N 4562.86 N 2234.81 E 5916562.13 N 4642.03 N 2271.60 E 5916641.10 N 4723.45 N 2310.39 E 5916722.32 N 4801.65 N 2346.63 E , 5916800,33 N Eastings (ft) 462379,69 E 462413.80 E 462449.42 E 462487.09 E 462525,47 E 462563.69 E 462606.23 E 462645.88 E 462687.73 E 462728.69 E 462768.76 E 462809.76 E 462848.6O E 462886.41E 462923.51E 462961.56 E 463000.40 E 463038.65 E 463O76,76 E 463115.28 E 463151.96 E 463188.32 E 463224.08 E 463259.99 E 463296.16 E 463331.08 E 463366.09 E 463403.29 E 463442.50 E 463479,14 E Dogleg Rate (°/100ft) 1.773 0.722 1.193 1.047 0.615 2,391 1.153 0.953 0,729 0.775 0.724 0.769 1.036 0.830 0,365 0.679 0.655 0.784 0.365 1.499 1,281 0.642 0.358 0.893 0,997 0,630 0.498 2.243 1.299 0,829 North Slope, Alaska Kuparuk 2N Vertical Section Comment 2828.46 2914,42 3OO2.33 3091.55 3180.25 3265,87 3357,13 3439.27 3525,49 3611.74 3696.76 3784.48 3870.28 3956.51 4O42.66 4130.53 4218.29 4304.80 4391.60 4478.63 4563.00 4649.30 4735,78 4821.82 4908.57 4994.44 5080.76 5168.03 5258.21 5344,38 23 July, 2001 - 1:40 Page 4 of 7 DrillOues! 2,0~. O&O05 Sperry-Sun Drilling Services Survey Report for 2N-302 Your Ref: 501032038000 Job No. AKMMllfOl, Surveyed: 9 July, 2001 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) 7434.51 66.030 26.500 4079.06 4232.69 7530.15 66.810 26.270 4117.32 4270.95 7626.38 65.810 27.270 4155.99 4309.62 7722.18 64,320 27.440 4196.37 4350.00 7817.52 64.550 27.100 4237.52 4391.15 7912.72 63.210 25.970 4279.43 4433.06 8011.04 63.340 25.830 4323.64 4477.27 8109.50 62.250 26.120 4368.66 4522.29 8204.71 61.380 24.720 4413.63 4567.26 8301.40 61.910 24.160 4459.55 4613.18 8396.94 59.980 24.290 4505.95 4659.58 8492.78 58.180 25.710 4555.19 4708.82 8591.18 55.540 25.840 4608.98 4762.61 8684.54 54.260 26.700 4662.66 4816.29 8780.33 53.040 26.370 4719.44 4873.07 8876,35 51.820 27.230 4777,98 4931.61 8972,36 49.740 26.370 4838.69 4992.32 9068,39 47.380 26.160 4902,24 5055.87 9165,75 45.170 26.630 4969,53 5123.16 9261,40 43.190 25.120 5038,13 5191.76 9357.29 42.950 24.630 5108.18 5261.81 9454.16 43.550 24.220 5178.73 5332.36 9548.39 43.660 23,940 5246.97 5400.60 9644,85 43.790 23,170 5316.67 5470,30 9741.11 43.410 22.000 5386.38 5540.01 9836.11 43.420 22.980 5455.39 5609.02 9932.67 44.270 22.350 5525.03 5678.66 10029.45 44.710 22,920 5594.07 5747.70 10124.04 44.930 22,890 5661.17 5814.80 10219.29 44.690 22,050 5728.74 5882.37 4880.85 N 2384.74 E 5916879.34 N 463517.65 E 4959.37 N 2423,69 E 5916957.66 N 463557.01 E 5038.04 N 2463.38 E 5917036.13 N 463597.10 E 5115.20 N 2503.30 E 5917113.08 N 463637.41 E 5191.65 N 2542.70 E 5917189.32 N 463677.21 E 5268.11 N 2580.89 E 5917265.59 N 463715.79 E 5347.11 N 2619.25 E 5917344.39 N 463754.55 E 5425.83 N 2657.60 E 5917422.91 N 463793.31 E 5501.62 N 2693.63 E 5917498.52 N 463829.72 E 5579,09 N 2728.83 E 5917575.80 N 463865.32 E 5655,25 N 2763.10 E 5917651.78 N 463899.98 E 5729.76 N 2797.83 E 5917726.12 N 463935.10 E 5803.95 N 2833.66 E 5917800.12 N 463971,30 E 5872.44 N 2867.46 E 5917868.44 N 464005.46 E 5941,47 N 2901.92 E 5917937.28 N 464040,28 E 6009.40 N 2936.23 E 5918005.04 N 464074.94 E 6075.78 N 2969.78 E 5918071.25 N 464108.82 E 6140.33 N 3001.63 E 5918135.63 N 464141.01 E 6203.35 N 3032.90 E 5918198.49 N 464172,60 E 6263.32 N 3062.01 E 5918258.31 N 464202.01 E 6322,72 N 3089.55 E 5918317.57 N 464229,86 E 6383.16 N 3116.99 E 5918377.86 N 464257,62 E 6442.49 N 3143.51 E 5918437.06 N 464284.44 E 6503.61 N 3170.15 E 5918498.04 N 464311.39 E 6564.90 N 3195.65 E 5918559.20 N 464337.21 E 6625.22 N 3220.62 E 5918619,39 N 464362.49 E 6686.94 N 3246,40 E 5918680,98 N 464388.58 E 6749.54 N 3272.50 E 5918743.44 N 464415.00 E 6810.96 N 3298.45 E 5918804,73 N 464441.27 E 6872.99 N 3324.11E 5918866.62 N 464467.24 E Dogleg Rate (°/100ft) 1.618 O.845 1.409 1.564 0.402 1.765 0.183 1.138 1.586 0.748 2.024 2.268 2.685 1.565 1.303 1.455 2.275 2.463 2.297 2.344 0.429 0,684 0.236 0.568 0.926 0.709 0.990 0,614 0.234 0.671 North Slope, Alaska Kuparuk 2N Vertical Section Comment 5432.27 5519.92 5608.04 5694.88 5780.87 5866.34 5954.16 6041.73 6125.64 6210.69 6294.15 6376.35 6458.74 6535.12 6612.26 6688.36 6762.73 6834.72 6905.07 6971.72 7037.19 7103.53 7168.48 7235.08 7301.33 7366.49 7433.25 7500.95 7567.52 7634.51 23 July, 2001- 1:40 Page 5 of 7 DrillQuest 2.f)O. 08.005 Sperry-Sun Drilling Services Survey Report for 2N-302 Your Ref: 501032038000 Job No. AKMM11101, Surveyed: 9 July, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 10297.00 44.690 22.050 5783.99 5937.62 6923.64 N 3344.62 E 5918917.17 N 464488.02 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 153.9' MSL. Northings and Eastings are relative to 5' FSL & 484' FEL. Magnetic Declination at Surface is 25.662° (13-Jun-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 5' FSL & 484' FEL and calculated along an Azimuth of 26.140° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10297.00ft., The Bottom Hole Displacement is 7689.17ft., in the Direction of 25.784° (True). Dogleg Rate (°/100ft) 0.000 North Slope, Alaska Kuparuk 2N Vertical Section Comment 7689.02 Projected Survey Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 838.31 835.06 44.22 N 23.03 E 10297.00 5937.62 6923.64 N 3344.62 E Comment Tie On to Gyros Projected Survey 23 July, 2001- 1:40 Page 6 of 7 Dr#/Quest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-302 Your Ref: 501032038000 Job No. AKMM11101, Surveyed: 9 July, 2001 Kuparuk River Unit North Slope, Alaska Kuparuk 2N Survey tool program for 2N-302 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 838.31 835.06 838.31 835.06 10297.00 5937.62 Survey Tool Description Tolerable Gyro (2N-302 Gyros) MWD Magnetic (2N-302 MWD) 23 July, 2001.1:40 Page 7 of 7 DrillOue,st 2.00.08.005 19-Jul-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-302 ~01- Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 10,297.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AU60Z 001 Ala~a Oil & Gas Cons. Commia~n PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. R. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 September 14, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED SEP 1.t ~ 2..001 Alaska Oil & Gas Cons, Commission Anchorage Subject: Completion Report for 2N-302 (201-115 / 301-179) Dear Commissioner Taylor: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kupamk well 2N-302. If you have any questions regarding this matter, please contact Brian Noel at 265-6979. C. R. Mallary Drilling Engineering Supervisor PAI Drilling CRM/skad 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 _ Other _ Change approved program _X Pull tubing _ Variance _ Pedorate _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_ RKB 35 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service _x Kuparuk River Unit 4. Location of well at surface 8. Well number 4' FSL, 485' FEL, Sec. 34, T10N, R7E, UM 2N-302 At top of productive interval 9. Permit number / approval number 1096' FSL, 2628' FEL, Sec. 26, T10N, R7E, UM (proposed) 201-115 At effective depth 10. APl number 50-103-20380-00 At total depth 11. Field / Pool 1715' FSL, 2326' FEL, Sec. 26, T10N, R7E, UM (proposed) Kuparuk River Field /Tarn River Pool 12. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 16" 200 sx AS I 155' 155' Surface Production Liner Perforation depth: measured RECEIVED true vertical JUN 2 9 2001 i Tubing (size, grade, and measured depth Aiaska 0il & Gas C~ns. Commlssl0n i Packers & SSSV (type & measured depth) Anchorage 13. Attachments Description summary of proposal__ Detailed operations program _ BOP sketch ~ Refer to attached morning drilling report for LOT test, surface cement details and detail schematic casing sheets, 14. Estimated date for commencing operation 15. Status of well classification as: June 29, 2001 16. If proposal was verbally approved Oil m Gas m Suspended __ Name of approver Date approved Service __X 17. I hereby edify that the foregoing is true and correct to the best of my knowledge. Questions? Brian Noel 265-6979 Signed ~.~. v~.~ C Title: Drilling Engineering Supervisor Date '~-._~ J"dm~J ~ Trantharn Prepared b? Sharon Al/sup-Drake _ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witneSSplug integrity__ BOP Test _ Location clearance_,.., I Approval n . .o,~ / . Mechanical Integrity Test _ Subsequent form required lo- ';''L "GNED ~y Commissioner Date .... A_pproved by order of the Commission .___:i:,, ~_.-.~. ...... : ........... Form 10-403 Rev 06/15/88 · ORIGINAL SUBMIT IN TRIPLI CATE RECEIVED JUN 29 2001 Alaska Oil & Gas Co'ns. Comml~Idn AnchorageKuparuk River Unit 2N-302 (wp03) MD !Pc ~im. SS~D ~D NIS ~ ~ ~ DLS V.S~ Comment (fl) (~g) (Deg~ (fi) (fi) (fi) . (fi) ...... (fi) ..... (fi) , (0~100~) , (fl) .... 