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Home My WebLink About200-155 • • P7/7 Zov —l 5-5--- Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday, December 10, 2017 9:04 AM To: Wallace, Chris D (DOA) Cc: NSK Well Integrity Supv CPF1 and 2 Subject: KRU 2N-326(PTD#200-155) update Attachments: Capture.JPG;MIT KRU 2N-326 Diagnostic MIT-IA 10-06-17.xlsx Chris, Tarn WAG injector 2N-326(PTD#200-155)was reported for an anomalous IA pressure increase on October 2, 2017. The well was then WAG'd to water and a series of gas bleeds were performed on the IA after which a passing MIT-IA was achieved. During the subsequent water injection and gas injection monitor periods the well exhibited no anomalous annular pressure changes. As such CPAI plans to return the well to 'normal'status. If the well displays signs of annular communication in the future the proper notifications and corrective actions will be made at that time. A 90 day TIO trend and MIT 10-426 are attached. Please let us know if you disagree or have any question with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 AWELLS TEAM conocounps SC P1 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Monday, October 2, 2017 10:08 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of IA pressure anomaly Tarn injector 2N-326(PTD#200-155) 10-2-17 Attachments: 2N-326 schematic.pdf; 2N-326 90 day TIO 10-2-17.JPG Chris, Tarn WAG injector 2N-326(PTD#200-155) is demonstrating an IA pressure anomaly. The well was WAG'ed to water a few days ago on September 28, 2017 after having been on gas injection since July 20,2017. There have been several failed attempts to establish proper differentials between the IA and tubing. Bleeding the IA pressure below'"950psi has proven problematic. DHD will begin the initial suite of diagnostics to include packoff testing,extended bleeding as necessary and an MITIA. Pending a passing MITIA,the well will be monitored on water injection for 30 days. If there are indications of a gas-only leak, at the conclusion of the water monitor,the well will be WAG'ed back to gas injection for a 30 day monitor to confirm or refute those suspicions. The well will be shut in and freeze protected if the MITIA fails with follow-up well intervention with e-line,slickline,etc as needed. A follow-up email will be provided at the conclusion of the diagnostic monitor. Let us know if you disagree with the path forward. Attached are the schematic and 90 day TIO plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Mobile Phone (907)943-0170 SCANNED 1, 1 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. ~_.O_~) J ~Well History File Identifier RESCAN J Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: ~age Project Well History File ,er Page OVERSIZED (Scannable) [] Maps: · ~ Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds BY: DIGITAL DATA ~ [] Diskettes, No. [] Other, No/Type [] Other BEVERLY ROBIN VINCENT SHERYL(~)JVINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~INDY III IIIIIIIIIII II III Scanning Preparation <:~ BY: BEVERLY ROBIN VINCENT SHERYL~INDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: BY: Stage 2 BY: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: _.~ YES NO RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: IS~ Quality Checked 12110/02Rev3NOTScanned.wpd A • • O s THE STATE Alaska ' and Gas f.; l/fA LAsKA c„..,onservation C0111111iSSiOri T4, GOVERNOR SEAN PARNELL 333 West Seventh Avenue • OF`+�mr • p. Anchorage, Alaska 99501 -3572 A L AS Y + � ��*s Main: 907.279.1433 SC aNNEry �� 2 J Fax: 907.276.7542 Martin Walters GVV Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 r1 0 Q Anchorage, AK 99510 c � Re: Kuparuk River Field, Tarn Oil Pool, 2N -326 Sundry Number: 313 -311 Dear Mr. Walters: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for 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, --J. P4<A Cathy P. reerster Chair sfr DATED this 2.1 day of June, 2013. Encl. m ,.w s.4 , -':.,, } k 1 • STATE OF ALASKA • b !2 C0 A OIL AND GAS CONSERVATION COMMISSION N ,� "1 ! ,.. % .1 t .. APPL FOR SUNDRY APPROVALS / 20 AAC 25.280 ^t,` "'' "., 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other: Conductor Extension . I• 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 200 -155 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20351 -00 • 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 2N - 326 . 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0375074 - Kuparuk River Field / Tarn Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 12775 " 5076 Casing Length Size MD TVD Burst Collapse CONDUCTOR 105 16 140' 140' 1640 630 SURFACE 4261 7 -5/8 4296' 2298' 6890 4790 PRODUCTION 11921 5 -1/2 11956' 4828' 7000 4990 PRODUCTION 813 3 -1/2 12769' 5074' 10160 10540 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12306 -12316 • 4938 -4942 3.5 L -80 11933 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) BAKER 80 -40 CASING SEAL ASSEMBLY ` MD= 11934 TVD= 4821 CAMCO DS NIPPLE . MD = 483 TVD = 483 12. Attachments: Description Summary of Proposal . 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 Commencing Operations: 15. Well Status after proposed work: 7/1/2013 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: "VVINJ r GINJ r WAG r7 ' Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Martin Walters / MJ Loveland Email: N1878ta'�.cop.com Printed Name Martin Walter Title: Well Integrity Projects Supervisor Signature 8 ;A A / 9 Phone: 659 -7043 Date: 06/16/13 Commission Use Only Sundry Number:36 ` 3 I Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r A\i Other: RBDMS JUN 2 6 20* Spacing Exception Required? Yes ❑ No d Subsequent Form Required: / L - yo APPROVED BY / Approved by: cgq THE,COMN}ISSION Date: (. at '' 1.3 ANNiL i t-atlurl is Valid Iu. 12 n io R nt l ia G uff% tl ic �la�c �I a Form 10 -403 (Revised 10/2012) Submit Form and Attachments in Duplicate � ,,t, rl-.�4,eZi ORIGINAL -� a lt • • » 1 ;` 2013 ConocoPhillips t y� RA�1. 