0.00 0.00 0.00 -153.90 0.00 0.00 N 0.00 E 5912010.68 N 461107.74 E 0.00 SHL 400.00 0.00 0.00 246.10 400.00 0.00 N 0.00 E 5912010.68 N 461107.74 E 0.00 0.00 Begin Dir 900.00 10.00 30.00 743.57 897.47 37.69 N 21.76 E 5912048.26 N 461129.69 E 2.00 43.42 Increase Dir Rate 1217.25 19.52 30.00 1050.00 1203.90 107.60 N 62.13 E 5912117.96 N 461170.42 E 3.00 123.97 Base Permafrost 1233.33 20.00 30.00 1065.13 1219.03 112.31 N 64.84 E 5912122.66 N 461173.16 E 3.00 129.39 Increase Dir Rate 1497.45 29.22 28.29 1305.00 1458.90 208.40 N 118.09 E 5912218.47 N 461226.90 E 3.50 239.11 Top West Sak 2251.54 55.58 26.32 1857.00 2010.90 657.22 N 347.27 E 5912666.11 N 461458.38 E 3.50 742.99 Base West Sak (WSIO) 2516.35 64.84 25.94 1988.42 2142.32 863.35 N 448.33 E 5912871.71 N 461560.50 E 3.50 972.57 End Dir, Start Sail 2887.27 64.64 25.94 2146.10 2300.00 1165.27 N 595.16 E 5913172.88 N 461708.89 E 0.00 1308.30 7-5/8" Csg Pt. 3369.27 64.84 25.94 2351.00 2504.90 1557.61 N 785.97 E 5913564.23 N 461901.70 E 0.00 1744.57 C80 (K10) 3486.88 64.84 25.94 2401.00 2554.90 1653.35 N 832.53 E 5913659.73 N 461948.75 E 0.00 1851.03 Camp SS 6573.15 64.84 25.94 3713.00 3866.90 4165.53 N 2054.27 E 5916165.60 N 463183.39 E 0.00 4644.52 C50 7210.63 64.84 25.94 3984.00 4137.90 4684.43 N 2306.62 E 5916683.19 N 463438.40 E 0.00 5221.53 C40 (K5) 7631.70 64.84 25.94 4163.00 4316.90 5027,17 N 2473.31 E 5917025.08 N 463606.85 E 0.00 5602.65 C37 8157.54 64.84 25.94 4386.54 4540.44 5455.20 N 2681.47 E 5917452.03 N 463817.21 E 0.00 6078.61 Begin Dir 8527.56 57.44 25.94 4565.00 4718.90 5746.43 N 2823.10 E 5917742.53 N 463960.33 E 2.00 6402.45 Iceberg 8855.65 50.88 25.93 4757.00 4910.90 5985.49 N 2939.36 E 5917980.99 N 464077.82 E 2.00 6668.28 T7 9149.70 45.00 25.93 4953.90 5107.80 6181,73 N 3034.79 E 5918176.74 N 464174.26 E 0.00 6886.49 End Dir, Start Sail 9350.66 45.00 25.93 5096.00 5249.90 6309.53 N 3096.94 E 5918304.21 N 464237.06 E 0.00 7028.60 T3.1 9435.51 45.00 25.93 5156.00 5309.90 6363.48 N 3123.18 E 5918358.03 N 464263.58 E 0.00 7088.59 T3 9449.66 45,00 25.93 5166.00 5319.90 6372.48 N 3t27.55 E 5918367.00 N 464268.00 E 0.00 7098.59 Target- T1 (2N 302) 9576.94 45.00 25.93 5256.00 5409.90 6453.41 N 3166.91 E 5918447.73 N 464307.78 E 0.00 7188.59 T2 9823.01 45.00 25.93 5430.00 5583.90 6609.89 N 3243.01 E 5918603.82 N 464384.68 E 0.00 7362.59 C35 (K3} 10067.67 45.00 25.93 5603.00 5756.90 6765.47 N 3318.67 E 5918759.01 N 464461.13 E 0.00 7535.59 Albian Sand 10423.00 45.00 25.93 5854.26 6008.16 6991.43 N 3428.55 E 5918984.39 N 464572.18 E 0.00 7786.85 Total Depth PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P. O. BOX 100360, ATO-1482 ANCHORAGE, ALASKA 99510-0360 Telephone 907-263-4076 Facsimile 907-263-4966 Paul K. Wharton Sr. Landman June 28, 2001 via hand delive~ Mr. Mark Myers, Director Division of Oil and Gas Alaska Department of Natural Resources 550 W. Seventh Avenue, Suite 800 Anchorage, Alaska 99501 Re: Notification of Lease Operation 2N-302 Albian Tail Kuparuk River Unit Dear Mr. Myers: Phillips Alaska, Inc. ("Phillips"), for itself and on behalf of BP Exploration (Alaska), Inc., Union Oil Company of California, Exxon Mobil Corporation, and Chevron USA Inc., hereby notifies the Alaska Department of Natural Resources ("DNR") of its intent to drill an Albian tail from the Tarn 2N-302 well. The tail will be conducted as a lease operation to evaluate the Torok formation (the "Lease Operation"). Phillips anticipates commencing the drilling of the tail during the week of July 9, 2001. The Tarn 2N-302 well is scheduled to spud today. Phillips shall serve as Operator for the well and Lease Operation. Adding this tail onto the Tarn 2N-302 well will extend the originally planned total depth approximately 300' MD. The well with Albian tail will be drilled and cased to a projected depth of 5854' SS TVD or 10,423' TMD from the existing 2N pad located on ADL-375074 to a bottomhole location within the leased area of ADL- 380053 as follows: Surface Location: Target Location: TD Location' 5' FSL and 484' FEL of Section 34, T10N-R7E, UM 1096' FSL and 2628' FEL of Section 26, T10N-R7E, UM 1715' FSL and 2326' FEL of Section 26, T10N-R7E, UM The purpose of extending this well is to log and evaluate the upper Albian interval in the Tarn area. If the evaluation of this interval shows it contains an economical accumulation, additional drill wells and/or testing may be conducted. Phillips Alaska Inc. is a Subsidiary of Phillips Petroleum Company Mr. Mark Myers June 28, 2001 Page 2 The lease is owned by the working interest owners in the Greater Kuparuk Area pursuant to the Greater Kuparuk Operating Agreement in the percentages outlined below: PAl 55.293767% BPX 39.282233% Unocal 4.950600% Exxon Mobil 0.364800% Chevron 0.108600% Please accept this letter of notification of the Lease Operation and do not hesitate to contact Chip Landmesser at 265-6384 or the undersigned at 263-4076 with any questions you may have. After the drilling of the tail, Phillips will inform DNR of our findings and outline our plans for the tail. Phillips requests DNR to give this matter its expedited consideration as the well will spud June 28, 2001, and the tail is scheduled to be drilled within two and one-half weeks of spudding. Phillips regrets the late notice, but only received necessary partner approval as of June 27, 2001. Very truly yours, ' Paul K. Wharton Sr. Landman CC: Mr. Mark Bly, BP Exploration (Alaska) Inc. Ms. Karen Lauder, Union Oil Company of California Mr. Wade G. Fennel, Chevron U.S.A., Inc. Mr. Rob G. Dragnich, Exxon Mobil Corporation Mr. Mark Myers June 28, 2001 Page 3 bcc: Dallam Masterson ~>~;hip Landmesser 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 June 29, 2001 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 29 2001 Alaska 0il & Gas Cons. Commission Anchorage Subject: 2N-302 Application for Sundry Approval (APD 201-115) Dear Ms. Commissioner: Phillips Alaska, Inc. hereby files this Application for Sundry Approval to change the approved program (20 AAC 25.015 (b2)) and drill an Albian tail from the Tam 2N-302 well. The permitted TD is 10,123' MD (5796' TVD). Nabors 16E began drilling surface hole June 28, 2001 and expects to be at TD on or before July 9, 2001. To drill and log the Albian sands will require an additional 300' MD (212' TVD) beyond the permitted TD, holding the 45 deg. angle. The 5-1/2" by 3-1/2" long string will be run to the deeper TD and cement volume increased by 90 sacks, thus isolating the Albian from the shallower objective Bermuda (T3 and T2) sands. At this time there are no plans to perforate and test the Albian. This extension tail is requested to further evaluate the Albian interval, which was penetrated approximately 1 mile to the southeast in 1991 by the Bermuda 4/1 (Tam discovery well). The Bermuda #1 well drilled through the Bermuda and Albian sections with 10.0 ppg LSND mud without problems. This gradient of 0.52 - 0.53 psi/ft (reservoir pressure plus trip margin) indicates no abnormally pressured intervals were encountered and matches the expected pressure for the 2N-302 well (2600 psi at 5310' TVD = 0.49 psi/ft for the Bermuda. There are no faults mapped between the Bermuda #1 and the 2N-302 well. The prognosed TD for 2N-302 with the Albian tail is 10,423' MD (6008' TVD) at a BHL of 1715' FSL and 2326' FEL of Section 26, T10N, R7E, UM. See attached letter of notification to DNR. If you have any questions regarding this matter, please contact me at 265-6434 or Brian Noel at 265- 6979. Si,,,~erely, ------~ .. J .x,lrantlaam Drilling Engineering Supervisor ORIGINAL [Fwd: Change to approved 2N-302 permit to drill] Subject: [Fwd: Change to approved 2N-302 permit to drill] Date: Thu, 5 Jul 2001 17:12:26 -0800 From: "Brian D Noel" <bnoel@ppco.com> To: tom_maunder@admin.state.ak.us Tom - Here's the email correspondence trail deepening 2N-302. Jane left sundry with Bob Crandall. Thanks - Brian Michael D Erwin 07/02/01 08:08 AM To: Sharon Allsup-Drake/PPCO@Phillips cc: W Dallam Masterson/PPCO@Phillips Subject: [Fwd: Change to approved 2N-302 permit to drill] Sharon, Look like this came to me by mistake. Mike Erwin 907/265-1478 (office) 907/240-5817 (cell) ..... Forwarded by Michael D Erwin/PPCO on 07/02/01 08:10 AM ..... Jane Williamson <Jane_Williamson@admin.state,ak. us> 06/29/01 04:39 PM To: Julie M Heusser <julie_heusser@admin.state,ak.us>, Robert E Crandell <robert_.crandell@correct.state.ak. us>, Michael D Erwin/PPCO@Phillips CC: Subject: [Fwd: Change to approved 2N-302 permit to drill] Julie, I have this 403. Assuming this doesn't require spacing exception, recommend approval, i am puffing in Bob's box for his Iooksee. Needed by July 9. Jane ..... Message from "Brian D Noel" <bnoel@ppco.com> on Fri, 29 Jun 2001 13:34:09 -0800 ..... To: jane_wiiliamson@admin.state.ak, us Subject: Change to approved 2N-302 permit I of 4 7/§/01 2:35 PM [Fwd: Change to approved 2N-302 permit to drill] to drill Jane - Yesterday, exploration group finally decided they wanted the Albian tail on 2N-302. Well spudded thursday 6/28 and now drilling surface hole at 1200'. As discussed earlier, am sending sundry to extend permitted TD by 300' md with cover letter outlining details from email below. Estimate being at original TD by monday 7/9. Let me know if any additional information will be required. Thanks - Brian 265-6979 .... Forwarded by Brian D Noel/PPCO on 06/29/01 12:52 PM ..... Brian D Noel 06/20/01 04:33 PM To: Tom Maunder <tom_maunder@admin.state.ak.us> cc: Subject: Change to approved 2N-302 permit to drill(Document link: Brian D Noel) Hello Tom- Well's permitted TD = 10,123' md (5796' tvd). To drill through the Albian sands (discussed below) would require an additional 300' (212' tvd) assuming hold 45 deg angle. No fault crossings are prognosed to drill the extra 300'. The Bermuda #1 well was drilled in 1991 with 10 ppg LSND mud through the Bermuda and Albian section and 10.2 ppg LSND for the Kuparuk. This mud weight gradient of 0.52 - 0.53 psi/ft (reservoir pressure plus trip margin) indicates no abnormally pressured intervals were encountered and matches the expected pressure for the 2N-302 well (2600 psi at 5310' tvd = 0.49 psi/ft for the Bermuda. What will be needed to amend the permit for the deeper TD? Latest estimate for spud is this friday 6/22 and expect 2 weeks to reach TD. Leaving office now, but I'll be in all day tomorrow. Thanks - Brian Tom Maunder <tom_maunder@admin.state.ak.us> 06/08/01 03:35 PM To: Brian D Noel/PPCO@Phillips 2 of 4 7/6/01 2:35 PM [Fwd: Change to approved 2N-302 permit to ddll] · Subject: Re: Albian in Bermuda #1 area wells Brian, I will have to check. You can probably make a good case given the proximity to Bermuda #1. Key point might be if there are any faults involved. Talk to you Monday. Tom Brian D Noel wrote: > Hello Tom. > Finally received some information, right after Sharon sent the APD for > 2N-302 (Tarn development well) out this morning! As we discussed Nabors > 16E will be moving to 2N pad sometime next week and possibly ready to spud > 2N-302 as early as 6/15. > The deeper target of interest is listed below but was not included in > 2N-302 APD. The Bermuda #1 well (vertical hole drilled jan 1991) is <1mile > from 2N-302 BHL. Also plan to drill 2N-304 next and it's BHL is right > next to Bermuda #1. Given the close proximity, would these "tails" still > be considered exploration and thus require the more detailed, regional > information package or would including data from Bermuda #1 be sufficient > to permit the deeper target? > As noted, I'!1 know more by noon tuesday, but understanding what additional > information APD requires will help pressure a commitment. > > Thanks. Brian > ....Forwarded by Brian D Noel/PPCO on 06/08/01 02:31 PM ..... > Albian in Bermuda #1 area wells > All, > A TO 1217 is reserved from 10-11:30 on Tuesday, June 12, to discuss the > proposed Albian tails in the upcoming Tarn 2N wells near the Bermuda #1 > well. Bermuda #1 penetrated Albian sandstones with potential pay based on > the porosity, permeability, and oil shows in some rotary SWCs. As currently > envisaged, the Albian tails in one or both Tam wells would simply be > MWD-Iogged extensions of a few hundred feet below the normal rathole for > the Bermuda interval, and would be funded by the GKA. We need to discuss > possible additional data acquisition or testing. 3 of 4 7/6/01 2:35 PM [Fwd: Change to approved 2N-302 permit to drill] > Regards, > Da/lam Masterson > Manager North S/ope Satellite Exploration > Ph~71ips Alaska,/nc. > 700 G St., A TO 14 76 > Anchorage, AK 99510 > wmaster~ppco, com > 907-265-1138 (office), 263-4966 (fax) (See attached file: tom_maunder.vcf) (See attached file: tom_maunder, vcf) Tom Maunder <tom maunder~admin.state.ak, us> Petroleum Engineer Alaska 0~ and Gas Conservalion Commission 4 of 4 7/6/01 2:35 PM ALASKA OIL AND GAS CONSERVA ION C0PI ISSION James Trantham Drilling Engineer Supervisor Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TONY KNOWLES, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re.' Kupamk River Unit 2N-302 Phillips Alaska Inc. Permit No: 201-115 Sur Loc: 5' FSL, 484' FEL, SEC 34, T10N, R7E, UM Btmhole Loc. 1524' FSL, 2419' FEL, SEC 26, T10N, 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 of the Permit to Drill apPlication for KRU 2N-302. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on KRU 2N must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerelv.~' ..~ ~ Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this .].5~ay of June, 2001 jjc/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ii' STATE OF ALASKA "ii' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work: Drill [~] Redrill U Re-entry E] Deepen F~I Service E] Development Gas E] single Zone [~ Multiple Zone r~ 2. Name of operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 35 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 AD L 380053 ALK 4601 Tarn River Pool 4. Location of well at sudace 7. Unit or properly Name 11. Type Bond (see 20 AAO 25.0251) 5' FSL, 484' FEL, Sec. 34, T10N, R7E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1096' FSL, 2628' FEL, Sec. 26, T10N, R7E, UM 2N-302 # 59-52-180 At total depth 9. Approximate spud date Amount 1524' FSL 2419' FEL, Sec. 26, T10N, R7E, UM June 15, 2001 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1096 @ Target feetI 2N-303 14' @ 500' feet 2560 10123' MD /5796 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) !Kickoff depth: 400' MD Maximum hole angle 64.8° Maximum surface 2018 psig At total depth (TVD) 2602 psig 18. Casing program Setti%l Depth size Specifications Top Bottom Quantity of Cement Hole Casin~l Wei~lht Grade Couplin~ LenCh MD TVD MD TVD /include sta~le data/ 24" 16" 62.5# H-40 Weld 120' 35' 35' 155' 155' 350 sx AS 1 9.875" 7.625" 29.7# L-80 BTCM 2852' 35' 35' 2887' 2300' 300 sx AS Lite, 240 sx Class G 6.75" 5.5" x 15.5# L-80 LTC-Mod& 9215' 35' 35' 9250' 5179' 60 sx Class G, 240 sx Cl. G Gasblok 6.75" 3.5" 9.3# L-80 EUE 8rd Mo( 873' ~ ~ 10123' 5796' included above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) tree vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface ' · Production 'P 'E£E!VE D Liner Perforation depth: measured ~,~S~ 0i[ & {~8.S O'0','~S. ~0i't'~'ii~iSSJ0L tree vertical Anchorage ~o. Attachme.ts Fi,ng fee ~ Prope~j P~at I--! E~OP Sketch I--! Dive,er Sketch r"l Dri,ing program 1'71 P,,ing,~id program [71Time vs depth p~ot FIRefractio. a.a~ysis FI Se~ed repo, FI *OAAC ~.o~0 requireme.ts I--I 21. I hereby cel tify that the foregoing is true and correct to the best of my knowledge Questions? Brian Noel 265-697(, Signed j %._.~¢arnes Trantham Prepared hv Sharon A/Isut~-Dral¢~ Commission Use Onl) Permit Number I APl number I Approvaldate ~/,~F//~,,~.-/~.~ ISee cover lottor ~'~ / - //5- ~o- / o.9 - ~ o 3-~O l If°r other requ,rements Conditions of approval Samples required E] Yes J~ No "- Mudlog required /' / E] Yes J~ No Hydrogen sulfidemeasures E] Yes ,,~ No Directional surveyrequired ~ Yes E] No Required working pressure for BOPE D2M; r-] 3M; r'~ 5M; r'~ 1oM;r-] Other: ORI~IN~I $IGNED By Commissioner the commission Date Approved by Form 10-401 Rev. 12/1/85 · Submit in triplicate t, Appli~' ",n for Permit to Drill, Well 2N-302 . Revision No.0 Saved: 8-Jun-01 Permit It- Kuparuk Well 2N-302 (Tarn) App/icat/on for Perm/t to Dr///Document MaxWell !~10 x i ~ i z E Well VoluE Table of Contents lw 1 m m Si Sm 1 el gm 10. 11. 12. 13. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ........................................................................................................ 2 Location Summary ................................................................................................... 2 Requirements of 20 AAC 25. 005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ........................................................................................................ 2 Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25. 005(c)(3) ................................................................................................... 3 Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25. 005 (c)(5) .................................................................................................. 3 Casing and Cementing Program ............................................................................. 3 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 3 Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25. 005(c)(7) ................................................................................................... 4 Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25. 005(c)(8) ................................................................................................... 4 Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25. 005 (c)(9) .................................................................................................. 5 Seismic Analysis ...................................................................................................... 5 Requirements of 20 AAC 25. 005 (c)(10) ................................................................................................ 5 Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25. 005 (c)(11) ................................................................................................ 5 Evidence of Bonding ................................................................................................ 5 Requirements of 20 AAC 25. 005 (c)(12) ................................................................................................ 5 Proposed Drilling Program ...................................................................................... 5 2N-302 PERMIT IT. DOC 0"~' ' ~L Page,of6 t .~ ~. ~ Printed: 8-Jun-01 14. 15. Appli ' -q for Permit to Drill, Well 2N-302 Revision No.O Saved: 8-Jun-01 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 Attachments ............................................................................................................. 6 Attachment I Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards ............................................................................................. 6 Attachment 3 Well Schematic .............................................................................................. 6 1, 1 Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator'and a unique AP[ number ass/~gned by the commL~sion under 20 AAC 25'~ 040(b). ~r a well with multiple well brand~e.~ each bh~nch must similarly be ide/~tified by a unique name number by adding a suffix to the name des/~nated for the wall by ~he operator and to the number a.;.