1p. "� / Alaska 4 P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 16, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2N -326, PTD 200 -155 conductor extension. Please contact Martin Walters or MJ Loveland at 659 -7043 if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 ConocoPhillips Alaska, Inc. Kuparuk Well 2N -326 (PTD 200 -155) SUNDRY NOTICE 10 -403 APPROVAL REQUEST June 16, 2013 This application for Sundry approval for Kuparuk well 2N-326 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to SC. At some point during normal operations the conductor subsided about 9 1 /4 ". 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. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10 -404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor . � e1. °, KUP • 2N -326 Conoco Phillips ° Well Attributes fMax Angle & MD ITD Alaska InC Wellbore API /UWI Field Name Well Status Incl (7 MD (ftKB) Act Btm (ftKB) cnnmptulkps 501032035100 TARN PARTICIPATING AREA INJ I 75.44 12,707.09 12,775.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date ••• Well Conan HORIZONTA-2N -326, 124/2012 3 13 01 PM.. S$SV: NIPPLE Last WO. 41.02 11/2/2000 HORIZONTAL Schematic - Acluni Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 12,285.0 4/20/2007 Rev Reason: WELL REVIEW osborl 1/24/2012 Casing Strings HANGER, 30T " PM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 34.7 140.0 140.0 62.50 H WELDED or Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 7 5/8 6.875 34.7 4,295.5 2,298.7 29.70 L BTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd ■ ' PRODUCTION 51/2 4.950 32.2 12,769.1 5,074.5 15.50 L -80 BTC MOD 5.5 "x3.5" @ 11956' Tubing Strings __ Tubing Description String 0... String ID .. Top (ftKB) ISet Depth (f... I Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 _ 30.0 I 11,949,7 I 4,825.9 9.30 L -80 EUE8RDMOD Completion Details CONDUCTOR, Top Depth Ir 35140 (TVD) Top Incl Nomi... Top (ftKB) Top ( Item Description Comment ID (in) 30.0 30.0 -1.69 HANGER FMC GEN V TUBING HANGER 3.500 NIPPLE, 483 - 483.4 483.0 6.61 NIPPLE CAMCO DS NIPPLE 2.875 II 11,840.8 4,789.8 70.48 SLEEVE BAKER CMU SLIDING SLEEVE W /CAMCO PROFILE 2.813 11,926.1 4,818.0 70.69 NIPPLE CAMCO D NIPPLE w/ NO GO PROFILE 2.750 11,933.2 4,820.4 70.76 LOCATOR BAKER LOCATOR 2.985 11,934.0 4,820.7 70.77 SEAL ASSY BAKER 80-40 CASING SEAL ASSEMBLY 2.985 Perforations & Slots , - GAS LIFT. Shot 3,789 et Top (WD) Btm (TVD) Dens it Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh••• Type, Comment 12,306.0 12,316.0 4,938.8 4,942.3 S -3, 2N -326 11/6/2000 4.0 IPERF 2.5" BH HSD; 180 deg ph; w /4000# whp. , Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment SURFACE, ' 12,306 0, 12,316.0 4,938 8, 4,942.3 FRAC 11/7/2000 j Placed 222 Mlbs prop behind pipe 354,296 Notes: General & Safety End Date Annotation 11/23/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, 4 7,857 GAS LIFT, 10.347 1 SLEEVE, , 11,841 1 GAS LIFT, 11,882 NIPPLE, 11,926 1111 LOCATOR, 11,933 1 SEAL ASSY, 7 1 11,934 r Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) IRKS) (1 Make Model (in) Sery Type Type (16) (psi) Run Date Com... 1 3,789.1 2,148.1 72.47 CAMCO KBG -2 -9 1 GAS LIFT DMY DCK 0.000 0.0 10/31/2000 2 7,857.0 3,472.5 69.97 CAMCO KBG -2 -9 1 GAS LIFT DMY DCK 0.000 0.0 10/31/2000 IPERF, 3 10,347.3 4,299.7 68.96 CAMCO KBG -2 -9 1 GAS LIFT DMY DCK 0.000 0.0 10/31/2000 12,306 12,316 - _ FRAC, 12,306 i=;:.: . _ _ 4 11,882.4 4,803.0 70.25 CAMCO KBG - 2 - 9 1 GAS LIFT DMY BTM 0.000 0.0 1/1/2002 PRODUCTION 5 5 "03.5' ft 11956', 32- 12769 TD, 12,775 • • Page 1 of 1 Regg, James B (DOA) From: Phillips, Jim (ASRC Energy Services) [Jim.Phillips@contractor.conocophillips.com] Sent: Wednesday, August 25, 2010 3:57 PM /~, ` ~~~~~! To: Regg, James B (DOA) Subject: RE: State MITIA test results for 2N pad on 8/24/10 Follow Up Flag: Follow up ~ ~p -15~ Flag Status: Red Z ~,~; ~{ ~ - . 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 Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 tt t ~~r` ~~ 4~ fJ 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(u~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: ConocoPhillips Alaska Inc. n 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 TVD 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 TVD 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 e test 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 TVD 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 ND 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 TVD 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 TYPEINJ 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 . . eonoarPhillips Alaska Re.ee.\VED SEP 1 2 2007 . . n A'aska 0\\ & Gas Cons. CommlSSlO Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 07, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission _ 1 2- 201:H 333 West 7th Avenue, Suite 100 5cANNt:.D SEt' Anchorage, AK 99501 d,¡þ~ \55 (0 ß,Ñ- Ý Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells trom 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 trom entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped on September 5,2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, \~/~ ~ ~end ConocoPhillips Well Integrity Field Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft (lal 2N-320 199-001 4" n/a 4" n/a 2 9/5/2007 2N-321 198-173 6" n/a 6" n/a 2 9/5/2007 2N-323 198-071 1" n/a 1" n/a 1 9/5/2007 2N-325 198-163 10" n/a 10" n/a 2 9/5/2007 2N-326 200-155 9" n/a 9" n/a 3.5 9/5/2007 2N-337 206-163 6" n/a 6" n/a 1 9/5/2007 2N-339 198-100 8" n/a 8" n/a 2.5 9/5/2007 2N-341 198-103 3" n/a 3" n/a 1 9/5/2007 2N-342 207-068 18" n/a 18" n/a 4.5 9/5/2007 2N-343 198-092 4" n/a 4" n/a 2 9/5/2007 2N-345 204-034 9" n/a 9" n/a 3.5 9/5/2007 Date 917/2007 (LlÞ------- - 01/02/07 Schlumberger NO. 4092 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 6CANNED JAN 0 8 2007 UI~ Ð()O- ¡06- Field: Kuparuk Well Job# Color CD Log Description