~gned to the well by c~mmisdon, The well for which this application is submi~ed will be designated as 2N-302. Location Summary Requirements of 20 AAC 25.005(c)(2) An application fbi' a Permit to Dr/it rnust be accompanied by ead~ of' the fbllowirLq items; except for an item a/ready on file with tl~e commLesion ,~nd identified in the application: (2) a p/at identifying the property and the propeztyb owner~ ,~nd showing (A)the coorWinatz~.~ of the proposed location of #ze well at' the surface, at the top o5 each d~jecb'v~z fbrmation, and at total depth, f~fi~renced to .government;~/ section (B) the coordinates of the pmpo~d location of the well at the sudace, rel~renced to the s~te plane cz~ordinat~ .~ysZ~n'~ for this stat~ as maintained by the National Geodelic 5~ey in ~he National Oceanic and Atmos~heric Administration; (~) the proposed depth caf ~he well at the top of each otEec~ive tbrrnation and at lz~tal depth; Location at Surface I 5' FSL~ 484' FEL, Sec 34~ T10N~ R7E~ UM NG$ Coordinates RKB Elevation l 153.9' AIVlSL Northings: 5,912,010.7 Eastings: 461,107.7 Pad E/evationI 119.3' AMSL Location at Top of 1096' FSL, 2628' FEL, Sec 26, T10N, R7E, UM Productive Interval (Kuparuk "A3" Sand) NGS Coordinates Measured Depth~ RKB: 9450' Northings: 5,918,367 Eastings: 464,268 Total Vertical Depth, RKB: 5320' Total Vertical Depthz SS: 5166' Location at Total Depth 1524' FSL, 2419' FEL, Sec 26~ T10N, R7E, UM NGS Coordinates Measured Depth~ RKB: 10,123' Northings: 5,918,794 Eastings: 464,478 Total Vertical Depth~ RKB: 5796' Total Vertical Depth~ SS: 5642' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AA C 25. 050(b) If ,.~ well is to be intentionally devi~Tted, the apptic~tion for a Permit to Dr/ti (Form 10-.¢01) must (Z) include a pk~t; drawn ~o ,~ .euiZ~ble so~le, showing the path of the proposed wellborn./i~dudin,q dl adjacent we#bores w/thin 200 feet' of any portion of the propo.~ed ~el~' Please see Attachment 1: Directional Plan 2N-302 PERMIT IT. DOC Page 2 of 6 Printed: 8-Jun-01 ~ Appli9 ...... ~n for Permit to Drill, Well 2N-302 ~1 Revision No.0 Saved: 8-Jun-D1 1 . 1 . and (2) for afl ;veils within 200 feet o? the proposed wellbore (A) I/st the name.~ of the operators of those we/is, to the extent that' tho.~'e names are known or discoverable in public records, and W~ow that each named operator ha¢ been f~nished a copy of the application by ~rtified mail; or (B) ¢tate that the applicant is the only affected owner. The Applicant is the only affe~ed owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25. 005(c)(3) An application for a PemTit to Drill must be adwompanied by each of the following/tem~ except for an item a/rea~y on file ~v/t/~ the comm/~.~ion and identified in the application: (3) a diagram and desc/Yption of the blowout prevention equipment (BOPE) a~ /~quired by 20 AAC 2S. 03~ 20 AAC 2S. 03~ or 20 AAC 2~ 0~ as applicable; Please reference BOP schematics on file for Nabors ~6E. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application fo/' a Permit to Dr/II must be accompanied by each of the lb/lowing item, s; except for an item Wready on file v/it/~ the commis~Yon and identified in the appli4~'~tion: (,t) intb/TT~ation on dr/il/nE haza/'d.$ fiTcluding (A) the maximum downho/e pressur~ that may be encountere~ critenT~ u.~ed to determine i~ and max/mum potential surfi~ce pt'e~.~ure ba~ed on a methane Based on offset well data, the expected reservoir pressure in the T3 Bermuda sand for the Tarn well 2N- 302 is -2600 psi at 5310' tvd, 0.49 psi/It or 9.4 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) while drilling 2N-302 is calculated using above reservoir pressure, a gas gradient of 0.11 psi/fi, and top of the T3 Bermuda sand target at 53:[0' tvd: MPSP =(5310 ct)*(0.49- 0.11 psi/fi) = 2018 psi data on pot~:ntial gas zones;' The well bore is not expected to penetrate any gas zones. and (C) data concerning potential ~:~uses of hole problems .~'uch a.s' abnormally 9eo-pz'e~'sured st'ra~, to.st drcu/a~fon zone~; and zones that have a propensity for different/a/sticking/ Please see Attachment 2 - Drilling Hazards Summary Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application fbr a Permit to Dr/Il must be accompanied by e,?ch of the th/lowing item~ except for an item already on file w/th the commission and identified fi7 the application; (LS) a descript/dn of the procedure tbr conducb)~g format/bn iflt~q~ity te.s't:% a.s' required under'20 AAC.ZS; Drill out surface casing shoe and perform LOT test or F:[T (maximum of 16 ppg ENW) in accordance with the Kuparuk LOT/F:[T procedure, that Phillips Alaska has on file with the Commission. Casing and Cementing Program Requirements of 20 AA C 25. 005(c)(6) An application fbz' a Permit to Dr/Il must be accompanied by each of the fbi/owing item~ except for an item already on fife w/th the c~nmi~qion and identified fi7 the application: (d) a complete proposed casJfLq and cementing program as required by 20 AAC 2.5~ 0.~0, and a description of any .¢lotted liner; pre.- per~rated /ine~ or screen to be installe~' 2N-302 PERMIT IT. DOC Page 3 of 6 , ~. ~ ~,nrd: 8-Jun-D1 1 am ,. ?..~ Appli .' ',n for Permit to Drill, Well 2N-302 . Revision No.O Saved: 8-Jun-01 Casing and Cementing Program J Hole Top Btm - Csg/-I'bgSize Weigh Length MD/I'VD MD/I-VD OD (in) (in) t (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program _ ::[6 24 62.5 H-40 Welded 120' 35'/35' :[55'/155' 350 sx 15.8 ppg AS1 7-5/8 9-7/8 29.7 L-80 BTC 2852' 35'/35' 2887'/2300' Lead: 300 sx :[0.7 ppg AS Lite Tail: 240 sx :[5.8 ppg 'G' w/add. Planned TOC=Surface 5-1/2 x 6-3/4 15.5 L-80 BTC-Mod 92:[5' 35'/35' 9250'/5:[79' Lead: 60 sx 13 ppg'G' 3-1/2 9.3 L-80 EUE 8rd 873' 9250'/5179' :[0,::[23'/5796'w/add. Mod Tail: 240 sx 15.8 ppg 'G' w/Gasblok Planned TOC=8528' 3-1/2 9.3 L-80 EUE 8rd 9250' 35'/35' 9250'/5179 ' Nod Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application/'or' a Per/nit to Drill/nustbe accomp~.~nied by each of the ~//owing ite/n.~ e~ept' for an item already o~ file w/th the con~mL¢.¢ion and identified in the applic,~tion: (7) a diagram and desz:~'iption of the diver~er s%~tem as required by 20 AAC 25'~ 035, unle~:~' ~his requirement is' waived by the ~z~n?n'Hstsion under 20 Please reference diverter schematic on file for Nabors 16E. Drilling Fluid Program Requirements of 20 AA C 25. 005(c) (8) An application fbr a Pern#t to Dr/II must bf., accompanied by each o/' the fbi/owing item~5 except tbr an item already on file w/th the commLs:s'ion and identified in the application: (8) a dril#ng fluid pr(?.gram, including a alia. qram and ciescriptk~z? of #ze drilling tTuid.~ysfen?, a.~ r~quired by 20 AAC.25;03.~' Drilling will be done using mud systems having the following properties: Spud to surface Dr/Il out cas/nE point to TD Extended bentonite slurry LSND Density (ppg) 9.5-10.2 9- :[ 0.5 Funnel Viscosity(sec) 50-120' 35-50 Yield Point (cP) 25-35 5-20 Plastic Viscosity (lb/lO0 sf) :[ 6- 26 6- 20 10 sec. Ge/(lb/lO0 st) :[0-20 2-6 ~0 min. Gel (Ib/~O0 sf) 1S-40 4-8 APZ Filtrate (cc) 7-:[5 <6 through pay pH 9.5-:[0 9-10 So/ids (%) +__ 10 < 11 *Spud mud should be adjusted to a FV between 100-:[20 sec/qt to drill gravel beds Diagram of Nabors 16E IVlud System on file. 2N-302 PERMIT IT. DOC 0 R,I C LrintedP:agS'eJ4unO'fO~ ,~, Applic,~ "-n for Permit to Drill, Well 2N-302 ~ ~ Revision No.O Saved: 8-Jun-O1 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 1 Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Dr///must be accompanied by each of the following items, except for an item a/ready 0/7 file with the commission and identified in the application; (9) for an ezp/orator? or stratigraphic test we/l, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 2~.033(0; N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Dx#1 must be accompanied by each of the fo/lowing items, except for an item already on file with the commis.don and identified in the application: (ZO) for' an exploratory or stratigrapt#c t'e.~t we/I, a seismic refraction or reflection analysis a.~ required by 20 AAC N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application fo/' a Pern'#t' to Dr///must be ac~¥)mpanied by each of the fbi/owing itEn?5; except for an item a/ready on file with the commission and identified in the app/i~'~tion: (1.l) for ~ well dr/lied fi'om an offertory, plattbrm, mobile bogom-fbunded sb'u~?ur~b jack-up rig, or floating drilling v~L~'se~ an analysis of seabed conditions as required by N/A - Application is not for an offshore well. 12, Evidence of Bonding Requirements of 20 AAC 25. 005 (c)(12) An application fbr a Permit' to Drill must be accompanied by each of the follow/?~7 items, except for an item a#~ad? on file with the commis:f#on and identified in the applicatior~ : (~2) evidence s'how#~g that' the requirements of 20/lAd' 25; [)25' t"Bond#~g½have been meC Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application fbr a Permit to Df///mu.¢t be accompanied by each of the to/lowing item~ except for an item a/ready on file with the commi~qion and ide/?tified in the applioatio/~: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Nabors 16E. 2. Install diverter system. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. 4. Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry and pump adequate excess to ensure cement reaches the surface. If cement does not circulate to surface, perform stage or top job. Install and test BOPE to 5000 psi. Test casing to 2,000 psi. 5. Drill out cement and 20' of new hole. Perform LOT/FIT, but do not exceed 16.0 ppg EHW. 6. Drill 6-3/4" hole to TD according to directional plan. Run LWD logging equipment with GR, resistivity, density-neutron tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 7. Run and cement 5-1/2" L-80 BTC-Mod Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 8. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 9. Set TWC and ND BOPE. Install and pressure test production tree. 2N-302 PERMIT IT. DOC Page 5 of 6 O R ~l~,~ i ~ ~ ~,t' ~ ~ *~ Lnted: 8'Jun'01 .... , Appli,~ "~n for Permit to Drill, Well 2N-302 it f~ Revision No.0 Saved: 8-Jun-O1 10. Secure well. Rig down and move out. 11. Handover well to Operations Personnel. Note: Cement quality log and NTT will be run after rig moves off well. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25. 005 (c)(14) An application for a Permit to Dr/1/mustc be ac'companied by each of the fo/lowing/terns, except for an item a/ready on fee with tile commit'sion and identified in the application: (Z4) a genera/description of how the operator plan.¢ to dispose of'riff/ling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for' an annular disposa/ operation in the well,; Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 2N pad or hauled to a KRU Class ]:! disposal well. All cuttings will be disposed of either down a permitted annulus on 2N pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit 2N-302 for annular pumping of fluids occurring as a result of future drilling operations on 2N pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. 2N-302 PERMIT IT. DOC 6of6 ORI ' 8-Jun-01 .~ I~ J~ ~ ~?ntedF.a.ge Be~in Dir @ 2.0°/100R (i~] 9--7,/8~' Hole): 400.00f~ MD, 400.00'a TVD increase in Dir Rate @ 3.0°/100ff: 900.00ft MD, 897.47ft TVD ~ncrease in Dir Rate @ 3.5°/100ft : 1233,33ft MD, 1219.03ft TVD End Dir, Start Salt @ 64.842°: 2516.35ft MD, 2142.32ft 'FVD No~h S~ope, Alaska Kuparuk River Unit 2N Pad 2N 302 (wp02) J 1 1 T- [ (1524' PSI;- & 241.9'F~L, S~C 267T!0N: R7E) , {) 1000 2000 3000 4000 Scale: linch = 1000fi; Sect on Azimuth; 26 141" (TFue Nod:h) 5000 8000 7000 8000 9000 prelpared by: Bate/Time: ~hacked: ¢,pproved: Dave Egedah~ 24 May, 200~ - 7:34 ; North Slope, Kup~ruk River U~it 2~ P~d N i~efere~'~ce s TrJe North Current We~l Properties We[f: 2N-,302 Plan Hndzonta~ Cooldinates: Ref. Global Coordinates: 5912010,68 N, 461107 74 E Ref Structure: 72.21 N, 306,68 E Ref. Geographical Coordinates: 70° I0' 14.0030" N, 150° 18' 46.84t 6" W 5' FSL & 4~' FEb Sec. 34 - T10N - R7E RKB Elevation: 153.90ff above Mean Sea Level j Nodh Reference: True DdJlQ uesl 2 O0 ogeE)t Tota~ Depth: I0,123.00ft MD, 5796.03ft TVD (I 524' FSL & 2419' FEL, SEC. 26 - T10N - R7E) End Dir, Start Sail @ 45,000°: 9149,70ff MD Begin Dir @ 2.0°/'100tt: 8'¢57 54ft MD, 4540.44ft TVD~f-'-~/ / 75OO 8000 45OO 3000 %5/8" Csg Pt ... Drill 6 3/4" Ho~e te TE~ k t 500 End Dir, Stair Sail @ 64.842°: 2516.35ff k~crease ~n D~r Rate ~ 3.5'¥100~ : 1233.33ff increase ~n Dir Rate ~ 3.O°/100fl: 900~OO~ MD, 897.47fl TVD Begin D~ ~ 2.0°t100~ {~n 9-718" Hole): 400.00ff MD, 400.O0ff TVD e SNL: X ~* 4! 0774 E & ¢ = 58120~0 68' N0 1500 3000 (5r FS~ & 484' FEL, Sec ;~ ~ Scale: linch = 1500ff Kuparuk River Unit North Slope, Alaska Kuparuk 2N, S!ot~,~ 2N-302 ...... N~302Wp02 0 SA L REP OR T .......... ....... ,x::?i~ ,~: 7 June, 2001 Your Reft Per Phillips 'In House' Prelim Plan Ver. #1 Surface Coordinates: 5912010.68 N, 461107.74 E ('i0' 10' 14.0030"N, 150° 18'46.8416" W) Surface Coordinates relative to Project H Reference: 912010.68 N, 38892.26 W (Grid) Surface Coordinates relative to Structure: 72.21 N, 306.68 E (True) Kelly Bushing: 153.90ft above Mean Sea Level Proposal Ref: pro9556 Sperry-Sun Drilling Services Proposal Report for 2N-302 Plan - 2N-302 wp02 Your Ref: Per Phillips 'In House' Prelim Plan Ver. #1 Revised: 7 June, 2001 Kuparuk River Unit Measured Depth Incl. (ft) 0.00 0.000 0.000 Sub-Sea Vertical Depth Depth (ft) (ft) -153.90 0.00 100.00 0.000 0.000 -53.90 100.00 200.00 0.000 0.000 46.10 200.00 300.00 0.000 0.000 146.10 300.00 400.00 0.000 0.000 246.10 400.00 500.00 2.000 30.000 600.00 4.000 30.000 700.00 6.000 30.000 800.00 8.000 30.000 900.00 10.000 30.000 30.000 30.0~;i~;~i~: ~!ii~i938.3~i~i~ii~:' 1092.25 445.94 599.84 ..::..............:.........:: .. .... :.:~.:.-~:~...~ 545.55 699,45,~::~;ii:;:i':'~'' '~i:::;i::.i:i;:~::::-~ "':'":::;1:3:~59 N 644.80 .798i~0:'ii~::!i??:.i?'~"~:i-i:'.i.::::-:i::...:::~:~::_ .~::~: ~'?i4 N 743.57 :~:i;i;;;-;:89~7 "~"~':?i:~:;:;;:-:-?:i;:.:i~::i:.': 37.69 N .... :.:':.:..:.:iii;:i;iii:i~4'~'~i~~ .... ~::i.~ii:i';':'~ 995.45 54.96 N 76.64 N 1000.00 13.000 1100.00 16.000 1200.00 19.000 3~ 0 ":~i~iiiii~, ~'~3.71 1187.61 1217.25 19.518~::~i~ii~i~ii;iiii~:30~090 .iiiii~ii~ 1050.00 1203.90 1233.33 ......... 20.~i~! ...... ~i30.O00?~i~ 1065.13 1219.03 1300.00ii~iiiiiiiii!!ii~::~3~:. ~;~iii!ii!~.~ 29.442 1127.30 1281.20 1497.457~ 29.217 28.286 1305.00 1458.90 1500.00 29.306 28.274 1307.23 1461.13 1600.00 32.800 27.864 1392.88 1546.78 Local Coordinates Northings Eastings (ft) (ft) 0.00 N 0.00 E 59120.~[D~.68 N ..:.~ .. ~-.-~.~..~.:. :-::, ...... ':";~ ii~{~ii'. ~"~'~-:'.~::~ 0.00 N ":~00 E?:? :'~:::591~:.0.68:N 0.00 N ..-:.:':/::'::;:;:::,:-::'... ~0O E ..:,:;i':'759;~:20~0.68 N 0.00 N .~':'~:~-.::.::::.:. ........ ':'::~:':~:::0.'O~:E 't'::::~::?~..~..~2010.68 N ..... .. ~:.?.~:.?:,~ ::. ?-~ : :.~.. .... . ..... :'..'.:';-.'.:. ~.. '.':::.:..~:~::.:..;...:.. ~":.:::::~"~:':*:': 0.87 E 59~20~2.~9 N 3.49 E 5912016.71 N 7.85 E 5912024.23 N 13.94 E 59120~.75 N 21.76 E 5912048.26 N 102.68 N 107.60 N 112.31 N 133.21 N 168.85 N 208.4O N 209.50 N 255.01 N 31.73 E 5912065.47 N 44.25 E 5912087.09 N 59.28 E 5912113.05 N 62.13 E 5912117.96 N 64.84 E 5912122.66 N Global Northings Vertical Section 0.00 461107.74 E 0.000 0.00 461107.74 E 0.000 0.00 461107.74 E 0.000 0.00 461107.74 E 0.000 0.00 461108.62 E 2.000 1.74 461111.26 E 2.000 6.96 461115.66 E 2.000 15.66 461121.80 E 2.000 27.82 461129.69 E 2.000 43.42 461139.75 E 3.000 63.31 461152.38 E 3.000 88.29 461167.55 E 3.000 118.29 461170.42 E 3.000 123.97 461173.16 E 3.000 129.39 76.77 E 5912143,50 N 461185.19 E 3.500 153.41 96.59 E 5912179.03 N 461205.20 E 3.500 194.13 118.09 E 5912218.47 N 461226.90 E 3.500 239.11 118.68 E 5912219.56 N 461227.49 E 3.500 240.36 142.94 E 5912264.95 N 461251.99 E 3.500 291.90 North Slope, Alaska Kuparuk 2N Comment SHL: X = 461107.74' E & Y = 5912010.68' N (5' FSL & 484' FEL, Se 34-T10N-R7E) Begin Dir @ 2.0°/100ft (in 9-7/8" Hole 400.00ft MD, 400.00ft TVD Increase in Dir Rate @ 3.0°/100ft' 900.00ft MD, 897.47ft -I-VD Base Permafrost Increase in Dir Rate @ 3.5°/100ft · 1233.33ft MD, 1219.03ft TVD Top West Sak ~-- - 1700.00 36.295 27.525 1475.24 1629.14 1800.00 39.790 27.238 1553.98 1707.88 1900.00 43.286 26.990 1628.82 1782.72 2000.00 46.783 26.773 1699.48 1853.38 2100.00 50.280 26.579 1765.69 1919.59 305.22 359.93 418.95 482.05 549.00 169.28 E 5912315.02 N 461278.59 E 3.500 348.58 197.62 E 5912369.59 N 461307.20 E 3.500 410.18 227.83 E 5912428.45 N 461337.72 E 3.500 476.47 259.81E 5912491.39 N 461370.03 E 3.500 547,21 293.44 E 5912558.16 N 461404.00 E 3.500 622,13 June, 2001 - 12:08 Page 2 of 8 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for 2N-302 Plan - 2N-302 wp02 Your Ref: Per Phillips 'In House' Prelim Plan Ver. #1 Revised: 7 June, 200~ Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Northings Eastings (ft) (ft) 2200.00 53.777 26.403 1827.20 1981.10 2251.54 55.580 26.319 1857.00 2010.90 2300.00 57.275 26.243 1883.80 2037.70 2400.00 60.773 26.095 1935.26 2089.16 2500.00 64.270 25.957 1981.39 2135.29 2516.35 64.842 25.935 1988.42 2142.32 2600.00 64.842 25.935 2023.98 2177.88 2700.00 64.842 25.935 2066.49 2220.39 2800.00 64.842 25.935 2109.00 2262.90 2887.27 64.842 25.935 2146.10 2900.00 64,842 25.935 2151,5~!.~? i ii.:'i:.~ :.: 2305i~ 3000.00 64.842 25,935 ............ 3100.00 64.842 25.935 :-~.i:ii!:.i~36:i~ ..... ......... :.ii?.;.72390 43 3200.00 64.842 25.935%:, '~:i!~79.0~:'i:"~: .... 2432.94 3300.00 64.842 ~5 '~':'~:-iii::?:::-~ 2321.55 2475.45 3369.2~;:%.::..64.~2:::'~.~.':... .::.? .... ::~25.~:.::~.:'~':~ ..... 2351.00 2504.90 3400,00~?~-.64,842:?.;..~. ~5.935.;;~;:~. 23 ~.07 2517.97 :.~:...~:~ ~::~.-~.::~.:~:.-..:-~. < ......... ............ 3486.88':~?:: ':~8~2':%:~:~;':?:~:~::~:25.935:~ 240~ .00 25~.90 . 3500.00:.~;~:::~.':::~:::?::~:~: ::~?~::~;'~?:..25.935 240~.58 25~0.4s 3600.00;-:.:?:~::; 64.842 ..... 25.935 2449.09 2602.99 3700.00 64.842 25.935 249~ .60 2645.50 3800.00 64.842 25.935 2534.11 2688.01 3900.00 64.842 25.935 2576.62 2730.52 4000.00 64.842 25.935 2619.13 2773.03 4300.00 64.842 25.935 2661.64 2835.~ 619.54 N 328.60 E 5912~2~.;53 N 657.22 N 347.27 E 59:~:..:~66~i~:..' N 693.42 N 365.15 E ............ 59'1i:2702.~i;;:~ 770.36 N 4~95 E :~.:.;'~::~° ~::'5-912~8.96~N 850.07 N ~:~:;.:~::i;;:.;ii:i;~l:i~8? E':.~i::? 5~858.47 N 863.35 N :~:'::~?;~:. ::::,:::..;'~.:~8.33:;:E: ::"5912871.71 N 93;~:~ N '~;:~::~::-::~:: 481.44 E 5912939.63 N ............................. :~O~'2:;~N :~ :'"' 521.03 E 5913020.83 N ~:~4.2~;~ 560.62 E 5913102.02 N Global Coordinates::. ;iii!~i;i~!i!i!:~ :~:i!iiiiiiiiiiiOogieg Northings i!i!iii!! .EaSfi~gS!iiiiii:!iii!~: ':~?~:Rate : ' i!iiiiiii 14 E 3.500 46~458.38 E 3.500 461~76.45 E 3.500 461514.64 E 3.500 461553.97 E 3.500 2300.00:~i?:' .::ili~.i'i'~i:/~'~.l't~7 N595.16 E 5913172.88 N .... .:'ii:::..-. ~':i :;7i.~ ...... :'~.'i.