Date BL 2N-304 11416232 FBHP SURVEY 10/30/06 1 2N-304 11296737 FBHP SURVEY 11/04/06 1 1D-109 N/A INJECTION PROFILE 11/27/06 1 1J-136 (REDO) 11534188 USIT 12/10/06 1 1R-18 N/A SBHP/DD 12/18/06 1 1G-16 11551836 INJECTION PROFILE 12/19/06 1 1D-103 11548555 INJECTION PROFILE 12/20/06 1 3K-09A N/A SBHP SURVEY 12/22/06 1 3K-26 N/A SBHP SURVEY 12/22/06 1 3K-18 11551838 SBHP SURVEY 12/23/06 1 2N-326 11551840 SBHP SURVEY 12/24/06 1 3S-19 11548564 PRODUCTION PROFILE 12/25/06 1 2M-10 11551841 PRODUCTION PROFILE 12/25/06 1 2M-16 11551842 INJECTION PROFILE 12/26/06 1 2A-20 11548565 INJECTION PROFILE 12/26/06 1 2M-15 11551843 PRODUCTION PROFILE 12/27/06 1 2M-22 11538773 PRODUCTION PROFILE 12/28/06 1 1J-184 11538775 PRODUCTION PROFILE 12/30/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor î/ q)/ '/ ~~Y1 ö\ It Cb DATE: Wednesday, August 09, 2006 SUBJECT: Mechanical Integrity Tests eONOeOPHILLIPS ALASKA INe 2N-326 KUPARUK RIV U TARN 2N-326 QfJö - /SS- FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U TARN 2N-326 API Well Number 50-103-20351-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060808191523 Permit Number: 200-155-0 Inspection Date: 8/8/2006 Rei Insp N urn Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. !Type Inj. ¡WI TVD - I I I ! Well 2N-326 4821 IA 1050 2420 2290 2290 i ! L I I I _----Ì- ITypeTest i SPT I Test p;i I t- -~ P.T. 2001550 1500 I OA 300 I 400 400 400 I , i I I I --~~- ¡,/ , Tubing I 1620 ! 1620 1620 1620 I Interval 4YRTST P/F P i -~- i ! Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. SCANNED AUG 2420GB Wednesday, August 09, 2006 Page I of I ....~ ~~~."":_', " "'-.--' ,....... . ,.~= '.1. ~ '. \ MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to Drill 2001550 MD 12775 TVD DATA SUBMITTAL COMPLIANCE REPORT 111612003 Well Name/No. KUPARUK RIV U TARN 2N-326 Operator CONOCOPHILMPS ALASKA INC 5076 Completion Dat 11/6/2000 Completion Statu l-OIL Current Status WAGIN APl No. 50-t03-20351-00-00 UIC Y __ REQUIRED INFORMATION Mud Log N._~o Sample N__g_o Directional Survey N__.~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fret Log Log Run Name ~ Scale Media No 103~ FINAL R R R R R R R (data taken from Logs Portion of Master Well Data Maint C~Bfl~~eme nt Mapping ~..~Y~O Survey Report ~'~ey Report 'I~D Survey Report PRES/TEMP/Baseline 5 /.-W~ater Flow Log 5 LIS Verification Interval OH I Start Stop CH 4252 12721 OH Received 10/11/2001 FINAL FINAL FINAL FINAL 4252 12721 Open 11700 12425 CH 11817 12311 OH 12055 12260 OH 4252 12721 OH 4252 12721 OH 9/27/2001 1/3/2001 1/9/2001 1/9/2001 1/9/2001 7/30/2001 7/30/2001 9/27/2001 9/27/2001 Dataset Number .~omments 10354-"'~252~-7-~ ~-gi~i -D-~'ta- -~ v~"t;¢ $. 10333~4252-12721 11700-12425 Color Print Surface to TD Paper Report Surface to TD Paper Report Surface to TD Paper Report 11817-12311 BL, Sepia 12055-12260 BL, Sepia 4252-12721 LIS Verification 10333 ~'~52-12721 Digital Data Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis R ~.c.~.iv~.d ? Daily History Received? ~/N Formation Tops ~1 N Comments: Permit to Drill 2001550 MD 12775 TVD DATA SUBMITTAL COMPLIANCE REPORT 1116~2003 Well Name/No. KUPARUK RIV U TARN 2N-326 Operator CONOCOPHILLIPS ALASKA INC 5076 Completion Dat 11/6/2000 Completion Statu 1-OIL Current Status WAGIN APl No. 50-103-2035t-00-00 UIC Y Compliance Reviewed By: Date: MEMORANDUM TO: Camille Taylor Chair State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 25, 2002 /~ '~-S~.~ ~ ~c~--J BJ ECT: Mechan ica ll nteg rity Tests THRU: Tom Maunder Phillips Alaska Inc. P.I. Supervisor 2N 309, 326, 335 FROM: John H. Spaulding Kuparuk River Unit Petroleum Inspector Kuparuk River Field WellI 2N-309I P.T.D.I 1990210 NON-CONFIDENTIAL Packer Depth Pretest Initial 15Min. 30Mi~ - ~ - [ - [ Type lnj. J P J T.V.D. J5~3 J Tubing J2250 J2250 J2255 J2255 J lntewalJ I J-- Type testJ a J TestpsiJ 1261 J CasingJ 2250J 2960J 2950J 2950J P/F I J Notes: WellJ~~ii,~r~JlTypelnj. J P J T.V.D. J 4021 J TubingJ 2450 J 2440 J 2440 J 2420 J lntervalJ I J t~'~'~'~'~lTypetestl a ITestpsi11205 I CasingJ 2250 12955I2960I2950IPIE I --P'I P.T.O.J 2001550I Notes: I Typelnj. I P ITM 14963 I Tubing I 2400 12400 12400 I 2400 I lntervall I I P.T.D.Iwell119820402N'335 ITypetestl a ]Testpsi11241 ICasing11150 12940 12920 12900' '1 PIE I"..-- 13 I' Notes: Type Inj. test Notes: Well] I TypeInj. P.T.D. I I Type test Notes: Type INJ. Fluid Codes F -- FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer surVey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W-- Test during Workover O= Other (describe in notes) Test's Details As noted in the above test report form no failures were observed. All wells are operating within the area's injection orders. M.I.T.'s performed: _3 Attachments: Number of Failures: 0 Total Time during tests: 3 hrs. cc: none MIT report form 5/12/00 L.G. mit's KRU 3N 4-25-02 Revised js.xls 718/2002 , Jeff A Spencer 06118/01 05:39 PM To: torn_maunder@admin.state.ak.us, bob_crandall@admin.ak.us, Brian D Noel/PPCO@Phillips cc: Jason Putnam/PPCO@Phillips, Satellites Prod Engrs/PPCO@Phillips, Stephen Bross/PPCO@Phillips Subject: Tarn Development - AOGCC Meeting Notes (06/13) Gentlemen, Please find below a summary of what was discussed at last Wednesday's (06/13) meeting regarding Tarn Field development. AEendance: AOGCC Phillips Tom Maunder Jeff Spencer Bob Crandall Brian Noel Well 2L-317A: (New Injection Well) RECEIVE'D JUL i' ?001 0il & Gas Cons. Commission Anchorage Because a CBL showed poor cement bonding in and immediately above the Bermuda interval, an alternative method was proposed by Phillips to demonstrate zonal isolation using a Water Flow Log (WFL). After reviewing the CBL, cement job data and other completion related information, the following plan was agreed to during an April 19th meeting. 'Note: Provide a detailed procedure, wellbore schematic, copy of CBL, details on the initial 2L-317A cement job, and a completed Sundry Form 403 to AOGCC prior to commencing any field work. 1. Perforate a 5' interval approximately 70' MD below the top of the Bermuda interval (T3). Projected depths of the initial perfs are expected to be 12182-12187' MD. 2. Establish injection into the well using water from a pump truck/transport at 1-2 BPM. Note: The expected maximum water injection rate into 2L-317A is <3000 BWPD. 3. Run WFL to determine if there is any behind Pipe upward flow out of the Bermuda interval. 4. Review WFL with AOGCC. If upward flow is detected above the Bermuda interval, determine an appropriate remedial fix. The WFL did not show any upward flow and was reviewed with AOGCC personnel on June 13th. Once we provide copies of the WFL and a completed Sundry Form 403, we can proceed with Steps #5, 6 & 7, as outlined below. Note: Copies of the CBL, wellbore schematic and details of primary cement job were previously provided to AOGCC. 5. If no upward flow is detected, add perforations in the net pay intervals below the initial perforations and complete well as an MWAG injector. Note: Leave well SI until water is available for injection. 6. Commence water injection at normal operating rates and monitor daily rates & pressures. Note: Injection rates and pressure data are to be reported on a monthly basis similar to other MIT waivered injection wells. 7. After 2-3 months of water injection, run another WFL log to confirm that injection is staying within desired interval. AOGCC prefers WFL be run after 3 months of water injection. 8. If second WFL shows no upward flow or behind pipe channelling, commence normal MWAG operations after reviewing log with AOGCC. Producer-to-Injector Conversions: 2L-305 Reviewed CBL on 2L-305 with AOGCC and it showed excellent bonding throughout the zone of interest. Approval to convert to MWAG injector will be forthcoming from AOGCC once we provide copies of the CBL, wellbore schematic, primary cement job information and a completed Sundry Form 403. ' Note: 'Future P-to-I Conversion candidates showing good cement bonding can be submitted for approval directly to the AOGCC (with appropriate supplementary information as shown above). 2N-326 Reviewed CBL on 2N-326 with AOGCC and it showed what appeared to be contaminated cement throughout the zone of interest. The VDL indicated some bonding to the formation but either due to weak compressive strength of the cement and/or incorrect CBL tool settings, the bond to the pipe appeared relatively poor. So although the CBL provides some evidence of cement behind pipe and it was our recollection that the frac job went as planned, the AOGCC requested that we run a WFL to ensure no upward flow above the Tarn producing horizon (Bermuda interval). Therefore, the action plan for 2N-326 is as follows: 1. Establish injection into the well using water from a pump truck/transport at 4 - 5 BPM. Note: The expected maximum water injection rate into 2N-326 is -7000 BWPD. 2. Run WFL to determine if there is any behind pipe upward flow above the Bermuda interval. Note: This well was fracture stimulated from a 10' perf interval near the base of the Bermuda. 3. If upward flow is detected above the Bermuda interval, determine an appropriate remedial fix and review with AOGCC. ,. 4. If no upward flow is detected, send copies of the CBL, WFL, wellbore schematic, fracture, stimulation' summary, primary cementing information and Sundry Form 403. to AOGCC. 5. Upon receiving approval from AOGCC, complete well as an MWAG injector. Other Tarn P-to-I Conversion candidates will follow procedures similar to those outlined above for receiving approval from AOGCC. Thanks again for taking the time to meet with us and have a great week, Jeffrey A. Spencer Tarn Development Coordinator Phillips Alaska, Inc. 907-265-6813 jspencer@ppco.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 76' FNL, 834' FEL, Sec~ 3, T9N, R7E, UM .At top of productive interval 1448' FNL, 149' FEL, Sec. 32, T1 ON, R7E, UM .At effective depth 5. Type of Well: Development Exploratory _ Stratigraphlc Service_X (asKs 460757, 5911930) ,At total depth 1276' FNL, 629' FEL, Sec. 32, T1 ON, R7E, UM (asKs 450418, 5916070) 12. Present well condition summary Total depth: measured true vertical 12775 feet Plugs (measured) 5076 feet 6. Datum elevaUon (DF or KB feet) RKB 155 feet 7. Unit or Property name Tarn Unit 8. Well number 2N-326 9. Permit number I approval number 200-155 / 10. APl number 50-103-2O351 11. Field ! Pool Kuparuk River Field/Tarn Oil Pool Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth (~OND UC-T-(~FI ........ 1-407 ...... t 6" .... .s cu-yds -High-Early-. 140'. -140' ' ........ SURF CASING 4140' 7-5/8" 410 sx AS III Lite & 240 sx Class ( 4295' 2299' PROD CASING 11801' 5-1/2' ~so bbis Class G 11956' 4828' PROD CASING 813' 3-1/2' (~nduded above) 12769' 5074' PROD CASING ::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::: 13. Stimulation or cement squeeze summary 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 mX 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~/ i i ~,,.._~~'-'~- ~- ~.,4,t,~..~ Title Production Engineering Supervisor Signed ~ ..,._..... ,. Jeff A. Spencer Form 10-404 Rev 06/15/88 · Representative Daily Average Production or Injection Data OiI-Bbi Gas-Md .,W,.a.t..e.r,.,,.E~.,! ,.C...a~.,.qg .P..r.~.s..u.r.e' .T..u.b. in.g.P..m,~.u,m.. .:.:.:.:.:.:,:.:,:.:.>:.: ........ , .................... ; ....................................... . .... . ........ ;:;:;:;:;:;;;:;:;:;:;:;:;.5:: .... :::::::::::::::::::::::::::::::::::::::::::::::: ':~:~:':~'~'~:'::.".'..'::'::'::':::':'::' : ::';: ' .'