~.'i~ ": ~ ~: ~' '-:.!..!.:. ':.:::.:.... :':ii';;~!~ 1175.63 N 600.20 E 5913183.21 N 1257.03 N 639.79 E 5913264.41 N 1338.43 N 679.38 E 5913345.60 N 1419.83 N 718.96 E 5913426.80 N 1501.23 N 758.55 E 5913507.99 N 1557.61 N 785.97 E 5913564.23 N 1582.63 N 798.13 E 5913589.19 N 1653.35 N 832.53 E 5913659.73 N 1664.03 N 837.72 E 5913670.38 N 1745.43 N 877.31 E 5913751.57 N 1826.82 N 916.89 E 5913832.77 N 1908.22 N 956.48 E 5913913.96 N 1989.62 N 996.07 E 5913995.16 N 2071.02 N 1035.65 E 5914076.35 N 2152.42 N 1075.24 E 5914157.54 N Vertical Section 700.95 742.99 783,37 869.10 957.80 461560.50 E 3,500 972.57 461593.97 E 0.000 1048.28 461633.97 E 0.000 1138.79 461673.97 E 0.000 1229.31 461708.89 E 0.000 1308.30 4200.00 64.842 25,935 2704.15 2858.05 4300.00 64.842 25,935 2746.66 2900.56 4400.00 64,842 25.935 2789.17 2943.07 4500.00 64.842 25.935 2831.69 2985.59 4600.00 64,842 25.935 2874.20 3028.10 2233.82 N 1114.83 E 5914238.74 N 2315.22 N 1154.41 E 5914319.93 N 2396.61 N 1194.00 E 5914401.13 N 2478.01N 1233.58 E 5914482.32 N 2559.41 N 1273.17 E 5914563.52 N 461713.98 E 0.000 461753.98 E 0.000 461793.99 E 0.000 461833.99 E 0.000 461873.99 E 0.000 1319.82 1410.33 1500.85 1591.36 1681.87 461901.70 E 0.000 1744,57 461914.00 E 0.000 1772.39 461948.75 E 0,000 1851,03 461954.00 E 0.000 1862.90 461994.01E 0.000 1953.42 462034.01E 0.000 2043.93 462074.01E 0.000 2134.44 462114.02 E 0,000 2224.96 462154.02 E 0,000 2315.47 462194.03 E 0.000 2405.98 462234.03 E 0.000 2496.50 462274.03 E 0.000 2587.01 462314.04 E 0.000 2677.52 462354.04 E 0.000 2768.04 462394,05 E 0.000 2858.55 North Slope, Alaska Kuparuk 2N Comment Base West Sak (WS10) End Dir, Start Sail @ 64.842° · 2516.35ft MD, 2142.32ft TVD 7-5/8" Csg Pt ... Drill 6-3/4" Hole to TD 7-5/8" Casing C80 (K10) Camp SS 7 June, 200~ - ~2:08 Page3 of 8 DrillQuest 2.00.09.00~ Sperry-Sun Drilling Services Proposal Report for 2N-302 Plan - 2N-302 wp02 Your Ref: Per Phillips 'In House' Prelim Plan Ver. #1 Revised: 7 June, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Northings Eastings (ft) (ft) 4700.00 64.842 25.935 2916.71 4800.00 64.842 25.935 2959.22 4900.00 64.842 25.935 3001.73 5000.00 64.842 25.935 3044.24 5100.00 64.842 25.935 3086.75 3070.61 2640.81 N 3113.12 2722.21N 3155.63 2803.61N 3198.14 2885.01N 3240.65 2966.41N 5200.00 64.842 25.935 3129.26 5300.00 64.842 25.935 3171.77 5400.00 64.842 25.935 3214.28 5500.00 64.842 25.935 3256.80 5600.00 64.842 25.935 3299.31 5700.00 64.842 25.935 3341.82 5800.00 64.842 25.935 3384.33 ~':~3~3 5900.00 64.842 25.935 342- .: ...... ,..:..~:.. 6000.00 64.842 25.935 6100.00 64.842 25.935 :~.:::.-i:i?:'~l'~6 ~:..;::i?i'3665.76 ............... 6200.00 64.842 25~35 '"-"-:i:i~:::!:'i:':.~ ~.37 3708.27 6300,00 64,842:~::~ii~:?:i??~25~i~35 :?..?' 35'96.88 3750,78 6400.0:Q~%. 64.~? ..... ~:'!ii25,~5~'::''''~:':~ .... 3639,39 3793,29 6500,0 ~i?;.~:.:~'i.;:i:;i~4,84~;:i::;:.- .... ~, 93~!?::'?. 3681,90 3835,80 6573,15i:i':!;i.i:; ':::~"i~2:~::;":;:.i;:~;i725, 935 ....... 3713,00 3866,90 ~:~:: ~:~ ..:~-:~?::;: 6600,007~?:i:.i 64.842 '~:: 25.935 3724,42 3878,32 6700,00 ?:': 64.842 25.935 3766,93 3920.83 6800.00 64.842 25.935 3809.44 3963.34 6900,00 64,842 25,935 3851,95 4005,85 7000,00 64,842 25.935 3894.46 4048,36 3283.16 3047.80 N 3325.67 3129.20 N 3368.18 3210.60 N 3410,70 3292,0~!:N 3453,21 ...... ::.:;~:::i.:'..~:.:..~. 3373,4~i::N 349~72 ':i;i-i:::!::.;i.iii:-'.~ ....... :i~:::i73454.80 N 3536,20 N 3617,59 N 3698,99 N 378O,39 N 3861.79 N 3943.19 N 4024,59 N 4105,99 N 4165,53 N 4187,39 N 4268,78 N 4350.18 N 4431,58 N 4512.98 N 1312.76 E 5914~.~1 N 1352,34 E 59~4~2~90 N :~-.~:. ~: ~..~ ~ :-~: 1391,93 E .... .:~.-~59I~807,ti~:?~ 143~;~52 E7%:i§914~8,2g~'N ...... ?~.~.47~;:9 E?' ::~;~;:':~'~":59t.A~9.49 N '?~;;:;;'~:'~ 550.27 E 59~5~3~.87 N ?.,.~:.?.~.589.86 E 5915213.07 N '"':'1629.45 E 5915294.26 N 1669.03 E 5915375.46 N Global Coordinate~ '::::Dogleg Northings i :.:.~. (ft) (.i'~ o oft) '~ i':!i:~i:~62434:05 E 0.000 '~62,474.05 E 0.000 462514.08 E 0.000 462554.06 E 0.000 462594.07 E 0.000 1708.62 E 5915456.65 N 1748.21E 5915537.85 N 1787.79 E 5915619.04 N 1827.38 E 5915700.23 N 1866.96 E 5915781.43 N 1906.55 E 5915862,62 N 1946.14 E 5915943.82 N 1985,72 E 5916025,01N 2025.31E 5916106,20 N 2054,27 E 5916165,60 N 2064.90 E 5916187.40 N 2104.48 E 5916268.59 N 2144.07 E 5916349.79 N 2183.65 E 5916430.98 N 2223.24 E 5916512.18 N Vertical Section 2949.07 3039.58 3130.09 3220.61 3311.12 462634,07 E 0,000 3401,63 462674.07 E 0.000 3492,15 462714,08 E 0,000 3582,66 462754,08 E 0,000 3673,17 462794,09 E 0,000 3763,69 462834.09 E 0,000 3854.20 462874,10 E 0,000 3944,71 462914,10 E 0,000 4035,23 462954,10 E 0,000 4125.74 462994,11 E 0,000 4216,26 463034.11 E 0.000 4306,77 463074.12 E 0.000 4397,28 463114,12 E 0,000 4487,80 463154.12 E 0.000 4578,31 463183,39 E 0,000 4644.52 463194,13 E 0,000 4668.82 463234.13 E 0,000 4759,34 463274.14 E 0.000 4849,85 463314,14 E 0,000 4940,36 463354,14 E 0,000 5030,88 C50 North Slope, Alaska Kuparuk 2N Comment 7100.00 64.842 25.935 3936.97 4090.87 7200.00 64.842 25.935 3979.48 4133.38 7210.63 64.842 25.935 3984.00 4137.90 7300.00 64.842 25.935 4021.99 4175.89 7400.00 64.842 25.935 4064.50 4218.40 4594.38 N 4675.78 N 4684.43 N 4757.18 N 4838.58 N 2262.83 E 5916593.37 N 2302.41 E 5916674.56 N 2306.62 E 5916683.19 N 2342.00 E 5916755.76 N 2381.59 E 5916836.95 N 463394.15 E 0.000 5121.39 463434.15 E 0.000 5211.91 463438.40 E 0.000 5221.53 463474.16 E 0.000 5302.42 463514.16 E 0.000 5392.93 C40 (K5) 7Jun~ 2001-12:08 DrillQuest 2.00.09.001 Page 4 of 8 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 7500.00 64.842 25.935 4107.01 4260.91 7600.00 64.842 25.935 4149.52 4303.42 7631.70 64.842 25.935 4163.00 4316.90 7700.00 64.842 25.935 4192.04 4345.94 7800.00 64.842 25.935 4234.55 4388.45 7900.00 64.842 25.935 4277.06 8000.00 64.842 25.935 4319.57 8100.00 64.842 25.935 4362.08 8157.54 64.842 25.935 4386.54 8200.00 63.993 25.935 4404.87 8300.00 8400.00 8500.00 8527.56 8600.00 8700.00 61.993 25.935 4450.28 ~i~'.~;~604~i8 .. ~ -:~:~:~'..'::¢.:~:.. :~::~:.~:.:.: 59.993 25.935 4498..~:7~:-:.:i,: :.q.'~., 4'652~67 ' '~...-~::~'::~:i~ 57.993 25.935 4~0~28 :'*~i:ii;:ii.:::i:i7704718 57.442 25.935 *:.;.??~565~9;:,:~:_::~;~.:~:C~;¢*'~_,......... ?~ ~, 718.90 55.993 25.9~.??-:~::. ~'~O4.75.~?~''' 4758.65 Sperry-Sun Drilling Services Proposal Report for 2N-302 Plan - 2N-302 wp02 Your Ref: Per Phillips 'In House' Prelim Plan Ver. #1 Revised: 7 June, 200~ Local Coordinates Northings Eastings (ft) (ft) 4430.96 4473.47 5326.97 N 4515.98 5408.37 N 4540.44 5455.2~!~ 4558.77 ;iiiiiE ,;;~;iii~;* 5489.64 N '~6';'. "~:';!::':'" 5569.76 N 5648.41N 5725.48 N 5746.43 N 5800.89 N 4919.97 N 2421.17 E 59169:~,.~15 N 5001.37 N 2460.76 E 59:;!.6~ N 5027.17 N 2473.31 E .:.~:~: :~.~ .... ~:~:~: :. ~ ~::~: 5082.77 N 25~34 E::::?~ %5917~080.53*N ................... 5164.17 N ...... ~.:., :-::;i::;~39;~ E' ??:.:~:: ::"59~7 ~'8~ .73 N 5245.57 N **;?~:~::.:., **=~2~9.5~:;;~'.~':<:';;"::*;;':'~91"'""' '"::"::"' ':'" 7242.92 N ':';;~;:~;?:~658.69 E 5917405.31 N :*"'2681.47 E 5917452.03 N 8800.0,~:ii:.i.;.:.::~= 5i '~ii:i;' "'::':i~-~:ii~;.*~;' ...... 4722.31 4876.21 8855.65.ii;ii?;;i::.;:i:'~0.8807..:}.: .... ,;:¢5.93~;i:~.::.:.. 4757.00 4910.90 . .....~. ,::3~j:~:~ ..... 8900.0~;i.:i:.;;~ **~49~993-:.;.".;;.;-;.:.;:; :..'.':.'::25.934" 4785.24 4939.14 9000.00:;i;:;ii:;i:;,;-;i;;;;i:::~?::~3'. ":";:;.':;:.:-.'.:. 25.934 4850.86 5004.76 -::;:.~.~-~.m 9100.00: ;;~** 45.993 25.934 4919.06 5072.96 9149.66 45.000 25.934 4953.87 5107.77 9149.70 45.000 25.934 4953.90 5107.80 5874.55 N 5946.36 N 5985.49 N 6016.24 N 6084.10 N 6149.86 N 6181.71 N 6181.73 N 9200.00 45.000 25.934 4989.47 5143.37 9300.00 45.000 25.934 5060.18 5214.08 6213.72 N 6277.31N Global Coordinates:.. ':::Dogleg Northings EaS~S ~. ::':::;::Rate (ft) :.. :;:i.:. ('/~ooft) ~ i:'~63554:16 E 0.000 ~63~,94.17 i 0.000 463606.85 E 0.000 463634.17 E 0.000 463674.18 E 0.000 2698.22 E 5917486.38 N 2737.18 E 5917566.30 N 2775.43 E 5917644.75 N 2812.91E 5917721.63 N 2823.10 E 5917742.53 N 2849.58 E 5917796.85 N 2885.40 E 5917870.32 N 2920.33 E 5917941.95 N 2939.36 E 5917980.99 N 2954.31 E 5918011.66 N 2987.31E 5918079.35 N 3019.29 E 5918144.94 N 3034.78 E 5918176.71 N 3034.79 E 5918176.74 N 3050.35 E 5918208.64N 3081.27 E 5918272.07 N Vertical Section 5483.45 5573.96 5602.65 5664.47 5754.99 463714.18 E 0.000 5845.50 463754.18 E 0.000 5936.01 463794.19 E 0.000 6026.53 463817.21E 0.000 6078.61 463834.13 E 2.000 6116.91 463873.51E 2.000 6206.00 463912.16 E 2.000 6293.45 463950.04 E 2.000 6379.15 463960.33 E 2.000 6402.45 463987.10 E 2.000 6463.01 464023.30 E 2.000 6544.91 464058.59 E 2.000 6624.76 464077.82 E 2.000 6668.28 464092.93 E 2.000 6702.47 464126.28 E 2.000 6777.93 464158.60 E 2.000 6851.05 464174.25 E 2.000 6886.46 464174.26 E 0.000 6886.49 464189.98 E 0.000 6922.06 464221.23 E 0.000 6992.77 North Slope, Alaska Kuparuk 2N Comment C37 Begin Dir @ 2.0°/100ft· 8157.54ff MD 4540.44ft TVD Iceberg T7 End Dir, Start Sail @ 45.000° · 9149.70ft MD, 5107.80ft TVD 9350.66 45.000 25.934 5096.00 5249.90 9400.00 45.000 25.934 5130.89 5284.79 9435.51 45.000 25.934 5156.00 5309.90 9449.66 45.000 25.934 5166.00 5319.90 9500.00 45.000 25.934 5201.60 5355.50 6309.53 6340.90 6363.48 6372.48 6404.49 N 3096.94 E 5918304.21N N 3112.20 E 5918335.50 N N 3123.18 E 5918358.03 N N 3127.55 E 5918367.00 N N 3143.12 E 5918398.93 N 464237.06 E 0.000 7028.60 464252.48 E 0.000 7063.48 464263.58 E 0.000 7088.59 464268.00 E 0.000 7098.59 464283.73 E 0.000 7134.19 T3.1 T3 Target - T1 (2N-302), 100.00 Radius., Current Target 7June, 200¢-¢2:08 Page 5 of 8 DrillQuest 2.00.09.00~ Sper ry-Sun Drilling Services Proposal Report for 2N-302 Plan - 2N-302 wp02 Your Ref: Per Phillips 'In House' Prelim Plan Ver. #1 Revised: 7 June, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Northings Eastings (ft) (ft) 9576.94 45.000 25.934 5256.00 5409.90 6453.41N 9600.00 45.000 25.934 5272.31 5426.21 6468.08 N 9700.00 45.000 25.934 5343.02 5496.92 6531.67 N 9800.00 45.000 25.934 5413.73 5567.63 6595.26 N 9823.01 45.000 25.934 5430.00 5583.90 6609.89 N 9900.00 45.000 25.934 5484.44 5638.34 6658.85 N 10000.00 45.000 25.934 5555.15 5709.05 6~4 N 10100.00 45.000 25.934 5625.86 5779.76 678.