- ................................. Questions? Call Jeff Spencer 659-7226 Prepared by Robert Christensen 659-7535 24 2002 SUBMIT IN DUPLIOATE 2N-326 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary lil0102iConversion from Oil Producer to WAG Injector completed. Commenced'WAG Injection Iservice. WELL LOG TRANSMITTAL To: State of Alaska October 9, 2001 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2N-326, AK-MM-00217 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2N-326: Digital Log Images 1 CD Rom RECEIVED OCT 1 Oil & Gas .Cons. Anchorage WELL LOG TRANSMITTAL To; State of Alaska Alaska Oil and Gas ConseIvation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 24, 2001 RE: MWD Formation Evaluation Logs 2N-326, AK-MM-00217 1 LDWG formatted Disc with verification listing. APl#: 50-103-20351-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ~ ATTACHED COPY OF THE TRANSMHTAL LETTER TO THE ATTENTION OF: Sperry-Stm Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: RECEIVED 8EP 7 2001 Aladm Oil & Gas Cons. Oomm'msion Anchorage "' STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance_ Perforate_ Prod-> MWAG Inj Other _X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 76' FNL, 834' FEL, Sec. 3, T9N, R7E, UM At top of productive interval 1448' FNL, 149' FEL, Sec.32, T10N, R7E, UM At effective depth 1480' FNL, 55 FEL, Sec. 32, T10N, R7E, UM At total depth 1276' FNL, 629' FEL, Sec. 32, T10N, R7E, UM 5. Type of Well: Development mX Exploratory _ Stratigraphic I Servia__ (asp's 460757, 5911930) (asp 's 450897, 5915897) (asp's 450991, 5915865) (asp 's 450418, 5916070) 6. Datum elevation (DF or KB feet) RKB 155 feet 7. Unit or Property name Tarn Unit 8. Well number 2N-326 9. Permit number I approval number 200-155 10. APl number 50-103-20351 11. Field / Pool Kuparuk River Field/Tarn Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 140' SURF CASING 4140' PROD CASING 11801' PROD CASING 813' PROD CASING Perforation depth: measured Size 16" 7-5/8" 5-1/2" 3-1/2" 12306'-12316' true vertical 4939' - 4943' 4spf Tubing (size, grade, and measured depth 12775 feet Plugs (measured) 5076 feet 12137 feet Junk (measured) 4885 feet Cemented 8 cu yds High Early 410 sx as III Lite & 240 sx ClassG 180 bbls ClassG Included above Packers & SSSV (type & measured depth) 3-1/2", 9.3#, L-80 Tbg (~ 11949' MD. ~'MD. CAMCO 'DS' @ 483' MD. 12642 MD none Measumd Depth 140' 4295' 11956' 12769' True ve~ical Depth 140' 2299' 4828' 5074' RECEIVED JUL i'Zo01 Oil & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal i Detailed operations program i BOP sketch 15. Status of well classification as: 14. Estimated date for commencing operation Convert to injection 12/2001 16. If proposal was verbally approved Name of approver Date approved Oil .~X Gas i Suspended Service 17. ' herein7 t.~hat the fo~oing is true and correct to the best of my knowledge. Questions? Call Jason Putnam 265-8970 Date 7//'~ l /() ~ Prepared by Kelli Wilrnot 265-6309 FOR COMMISSION USE ONLY , Approved by 0_rde_rpf_the _C_o.m_mjs_sion I Approva~l~ form -i u-4uo mev UOl-i OlOO · Conditions of approval: Notify Commission so representative may witness Plug integrity i BOP Test_ Location clearance Mechanical Integrity TestJ~"~ Subsequent form required 10- Original Signed By r_.,mmv I'lochsli ORIGINAL Commissioner &UBfviiT iN T~,i,'UC~TE PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY NIP OD:3.500) TUBING (0-11349, 0D:3.500, ID:2.992) Gas Lift andrel/Dummy Valve 1 (3789-3790, OD:4.725) Gas Lift andml~ummy Valve 2 (7867-7858, 0D:4.725) Gas Lift andrel/Dummy Valve 3 (1O347-1O348, 0D:4.725) SLEEVE (11840-11841, 0D:3.500) Gas Lift MandrelNalve 4 (11882-11883, OD:4.725) NIP (11926-11927, OD:3.500) SEAL (11934-11935, OD:4.000) FRAC (12306-12316) Peff (12306-12316) KRU 2N-326 2N-326 APl:. 501032035100 L__ SSSV Type: Annular Fluid: I Reference Log:; Last Tag:~ 12317 Last Tag Date: ~ 7/2/2001 Casing String - ALL STRINGS Well Type:: PROD Odg__C_0__mpletion:, 11/2/2000 Last WlO:! Ref Log Date:' TD: '. 12775 ffKB Max H_ ol__e_A_~ngle: :_~_75 deg_l~ 12775 An Ig~_~ TS:; deg_~. ~An_n.q~_~ TD:, 75 deg._~_127__75 Rev Reason: 'Tag_by line Last Update: ', 714/2001 Description - CONDUCTOR SURF CASING Size 16.000 Top ' BoEom 0 ' 140 TVD 140 Wt 'Grade 62.50 i H-40 Thread 9.30 ~ L-80 WELDED I 7.625 0 4295__ 2299 !29.70 ; L-80 BTCM PROD CASING : 5.500 0 ! 11956 4828 [ 15.50', L-80 LTC-MOD PROD CASING 3.500 11956 ~ 12769 5074 8RD EUE _T_ubing S___~ng - TUBING____ Size ; To.p Bottom I TVD ~-~t Gmde l Thread 3.500 I 0 11949 ! 4826 L_ 9.30 L_-80 i 8RD EUE Zone~_S_tatus_~_F_t L~..P_~ Date [_~1~_1 Comment ERF 2.5" BH HSD; 180 deg ph; w/4000# whp. Perforations Summary Interval I TVD 12306 - 12316 4939 - 4943 Stimulations & Treatments 12306 - 12316 L 1117/2000 _LFRAC Placed 22.2._MI b__ss prop_b.e_ hi_n~..p, ipe. Gas Lift Mandrels/Valves I St l MD I TVD I Man I Man I V Mfr I VType I V OD I Latchl .orr I TRO I O,te I Mfr Type Run ['-14--3~~ Camco KBG-2-9 - DMY L 1.0 DCK 0.000 L--0J10/31/2000~ L 21 7857L-34731 cam_co_J KBG-2-9 L L DMY [___1.0 _LDCK I 0.000 L--~_--~.l_-0J31/2000] [_-3__j10_~._~3_02_] CamEo-~-~'-/ ....... .L-D-~---[_'L-~-| DCK I 0.000 E4--~~4_~3-~-Ca--~-~-~--__~'--KBG-2-9 ! .-----__L---o-~--I._l_.O__L BTM [_0.313 Vlv Cmnt Other( ~lugs, equip., etc.'~- JEWELRY _De_E.th _TVD Type 483 483 NIP Camco 'DS' Nippl -11840 4790 SLEEVE Baker CMU Slidir 11926 4818 NIP Camco'D' Nipple 11934 4821 SEAL Baker 80-40 Csg 11950 4826 'ITL Tubing Tail 11956 4828 XO Crossover; 5.5" B Description__ ID 2.875 g. Sleeve 2.813 lo-Go profile 2.750 ~ea./_As_s_y; 4" OD x 2.985." ID Locater__ 2.985 2.992 5.5" BTCM Box x 3.5" 9.3# L-80 8rd EUE Pin 2.992 07/27/01 11:01 FAX 002 . Schlumberger Stimulation Service Report PHILLIPS ALASKA lNG 2D18~E~'7 2n 326 Prudhoe I:lay, AK 11/'7.~00 m,_ .J ...... . Tarn ,, . Clear~afld~he 45 ' iS in 12,~36 It 5,~52 It c..W ..t.~.,%~.. ~.j~ ....... a.sT ,~T .[ PO,.~,ms 029 Alaska 3000 psi ~45 'F ~20'F 0.5~ psi/It Rig Nam ' ' Drille4 hr ---- , NewI Development 0 O O YFIOOD 50 lb/lO00gal lb/gal O.~, sb. b' W~BM, mm OMB 8,~v~, LI,e Jol~ 'rylm 11G60 Fracturing . Fm=,Wide(YF1 xx.axx) 0 ..... 95(Z) psi 3500 psi J 3 1/Z' 9~ TIS ?Qp, ~t le~,~ a qw. N~'d ~lue~ s..~k" ~.~':, ..... '" 12306 12346 4 160' ' 40 YF-150D Frac w'Rh 21000CW 12/18 carbolite 16000~ 20/40 carbolite 0. 0 ' --(i. 0 ,. , _ o o o o o5. in 1'mat Down I)isHac.ma--- Paek~, llrlm - T,_,~ng 107 kkJ None 0 11/7A:X:) 6."~ t 11/7/00 6.'00[ 11/7/00 15:_~_ 107 bbl 0 I~1 0 bbl 1C)Tbbi l';,v=T. pRE" AN~,~.~ ~Um ~ ~&--.,~ PROP~N' ~O~PROP .' ' o o "~ '~'lP. sUge 24 'hr eJock ?R PRIEGS psi 'l~l/~lm I)bl PPA lb · O ~o:5~' 9~ ~0~ ' ' o.6' ' o.o o.o ' o " .d o ~ir~.~ 11.'08 8542 . 3633 33.3 95.6 0.0 ' 0 0 0 ~-'½,ge at Parrs: Pre Pad ' 11:08 6656 3521 3~.6 115.4 0.0 0 '0 .... 0 A~Uv__~ed__ ~'~_~ ~ .-.~.~' 21:20 . 77'1 ~S 0.0 192.4 0.0 0 0 0 L~~ Extend Stage' ' , 1,1:20 769 3380 . .. 0.0 .... 192.4 0.0 0' ' 0 ' 0 ~J~,ecl c°ndJtJon Autom~cally. 11:30 !J.JJ. . ,3~33 35.4 ' 230.7 0.0 0 '-0 0 ~arted ~ stage Automatically !1:30 7127 ~ , 33,0 ~42.4 0.0 ....0 0 0 ' _F;~md Pun~ng ~ 11:32 .6839 366? ..... 35,0 265,7 0.8 ;~= 0 0 - ~'~ed. Scour Rush Aut~..mlly 11:32 6331 3646 35.1 300,.8 .... 0.9 1910 "1~ 0 s~,.je at Peres: condium 11'32 6203 3629'" 35.0 307.8 5.9 i174 0 ' 0 ' $~r~ ~Jr ~'.~ .li:~t 694;i 74~1 ......35'.1 "335.8 1.3 2926 0 "' 0 F?ge at Perfs: Scour stage _JJ_;~_~ _ _65_55.' ...... _373.2 ...... _3S.0 J~/.9 1.3 ~74 0 0 ' St.~Fe~ Pumpk..3 F,~, ,11:35 6592 ~_.co 35.0 j/u.8 0.0 42~_4 0 0 ~tivated ~ Stage .... 11:35 6354 3679 35.0 405.8 0.0 4~4 0 0 ~;,age at I=e~: ~:~ur Rush ~-1:36 6~54 3~'2 34,9 408.1 0.0 4:~4 0 0 St~je at Parrs: Scour Flush 11:42 847. '" 339Y, '" '0.0' "'q~8'.6 0.0 4~_~_4 0 0 ' -~,;9~cUvad:ed EXtend S~.' -- '" ,il · 11:42 8s1... ~2 0.0 448,6 0.0 4224 o. 0 ~t~rted DataFrac Aura. maUc~¥ '- 12:13 6839 3726 31;8 54.1.7 0.0 4224 0 0 ~age at Per[s: DMaFrac ' 12:18 6912 3527 35.0 716.7 0.0 422,~ 0 0 ~tarted DalaFrac Ru Automatically 12:2~ s~2 3~ 35.~ 856.9 ' ' 0:0' 4224 0 0 N,,~_-_-~ Pre Pad~,~&.~aU~'..~y .... 13:05 906 3~09 0.0 ' 857.7 ' (~,0' ' 4224 O 0 5t.age at, Fe~: _r'~__*_...F-~. Flu 13:08 ~z~' 3505 §~,.9 941.4 0.0 e,22~, 0 0' _S.tage at Parrs: Pre Pad _1_~:15 s~$ .. 3S36 ~.0 1186,3 0'.0 4~4 0 0 Sta~ Elr-~e~t~; A,'~-.,._~;~:;V 13:18 .;663 3578 3,~.7 ' '1321,0 0.0 4224 0 0 ~.age at Parrs; BracketFt~ _13:U ~,? 3626 34.? 1425:1 0.0 4224 ' 0 ' 0 - s~rted Brackelf'Sac Autom0th:aily 13:26 5818 3565 22.2 1553.6 ' 0.0 42:~ 0 0 ~age at Perfs~ Bracketr-rac - .13:49 .6116 35O8 20.0 2C)40.5 0.0 4~:)4 0 0 garted Pad A~tJc~il¥ 13:54 '6702..... ~l 34.~ 21:~.1" 0.0 · '42~_d 0 0 . ~;._96 at ,-,,~.,-~---. F,a~' . ~14:11Nov 7.~<-:-~';-,-~aPun-~ngw.o..~R 35O8 35.0 2,~.8 0.0 4224 0 0 ..... ,$ta,~e.~ 2.O PPi .A.~_o,~.~_;~;¥ -- Page 1 of 2 07/27/01 11:01 FAX _ _ {~]001 ,,,, · 2n ~ Tam PHILLIPS ALA$1CA 1NC 201 ~"~ ?ime ?R PREU ~U~FRE~ &LU~]~A?"r TOT SLUR ~O~ ~ON ¥~ PRO~ d d Mes~,~e 24hr ~ 'IR PRESS psi bbl/ll~ bM PPA b 0 d ~4:~! 5077 3479 24.9 ~726.4 0.0 4224 0 0 ~Sl~'t~i Pumping Prop 14:16 4578 3408 25.0 2851.6 2.0 11736 0 0 S~]e at Perfs: 2.0 PPA -~4:~9 4495 3549 25.0 ., 2926.7 2.0 27614.. , 0 0 Start~l 3.0 PPA Aut~mtafically ... 14:24 4367 3503 25.0 3051.8 2.7 28354 0 0 3~.ge at Perfs: 3.0 PPA 14:31 4701 3541 25.0 3227.0 3.8 49172 0 . .. 0 Started 4,0 PPA Automatically 14:35 5017 3514 25.0 3352.1 3.9 66816 0 0 Stage at Per/s: 4.0 PPA 14:47 5498 3560 25.0 3627.3 3.9 105751 0 0 S~rted 6.0 PPA Manudly. . 14:5:1 5118 3442 25.1 3752.5 5.0 125335 0 0 Suge at Perfs: 6.0 PPA .. 15:02 5965 ~t72 25.0 4027,7 8.0 281012 0 0 Started 8.0 PPA Hanually 15:02 5956 3470 25.0 ....... 4029~ 8.1 281534 0 0 ~c~'~dted. .. Extend Stage 15:07 6239 3569 25.0 4127.8 9.2 206~:~1 0 ,, 0 S.~ge at Perfs: 8.0 PPA 15:10 ' 6358 3526 25.0 4227.9 ..... 10.0 235367 0 0 .~.. ,d_-.d IRush Hanually 15:10 .M Flush Ha~ 3532 25.0 4202.9 10.0 228057 0 0 De~'tivated Extend ..S~sge , , . 15:11 6303 3499 25.0 4252.9 0.1 238404 0 0 ~.;~Ped Pumping Prop. . Post Job 'Summary, Averse ~nj~Uon R;~,=, bpm ' Vol,~e of ~lui~' in~,d. U~ fluid N2 OC)~ M~ilmm Rib Olelll Fluid Alld Oil. OO~ li~ (sc~ ~o I o I o I ~ .o'~.,I.,o i o I o o, ......... ~ Treating Pressure Summary, psi ~uantity of 20/40 Carbo-Lie & 12/18 Carbo-L~ placed, II ~r~ak~w~ Maxi~mm Filml A¥.mge I$1P ~ Mi.,. I$1P Tetal I.Jeg~d 'i'otM O~rmUDeMWtml '~ I~ ! ,~= [~ I~= i 0 ~'~' L, ,,~=~' ~,.th.FergusonI .vance Yoa~..m 17 0.67 psi/n E] ,,m.,o..,.. Nov 7,2000 WRS3 V3.D,~R Page 2 of 2 Phillips Alaska Drilling Cementing Details Well Name: 2N-325 Report Date: 1110112000 Report Number. 25 Rig Name: Nabors 196 AFC No.: AK0116 Field: TARN · Casing Size Hole Diameter: Anglethru KRU: I ShoeDepth: LCDepth: 1%washout: ~-112 X 3-1/2 7.5 74 12759 12642 Centralizers State type used, intervals covered and spacing Comments: 18 3.9X6.5 SPIRAL J'IS 8-21, 7 STRAIGHT BLADE 3.9 X 6.5,17 BOW SPRING, 9 CENTERING GUIDES THRU SURFACE CSG. Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 10.5 15 15I 10 10 LSND Gels before: Gels after. Total Volume Circulated: 4/7 1.5 Wash 0 Type: Volume: Weight: Comments: RRCO Wash 20 8.4 Spacer 0 Type: Volume: Weight: Comments: MUDPUSHXL 28.44 11.0 Lead Cement 0 Type: I Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: GI 75 85 BBLI 10.7 1.99 Additives: .2% 1346, 8.0% D20, .3% D65, .6% D167, .06% DS00 Tall Cement 0 Type: I Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: GI 75 95 BBLI 15.8 1.2 Additives: .2 gps d47, 3.0% d53, .6% d65, .13% dS00, 2.0 gps d600, .15 gps d135 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 4 3 160 unable to reciprocate Reciprocation length: Reciprocation speed: Str. Wt. Down: Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 290.2 290.2 Calculated top of cement: I CP: Bumped plug.~' I Floats held: I Date:1111100 yes /I yes Time:04$0 {emarks:difflculty getting csg past 9200', ,-- _ -- Cement Company: Dowell IRig Contractor: NABORS Approved By: R.W. SPRINGER C,'tAmCZL n,T CX::'r'z E O T. - TOP ~3 -", inet: Shoe: ~ TVD; : : .iD Hole S: ~ ~/~' :ze and iNTEGRITY - P.&RT fl Annulus Press Test: iP .~S'Oo I 15 min ; 30 rain . · ~ .~. ' ,.. I '% ~--CF~_NiC=*_L iNTEGKITY - PART f2 Cement Volumes :' 3ant. Liner Cat vol to cover oerfs Theoreuical TOC Cement Bond Log (Yes or No) ~ ; In AOGCC File '- ,' Production Log: Typ.e Evaluation CONCLUSIONS: Part fl: 7/19/2001 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1303 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color 1J-03 7_/']1-. 