~;03 N 10123.00 45.000 25.934 5642.13 5796.03 6~0'0~6~;'iN 3166.91 E 59184.4~:~3 N 3174.04 E 59~1~8~62~36 N 3204.97 E ....... ~59 li:~25.'7;9.:iN · ~s~ ~ '::--.-.:'.-~ '::~.:~.~ 323~5~9 E::::'?:':!ii:5918~.22-~:N · **3335.78 E 5918794.10 N All data is in Feet (US) unless otherwise stated. Direc!io**i!~d;i;~rd{~' are relative to True North. Vertical depths are relative to RKB = 153.9' MSl_~.s:NO~in~i~ Eastings are relative to 5' FSL & 484' FEL. The Dogleg Sevedty is in Degrees per 10~f:~t Vertical Section is from 5' FSL & 4~::::..EEE?ai3d c~1~ted along an Azimuth of 26.141 o (True). Based upon Minimum ~a~re'~'~ C.~[~ulations, at a Measured Depth of 10123.00ft., The BottomH.~Je Dis~m~ti::is'7~'!~2ff., in the Direction of 26.128° (True). ~i::~it'::]ii.:;.;.:~::~: ;:.%:. ' ?.i::?':- i:..i;~ ~;- :;~i:'~-:~i~ Global Coordinate~ '::Dogleg Northings .Ea~s, (ft) ~i,. (oi~00ft) ':~.:' ;.:~6430~!78 E 0.000 :::'~'~:14"'""' 98 E 0.000 464346.23 E 0.000 464377.48 E 0.000 464384.68 E 0.000 Vertical Section 7188.59 7204.90 7275.61 7346.32 7362.59 464408.74 E 0.000 7417.03 464439.99 E 0.000 7487.74 464471.24 E 0.000 7558.45 464478.42 E 0.000 7574.72 North Slope, Alaska Kuparuk 2N Comment T2 C35 (K3) Total Depth · 10123.00ff MD, 5796.03f TVD 3-1/2" Liner 7 June, 2001 - 12:08 Page 6 of 8 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for 2N-302 Plan - 2N-302 wp02 Your Reft Per Phillips 'In House' Prelim Plan Vet. #1 Revised: 7 June, 200~ Kuparuk River Unit Comments Measured Depth TVD fit) (ft) 0.00 0.00 400.00 400.00 900.00 897.47 1233.33 1219.03 2516.35 2142.32 2887.27 2300.00 8157.54 4540.44 9149.70 5107.80 10123.00 5796.03 Formation Tops Station Coordinates Northings Eastings (ft) (ft) Comment 0.00 N 0.00 E SHL: X = 461107'~4' E &'~¥':~;-591~0.6~'~N (5' FSL & 484' FEL, Sec 34-T10N-R7E) 0.00 N 0.00 E Begin Di!;...~;'~:~Q~/l~ft (in~.9;7/~:~H~e) · 400.00ft MD, 400.00ff ~D 37.69 N 21.76 E Increa~;~"Di~:~ate~::~3.~t!:~'": 900.00ff MD, 897.47ff ~D 112.31 N 64.84 E Increas~::.Di~;:Rate ~1~'0~ · 1233.33ff MD, 1219.03ff~D 863.35 U 448.33 E '.:~::~:pd Dir, St~"Sail ~ 64:842°'2516.35ff MD, 2142.32ff ~D 1165.27 N 595.16 E ........ :.:~:;:~';':':'-~::.. .... 7',5./8......~' Csg Pf';;. Ddll 6-3~4" Hole to TD ~55.20 N 2681:77-':~E~. "::¥.'.:.:.:....B~:~ Dir ~ 2.00/100ff· 8157.~ff MD, 4~0.44ff ~D 6181.73 N 303~:~79~E:.::.~::=`':~ ':':'.'::~:::.;E~'Q Dir, Sta~ Sail ~ 45.000° · 9149,70ff MD, 5107.8~ ~D 6800.66 N ~:3~33=5~8:E..:;;'~::-::~;: Total Depth · 10123.00ff MD, 5796.03ff ~D · ::~ ~ ~ ~..~..~.. ~ ......::;~.....;; ? ~ · ':-:...:...: .:: .:- ~.~' (Below Well Origin) Sub-Sea Dip. :,.~i;.i-~;:;i:;;i;i ~ip ~, ............... .... .:::;:::!;:'Depth 1050.0 ~i::::'!-~ '""':~':~0~000'?..:i?iiiiiB59.706 1217.25 1305.0 (~:i:.;::::i::.: iii; ':ii~::::~:.~0'i'~ "~;:;:i359.706 1497.45 1857.00::';:'~;:;~ 0.000 359.706 2251.54 2351.00~:;~ ..... 0.000 359.706 3369.27 2401.00 0.000 359.706 3486.88 "P"~'o fi le Penetration Vertical Sub-Sea Depth Depth Northings (ft) (ft) (ft) 1203.90 1050.00 107.60 N 1458.90 1305.00 208.40 N 2010.90 1857.00 657.22 N 2504.90 2351.00 1557.61N 2554.90 2401.00 1653.35 N Point Eastings (~) 62.13 E 118.09 E 347.27 E 785.97 E 832.53 E Formation Name Base Permafrost Top West Sak Base West Sak (WS10) C80 (K10) Camp SS 3713.00 0.000 359.706 6573.15 3984.00 0.000 359.706 7210.63 4163.00 0.000 359.706 7631.70 4565.00 0.000 359.706 8527.56 4757.00 0.000 359.706 8855.65 3866.90 3713.00 4165.53 N 2054.27 E 4137.90 3984.00 4684.43 N 2306.62 E 4316.90 4163.00 5027.17 N 2473.31 E 4718.90 4565.00 5746.43 N 2823.10 E 4910.90 4757.00 5985.49 N 2939.36 E C50 C40 (K5) C37 Icebe~ T7 7Jun~ 200~-12:08 Page 7 of 8 North Slope, Alaska Kuparuk 2N DrillQuest 2.00.09.00~ Sperry-Sun Drilling Services Proposal Report for 2N-302 Plan - 2N-302 wp02 Your Reft Per Phillips 'In House' Prelim Plan VeT. #1 Revised: 7 June, 2001 Kuparuk River Unit Formati on Plane (Below Well Origin) Measured Sub-Sea Dip Dip Dir. Depth (ft) Deg. Deg. (ft) Formation Tops (Continued) Profile Vertical Depth (ft) Penetration Point Sub-Sea Depth Northings Eastings (ft) (ft) (ft) Formation Name North Slope, Alaska Kuparuk 2N 5096.00 0.000 359.706 9350.66 5249.90 5156.00 0.000 359.706 9435.51 5309.90 5256.00 0.000 359.706 9576.94 5409.90 5430.00 0.000 359.706 9823.01 5583.90 5096.00 6309.53 N 3096.94 E 5156.00 6363.48 N '3123.18 E 5256.00 6453.41.'N 3166.91E 5430.00 6609~89 N 3243.01E Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Sufface~." ?':. ..... Targets as~bted To Measured Depth . '...?..Deptl¥:'.. i~'.:'.:..'..: Casing Detail ..... ........ '~;:'~'~'b0.00 7-5/8" Casing 5796.03 3-1/2" Liner T1(2N-302) Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Radius: T3.1 T3 T2 C35 (K3) Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 5319.90 5166.00 lO0.OOff 6372.48 N 3127.55 E 5918367.00 N 464268.00 E 70° 11'16.6766"N 150° 17'16.1499"W Target Shape Circle Target Type Current Target 7 June, 2001-12:08 Page 8 of 8 DrillQuest 2.00.09.001 Sperry-Sun Anficollision Report NO GLOBAL SCAN: Using user def'med selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 153.90 to 10123.00 ft Maximum Radius: 1251.69 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/21/2001 Validated: No Version: 5 Planned From To Survey Toolcode Tool Name ft ft 153.90 800.00 Planned: 2N-302 wp02 V1 CB-GYRO-SS Camera based gyro single shots 800.00 10123.00 Planned: 2N-302 wp02 V1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Casing Points ......... ......... '~'~:~'~' "<" ~'"":"' ~'~;~,: ............... i~iA"~'~;~ ~;;~',; ' I ft ft in in ' 2885.87 2300.00 7.625 9.875 7-5/8" 6183.90 3.500 6.750 3-1/2" Summary ...... Site Well Wellpath MD MD Distance Area Deviation Warning ft' ft ff ft ft Kuparuk 2N Pad 2N-303 2N-303 V1 499.53 500.0~ 13.88 7.19 6.69 Pass: Major Risk Kuparuk 2N Pad 2N-304 Plan 2N-304 V6 Plan: 2N-304 548.72 550.00 30.76 9.38 21.40 Pass: Major Risk Kuparuk 2N Pad 2N-305 2N-305 V2 498.68 500.00 40.65 7.41 33.24 Pass: Major Risk Kuparuk 2N Pad 2N-307 2N-307 V6 449.04 450.00 76.53 6.47 70.05 Pass: Major Risk Kuparuk 2N Pad 2N-308 2N-308 V2 743.45 750.00 87.05 12.14 74.95 Pass: Major Risk Kuparuk 2N Pad 2N-309 2N-309 V2 448.74 450.00 105.91 6.07 99.85 Pass: Major Risk Kuparuk 2N Pad 2N-313 2N-313 V2 299.99 300.00 165.74 3.65 162.09 Pass: Major Risk Kuparuk 2N Pad 2N-314 2N-314 V1 153.90 153.90 180.13 0.73 179.40 Pass: Major Risk Kuparuk 2N Pad 2N-315 2N-315 V2 299.99 300.00 195.89 3.83 192.06 Pass: Major Risk Kuparuk 2N Pad 2N-316 2N-316 V8 ' 349.99 350.00 210.08 4.53 205.55 Pass: Major Risk Kuparuk 2N Pad 2N-317 2N-317 V2 494.74 500.00 226.57 7.05 219.52 Pass: Major Risk 2N-302 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan for further discussion of these risks) 9-7/8" Hole / 7-5/8" Casin_~ Interval Event Risk Level I Mitigation Strategy Conductor Broach Low Set 120' of conductor. Monitor cellar continuously during interval Well Collision Low Careful well planning and surveying, adherence to anti-collision policy Running Coal and Low Elevated mud viscosity from spud and high Gravel density sweeps Shaker/Trough Cuttings Low Controlled ROP System Overflow Gas Hydrates Moderate Mud gas detection, controlled drilling, increased mud weights, lower viscosity, cold make-up water, and pre-treat with lecithin Shoe Fracture/Lost Low Reduced pump rates, and lightweight tail Returns during cement cement job 6-3/4" Hole / 5-1/2" x 3-1/2" Casing Interval Event Risk Level I Mitigation Strategy Sticky clay and tight Low Attention to hole cleaning and wiper trips hole first 2000' below using PWD to monitor shoe Swabbing Camp sands Moderate Mud weight at 9.6 ppg by C80 marker, during trip control trip speed, flow checks Elevated pressure in Low Flow checks while drilling interval. Have sand lenses in Iceberg not encountered drilling to east of 2N pad. One hole volume of kill weight mud mixed and ready at mud plant 2N-302 Drilling Hazards Summary. doc 06/07/01 ORI Geli AL Tarn 2N-302 Injector Proposed Completion Schematic PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Conductor 16" 62.5# H-40 (155' MD / 155' TVD) Surface csg. 7 5/8" 29.7# L-80 BTCM (+/- 28~7~ MD / 2300' TVD) All Depths Reference Nabors 16E RKB Production csg. 5-1/2" 15.5# L-80 BTC Mod run from XO/CSR to surface (+/- 9250' MD / 5179' TVD) Production csg. 3-1/2" 9.3# L-80 EUE 8rd Mod run TD to XO/CSR (+/- 10,123' MD / 5796' TVD) J. 3-1/2" 5M FMC Gen 5 tubing hanger with 3-1/2" L-80 EUE 8rd Mod pin down I. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to surface H. 3-1/2" Camco 'DS' landing nipple with 2.812" No-Go profile set at +/-500' G. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to 'DS' landing nipple F. 3-1/2" x 1" Camco 'KBG-2-9' Mandrel w/DV and latch at +/-2300 md w/ 3-1/2" x 6' L-80 handling pups installed on top & bottom of GLM E. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to "freeze protect" mandrel D. 3-1/2" x 1" Camco 'KBG-2-9' Mandrel w/DV and latch at +/-9210 md w/ 3-1/2" x 6' L-80 handling pups installed on top & bottom of GLM C. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing B. 3-1/2" Camco 'D' landing nipple with 2.75" No-Go profile A. Baker 3-1/2" 'GBH-22' Locator Seal Assembly w/15' of seals & Iocator 3-1/2" x 6' handling pup installed on top. EUE 8RD-Mod box up Baker XO - CSR top sub (Iocator seat) Baker 80-40 5-1/2" x 3-1/2" Casing Seal Receptacle (CSR) Baker XO - set at +/- 9250' MD / 5179' TVD (200' MD above T3 top) Future Thru-Tubing Perforations BDN, 6/7/01, vl ORIGINAL PHILLIP[ Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 June 8,2001 Ms. Camille Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re; Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: Dear Ms. Camille Taylor: KRU 2N-302 5' FSL, 484' FEL, Sec. 34, T10N, R7E 1096' FSL, 2628' FEL, Sec. 26, T10N, R7E 1524' FSL, 2419' FEL, Sec. 26, T10N, R7E B) Geologic Data and Logs Bill Morris, Geologist (20 AAC 25.071) 263-4588 A) Completion Report (20 AAC 25.070) Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 2N, or hauled to an approved Prudhoe or GKA Class II disposal The following people are the designated contacts for reporting responsibilities to the Commission: Sharon AIIsup-Drake, Drilling Technologist 263-4612 If you have any questions or require further information, please contact Brian Noel at (907) 265-6979 or James Trantham at (907) 265-6434. Sincerely, James Trantham Drilling Engineering Supervisor The well will be drilled and completed using Nabors 16E. Please utilize documents on file for this rig. Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 2N-302. TR~NSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~) %3 -' '~o~ ~ CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR I~SPOSAL ( ANNULAR DISPOSAL ( ) YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS ! ( ~g} YES + SPACING EXCEPTION "CLUE" The permit is for a new wellbore segment of existing well , Permit No, APl No. ~. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PI-I) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ~ disposal has not been requested..~~ Annular Disposal of drilling wastes will not be approved... "~~ai o; driiiing ,~'as;~; ;-;ill iiot-be-apl~ed~. Please note that an disposal of fluids generated... Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservatiOn order approving a spacing exception. (Company Name)will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates American Express® Cash Advance Draft 140 Issued by Intqr'~.d Payment: System. Inc. En~lewood, Colorado Payable at Norwest: Bank of Grand Junction - Downtown, NA. Grand Junction, Colorado PERIOD ENDING ': ;,O 8 ~,OO hOO~: :~ 5 NOT VALID FOR AMOUNT OVER $1000 / ,,,O ;, ?SOOO S ~,P,,'D WELL PERMIT CHECKLIST FIELD & POOL ~ ?~;/~ ADMINISTRATION ENGINEERING 1. Permit fee attached: ...................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling 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 ........... GEOLOGY 14. Conductor string provided ................... 15. Surface casing protects all known USDWs...' ........ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations ...... i . . . 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, d° they meet regulation ......... ~. ...... 26. BOPE press rating appropriate; teSt to . '~~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable.. ............... COMPANY ~/~J ~/) .~' WELL NAME ~/-,~4::~?--PROGRAM: exp dev ~ redrll serv wellbore seg INIT CLASS ~ ~ ~'~,~)~7'~/ G' A~,(~)LL REA ~ ~ ~ UNIT# ///{~ ~ .... Y N ann. disposal para req_ ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; APPR DATE ON/OFF SHORE 30. Permit can be issued wlo hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... Y N// ,~ I /3 32. Seismic analysis of shallow gas zones. .... ........ Y ×N' J//,,/~~7~-'/ ~ 33. Seabed condition survey (if off-shore) .... ......... ~Y"' N ' - 34. Contact name/phone for weekly progress reports [exploratory onl¥]/Y N Y N C~'.~.~"t, o~-~'~-.. "~/~'~ . . . (B) will not contaminate freshwater; or cause drilling waste... 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 GEOLOGY: ENGINEERING: UlClAnnular COMMISSION: Commentsllnstructions: ",- ~, '~rdi"n\di'm\rh,.r. klist (rev. 111011100) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is Part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIx. ., No special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Oct 11 13:12:53 2001 Reel Header Service name ............. LISTPE Date ..................... 01/10/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/10/11 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 1ST STRING 2ND STRING MWD RUN 2 AK-MM-ii101 P. SMITH M. THORTON OPEN HOLE BIT SIZE 6.750 (IN) 2N-302 501032038000 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services il-OCT-01 34 i0N 7E 4 485 .00 153.63 119.30 CASING SIZE (IN) 7.625 DRILLERS DEPTH (FT) 2888.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 2 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHWARTZ, PHILLIPS ALASKA, DATED 10/02/01. 6. MWD RUN 2 REPRESENTS WELL 2N-302 WITH API#: 50-103-20380-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10297'MD / 5937.62'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE 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 ABSORPTIONFACTOR (LOW-COUNT BIN). SLDSLIDE = SLIDE INTERVAL ADJUSTED FOR THE SLD SENSOR-TO-BIT DISTANCE PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.75" MUD WEIGHT: 9.6 PPG MUD SALINITY: 500-800 PPM CHLORIDES FORMATION WATER SALINITY: 19,149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE NCNT FCNT NPHI PEF DRHO RHOB GR RPD RPM RPS RPX ROP FET $ START DEPTH 2800.0 2800 0 2800 0 2809 5 2830 0 2830 0 2841 0 2847 5 2847 5 2847 5 2847 5 '2903 5 2904 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: STOP DEPTH 10186 0 10186 5 10186 0 10202 0 10202 0 10202 0 10233 5 10240 5 10240 5 10240 5 10240 5 10297 0 10240 5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 2800.0 10297.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 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 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 2800 10297 ROP MWD FT/H 4.66 4466.73 GR MWD API 51.35 259.85 RPX MWD OHMM 0.81 1762.32 RPS MWD 0HMM 0.11 81.06 RPM MWD OHMM 0.37 2000 RPD MWD OHMM 0.36 2000 FET MWD HOUR 0.1558 8.5171 NPHI MWD PU-S 9.31 66.37 FCNT MWD CNTS 89.65 1111.46 NCNT MWD CNTS 12777.5 34579 RHOB MWD G/CM 1.681 3.64 DRHO MWD G/CM -0.731 1.258 PEF MWD BARN 2.33 15.28 Mean Nsam 6548.5 14995 164.42 14788 141.805 14786 4.5472 14787 4.45549 14787 8.29389 14787 9.77623 14787 0.745483 14674 35.3506 14773 262.417 14774 19807.5 14773 2.38063 14678 0.0904734 14678 4.01157 14786 First Reading 2800 2903.5 2841 2847.5 2847.5 2847.5 2847.5 2904 2800 2800 2800 2830 2830 2809.5 Last Reading 10297 10297 10233 5 10240 5 10240 5 10240 5 10240 5 10240 5 10186 10186.5 10186 10202 10202 10202 First Reading For Entire File .......... 2800 Last Reading For Entire File ........... 10297 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/11 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 ....... 01/10/11 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT 2800.0 FCNT 2800.0 STOP DEPTH 10186.0 10186.5 NPHI PEF DRHO RHOB GR RPD RPM RPS RPX R0P FET $ LOG HEADER DATA DATE LOGGED: SOFTWARE 2800 0 2809 5 2830 0 2830 0 2841 0 2847 5 2847 5 2847 5 2847 5 2903 5 2904 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: 10186 0 10202 0 10202 0 10202 0 10233 5 10240 5 10240 5 10240 5 10240 5 10297 0 10240 5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ 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 09 -JUL- 01 Insite 4.3 Memory 10297.0 43.0 67.2 TOOL NUMBER 2076GR4 2076GR4 2076GR4 2076GR4 6.750 LSND 9.60 47.0 9.0 5OO 4.2 .950 .500 2.500 1.550 68.0 136.4 68.0 68.0 sandstone 2.65 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 DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Order Units Size Nsam Rep FT 4 1 68 MWD020 FT/H 4 1 68 MWD020 API 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 HOUR 4 1 68 MWD020 PU-S 4 1 68 MWD020 CNTS 4 1 68 MWD020 CNTS 4 1 68 MWD020 G/CM 4 1 68 MWD020 G/CM 4 1 68 MWD020 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 2800 10297 R0P MWD020 FT/H 4.66 4466.73 GR MWD020 API 51.35 259.85 RPX MWD020 OHMM 0.81 1762.32 RPS MWD020 OHMM 0.11 81.06 RPM MWD020 0HMM 0.37 2000 RPD MWD020 OHMM 0.36 2000 FET MWD020 HOUR 0.1558 8.5171 NPHI MWD020 PU-S 9.31 66.37 FCNT MWD020 CNTS 89.65 1111.46 NCNT MWD020 CNTS 12777.5 34579 RHOB MWD020 G/CM 1.681 3.64 DRHO MWD020 G/CM -0.731 1.258 PEF MWD020 BARN 2.33 15.28 Mean Nsam 6548.5 14995 164.42 14788 141.805 14786 4.5472 14787 4.45549 14787 8.29389 14787 9.77623 14787 0.745483 14674 35.3506 14773 262.417 14774 19807.5 14773 2.38063 14678 0.0904734 14678 4.01157 14786 First Reading 2800 2903.5 2841 2847.5 2847.5 2847.5 2847.5 2904 2800 2800 2800 2830 2830 2809.5 Last Reading 10297 10297 10233.5 10240.5 10240.5 10240.5 10240.5 10240.5 10186 10186.5 10186 10202 10202 10202 First Reading For Entire File .......... 2800 Last Reading For Entire File ........... 10297 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/10/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/10/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File