0~.,.Zj~ SBHP 06127101 ID-101 _7_~_ -.-/~'~, INJECTION PROFILE 06121101 ID-107 2_~0_-/1'/' INJECTION PROFILE 06124101 1D-128 ~ --/~ ~ INJECTION PROFILE 07106101 IR-26 /~/'., O~l~z INJECTION PROFILE 06/02/0t 2^-19A ~,,~.O;,~ SB,P STOPS 05117101 2F-08 1~-.~2) PRODUCTION PROFILE 06125101 2G-9 /~,tl~h, ifO~ GAS LIFT SURVEY 07103101 2G-09 / ~'/0 ~ PRODUCTION PROFILE 07114/0t 2N-326 ~ I~ PRESS & TEMP BASELINE 0710~01 2N'326 ~ e~"155 WFURST/PSP 07104101 2V-03 ~- ~ WFURST-A 06109101 3H-3t J~- ~/~ INJECTION PROFILE 06130101 3J-07A ~' e~ 8BHP SURVEY 06119101 3M-01 /~--~l[ INJECTION PROFILE 06129/0t ~o-0s /~- o~ ~N~ECT~ON .RO~LE 30-10 /~- ~ INJECTION PROFILE 07105101 30-19 I~- ~ RST BO~WLDL 06104101 C. ~ _~""~-' DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 56t-8317. Thank you. RECEIVED JUL 30 2001 Schlumberger NO. 694 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print ;/-cc,- 1 D-34 STATIC RECORDIPRESS/TEMP 001026 I 1 1H-02 PSP PRODUCTION PROFILE 001030 I 1 2D-13 PRODUCTION PROFILE-GLS 001108 I 1 '2N-326 SBHP/SBHT LOG 001106 I I /?3- ~'o,,~ ~ 11115100 DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 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 December 11, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & (}as Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for 2N-326 (200-155) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on 2N-326. If you have any questions regarding this matter, please contact me at 265-6434 or Brian Noel at 265- 6979. Sincerely, J. Trantham Drilling Engineering Supervisor PA1 Drilling JT/skad RECEIVED DEC ! 2 Z000 AJaska Oil & Gas Cons. Commission Anchorage WELL COMPLETION OR RECOMPLETION REPORT AND LOG 11 Status of well Classification of Service Well o,, 171 ~ 0 su~nd~ 0 ~.don~ 0 Se~c~ D 2. Nm of ~or ~~ 7. Pe~ Numr Phillips N=~, Inc.~ 2~-1~ / 3. A~m~ _'~: 8. ~1Nu~er P. O. Box 10~, ~chora~, AK ~510-~60~ ~10~2~51-00 4. L~n of well at suda~ ~~ 9. Un~ or L~ N~ 79' FNL, 8~' FEL, S~. 3, T9N, R7E, UM (ASP: 460757, 5911930) ~., :.... '..' ,.: ;,.. ; Kuparuk River Unit At T~ Pmdudng Inte~al '. ': ... 10. Well Nu~r 1~8' FNL, 14~ FEL, Sec. 32, T10N, R7E, UM (ASP: ~0~7, 5915897).~ ~.~. '.~D. .... ~ 2N-326 .... At Torn D~th ;; ,'-:;: -:;-';;' : 11. F~ld ~d P~I 1279' FNL, 6~' FEL Sec. 32, T10N, R7E, UM (ASP: .0418, 5916070) ~~ ...... ~ Kuparuk River Field 5. Elevation in f~t (Indbate KB, DF, etc.) ~6. Le~e Designation and Se~ No. T~n P~I RKB 35', Pad 119 f~t~ ADL 3751 ~ & 3~0~ & 375074, ALK 43~ 12. DUe Spudded 13. DUe T.D. Rea~ed 14. D~e Co~., S~p~~d.ils. Waer ~th, B off. om 16. No. of Co~tbns Oc~ber 9, 2000 October 29, 20~ Novembe[~~ N/A fe~ MSL 1 17. Tot~ Depth (MD + TVD) 18. Plug B~k D~th (MD + TVD) 19. DIm~ion~ Suwey ~20. Depth where SSSV set 21. Thb~e~ of Pe~m~ 12775' MD /5076' ~D 12642"'~MD /504~ ~D YES ~ No n'~ N/A lea MD 1293' 22. T~e Ele~dc or ~her Logs Run G~Res/Den/Neu, CCL, SCMT 23. CASING, LINER ~D CEMENTING RECORD S~ING DE~H MD c.s~m s,z~ ~.,~. ~. s~=~ ~o, ~owo~ .o~ s,z~ c~m=~.S.E~O.~I .=ou~ ~s' s=.~ H-~0 Sur~ ~0' 2~' ~ =u ~..~ ~ - - 7.625" 29.7~ L-80 Suda~ 4~5' 9.875" 41o sx AS III Lite & 240 ~ Cla~ G 5.5' x 15.5~ L-80 Su~a~ 119~' 7.5' 180 bbls CI~ G 3.5' 9.3~ L-SO 119~' 12769' 6.75' (Includ~ ~ve) ~ ~ C ~ ~uuu Alaska 011 24. Pe~orations ~n to Pmdu~ion (MD + TVD of Top and BoSom ~d 25. ~BING RECORD Intew~, size and number) SIZE DE~H SET (MD) PACKER SET (MD) 3.5" 11950' 11937' (CSR) 123~'-12316' MD 4939'-49~' ~D 4 spf 26. ACID, F~CTURE, CEMENT SQUEEZE, ETC. DE~H INTERVAL (MD) AMOUNT & KIND OF ~TERIAL USED 12306'-12316' Pump 2222~ behind pipe, le~ 16162~ of 1~1~1 ~1~! ,IA~ 27. PROD~TION TEST Date FI~ Produ~lon Meth~ of Operation (Flowing, g~ lift, etc.) November 24, 2000 Flowing Date of Test ~oum Tea~ Pmdu~bn for OIL-BBL ~MOF WATER-BBL CHOKE SIZE ]~S-OIL ~TIO 1~10/2000 6.0 Tea Pedod > 129 62 14 1 ~~ 478 Flow Tubing C~ng Pressure C~culated OIL-BBL ~MCF WATER-BBL OIL GRAV~ - ~1 (coif) pmk. 483 p~ 982 24-Hour Rate > 517 247 ~ not avall~ 28. CORE DATA B~f de~dptbn of Iitholo~, pom~, fm~ums, ~amnt dips ~d p~n~ of oil, g~ or water. SubmE ~m chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit In duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include Interval tested, pressure data, all fluids recoverecl and gravity. MEAS. DEPTH TRUE VERT. DEPTH GeR, and time of each phase. T-3 12137' 4885' T-2 12348' 4953' Annulus left open - freeze protected with diesel. RECEIVED DEC 1 Naska 0il & Gas Cons. Commission Anchorage 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Brian Noel 265'-6979 Signed ~ ~ ~ . Title Kuparuk Drillln.q Team Leader Date ~ t James Trantharn Prepared by Sharon AIIsup-Dral~e INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate 'none". Form 10-407 Date: 11/29/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-326 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: TARN PARTICIPATING AREA SPUD:10/09/00 START COMP: RIG:NABORS 19E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20351-00 10/08/00 (D1) TD/TVD: 146/146 SUPV:R.W. SPRINGER MW: 9.7 VISC: 93 PV/YP: 29/38 (146) SPUDDED g 0300 HR.GYRO @253' APIWL: 10.0 Move rig module to well 2N-326. Rig accept @ 1600 hrs. 10/8/00. Nipple up diverter system and function test. 10/09/00 (D2) TD/TVD: 735/146 SUPV:R.W. SPRINGER MW: 9.9 VISC: 62 PV/YP: 22/37 (589) DRILLING @ 934' APIWL: 9.8 Check diverter stack f/leaks. Drilled from 146' to 735' 10/10/00 (D3) MW: 10.2 VISC: 53 PV/YP: 25/25 APIWL: 7.0 TD/TVD: 1269/1182 (534) DIR DRLG 9 7/8' HOLE @ 1430' (RIG BACK ON HI LINE POWE SUPV:DEARL W. GLADDEN Dir drilling 735' to 976'. Pump sweep, circ hole clean. TOH. Check bit. Hold spud meeting. RIH. Dir drilling from 949' to 1269'. 10/11/00 (D4) MW: 10.2 VISC: 50 PV/YP: 11/23 APIWL: 6.4 TD/TVD: 2206/1647 (937) TIH ( RIG ON HI LINE POWER LAST 24 HRS - NO PROBLEMS) SUPV:DEARL W. GLADDEN Dir drilling 1269' to 2206' MD. Pump sweep, circ hole clean. 10/12/00 (D5) MW: 10.2 VISC: 50 PV/YP: 24/17 APIWL: 5.0 TD/TVD: 3023/1907 ( 817) DIR DRLG 9 7/8" HOLE @ 3366' ( RIG ON HI LINE POWER LA SUPV:DEARL W. GLADDEN TOH. C/O bit. Wash and ream from 2073' to 2206'. Dir drilling 2206' to 2614'. Work pipe and clean up, hole packing off, circ and work until clean. Dir drilling 2614' to 3023'. 10/13/00 (D6) MW: 10.2 VISC: 50 PV/YP: 22/19 APIWL: 4.8 TD/TVD: 4223/2277 (1200) WIPER TRIP TO HWDP - (RIG ON HI LINE POWER LAST 24 HRS SUPV:DEARL W. GLADDEN Dir drilling 3023' to 4223'. 10/14/00' (D7) MW: 10.2 VISC: 47 PV/YP: 22/17 APIWL: 5.0 TD/TVD: 4303/2301 ( 80) P/U LANDING JT & CMT HEAD SUPV:DEARL W. GLADDEN Dir drilling from 4223' to 4260'. Pump sweep, circ until clean. Wiper trip to HWDP, no swab, no tight hole. Dir drilling from 4260' to 4303'. Surv, pump hi vis sweep. Circ and condition mud to run casing. Run 7-5/8" casing. Date: 11/29/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 10/15/00 (DS) MW: 9.6 VISC: 44 PV/YP: 44/14 APIWL: 7.0 TD/TVD: 4303/2301 ( 0) TAG CMT ~ 4103' - CIRCU FOR CSG TEST SUPV:DEARL W. GLADDEN Circ and condition to cement casing. Cement 7-5/8" casing. Did not bump plug. No cement to surface, check floats, held. TIH w/Tam tool, latch into TAM, shut Tam collar and test to 1000 psi, OK. PJSM. Wash out cement and N/D diverter system. PJSM. Continue wash out cement and N/D diverter. N/U BOPs and test to 300/3500 psi. Annulus tested 300/2500 psi, no failures. 10/16/00 (D9) MW: 9.6 VISC: 45 PV/YP: 13/11 APIWL: 6.2 TD/TVD: 4303/2301 ( 0) DIR DRLG 4 3/4" X 7 1/2" HOLE @ 4906' (RIG ON HI LINE SUPV:DEARL W. GLADDEN TIH, tag cement @ 4103'. Test casing to 2000. Drilling cement and float collar 4103' to 4294'. Continue drilling FS, cement +30' new hole 4303' to 4333' MD. Circ, C/O to LSND 9.5 ppg mud. Circ and condition for LOT. PJSM. Perform LOT, 16.0 EMW. Dir drilling 43.33' to 4705'. 10/17/00 (D10) MW: 9.6 VISC: 46 PV/YP: 15/14 APIWL: 5.0 TD/TVD: 5589/2724 (1286) DRLG ~ 5905' (RIG ON HI LINE POWER LAST 24 HRS- NO PRO SUPV:DEARL W. GLADDEN Dir drilling 4705' to 5589'. 10/18/00 (Dll) MW: 9.6 VISC: 47 PV/YP: 15/12 APIWL: 4.4 TD/TVD: 6525/3041 (936) DIR DRLG 7 1/2" HOLE @ 6710' ( RIG ON HI LINE POWER LA SUPV:DEARL W. GLADDEN Dir drilling from 5589' to 6094'. Surv, record SPR, pump sweep, circ hole clean, rotate and recip DP. Wiper trip to shoe. Dir drilling from 6094' to 6525' 10/19/00 (D12) MW: 9.6 VISC: 47 PV/YP: 15/15 APIWL: 4.6 TD/TVD: 7358/3316 ( 833) DIR DRLG 7 1/2" HOLE @ 7560' (RIG ON HI LINE POWER SUPV:DEARL W. GLADDEN Dir drilling 6525' to 7358' 10/20/00 (D13) MW: 9.6 VISC: 46 PV/YP: 18/13 APIWL: 4.6 TD/TVD: 7358/3316 ( 0) DIR DRLG 7 1/2" HOLE @ 8277' ( RIG ON HI LINE POWER LA SUPV:DEARL W. GLADDEN Dir drilling 7358' to 7894'. Pump sweep. Circ hole clean. Stop pump, monitor for flow (static). Wiper trip to 6000', no swab, no tight hole. Circ 1 jt off bttm unitl ECDs below 11.0. Dir drilling 7894' to 8040'. 10/21/00 (D14) MW: 9.6 VISC: 46 PV/YP: 15/13 APIWL: 4.5 TD/TVD: 8938/3814 (1580) DIR DRLG 7 1/2" @ 9158' (RIG ON HI LINE POWER LAST 24 SUPV:DEARL W. GLADDEN Dir drilling from 8040' to 8938'. WELL SUMMARY REPORT 10/22/00 (D15) MW: 10.5 VISC: 48 PV/YP: 20/14 APIWL: 4.0 TD/TVD: 9571/4042 (633) TEST BOPS (RIG ON HI LINE POWER LAST 24 HRS -NO PROBL SUPV:DEARL W. GLADDEN Dir drilling from 8938' to 9571'. Pump hi vis sweep, circ hole clean. Monitor well (static), pump dry job. TOH to 7-5/8" shoe ~ 2298'. Circ and condition for LOT. 10/23/00 (D16) MW: 10.5 VISC: 41 PV/YP: 19/ 9 APIWL: 4.0 TD/TVD: 9571/4042 ( 0) DIR DRLG 7 1/2" ~ 9620' (RIG ON HI LINE POWER LAST SUPV:DEARL W. GLADDEN Cont. circu for LOT. Perform LOT, 16.0 ppg EMW. PJSM test BOPs and test to 250/3500 psi, PJSM. 10/24/00 (D17) MW: 10.5 VISC: 46 PV/YP: 20/14 APIWL: 4.0 TD/TVD:10133/4239 (562) DRILLING @ 10356' (24 HR HI-LINE POWER) SUPV:R.W. SPRINGER TIH, circulate bottoms up. Drilled from 9570' to 10133' 10/25/00 (D18) MW: 10.5 VISC: 46 PV/YP: 17/14 TD/TVD:10987/4239 (854) DRILLING @ 11175' (24 HR HI-LINE POWER) SUPV:R.W. SPRINGER Drilled from 10133'-10987'. APIWL: 4.0 10/26/00 (D19) MW: 10.5 VISC: 47 PV/YP: 15/13 APIWL: 4.0 TD/TVD:l1569/4239 ( 582) DRILLING @ 11780' (24 HR HI-LINE POWER) SUPV:R.W. SPRINGER Drilled from 10987-11271'. Circulate bottoms up, pump dry job and flow check. Short trip 18 stds to 9570', no tight spots, no drag. RIH to 11201'. Small diesel spill (1 gal). Ream from 11201'-11271'. Drilled from 11271'-11569' 10/27/00 (D20) MW: 10.5 VISC: 49 PV/YP: 16/12 TD/T1rD:12036/4239 ( 467) DRILLING @ 12147' (24 HR HI-LINE POWER) SUPV:R.W. SPRINGER Drilled from 11569' to 12036' APIWL: 4.0 10/28/00 (D21) MW: 10.5 VISC: 48 PV/YP: 15/13 TD/TVD:12176/4239 ( 140) RIH W/NEW BIT (24 HR HI-LINE POWER) SUPV:R.W. SPRINGER APIWL: 4.0 Drilled from 12036' to 12176'. Got stuck while rotating. Pulled free. circulate bottoms up, pump pill, monitor well. POH, tight spot at 4438', rotate and work thru tight spot, check for flow @ shoe. Down load FRT and change out mud motor. 10/29/00 (D22) MW: 10.5 VISC: 49 PV/YP: 17/13 APIWL: 3.5 TD/TVD:12775/5076 (599) POH AFTER SHORT TRIP (24 HR HI-LINE POWER) SUPV:R.W. SPRINGER RIH to 4375'. Ream from 12123'-12176'. Drilled from 12176'-12742'. Circulate bottoms up. Drilled from 12742' to 12775'. Date: 11/29/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 10/30/00 (D23) MW: 10.5 VISC: 45 PV/YP: 15/10 APIWL: 3.5 TD/TVD:12775/5076 ( 0) RUNNING CASING, CIRCULATING ~ 7-5/8" SHOE. (24 HR HI- SUPV:R.W. SPRINGER Circulation and condition, pump lo-vis sweep. Short trip to 12098'. Pump hi density sweep, spot torque trim pill. POH. PJSM. Set test plug, test all rams, HCR, hydrill and choke manifold to 350/3500#. PJSM. 10/31/00 (D24) TD/TVD:12775/5076 ( SUPV:R.W. SPRINGER MW: 10.5 VISC: 44 PV/YP: 15/10 0) NIPPLING UP CASING HEAD (24 HR HI-LINE) APIWL: 3.5 Ran 3.5" casing. Rig up to run 5.5" casing. Run 5.5" casing to surface shoe. Circulate bottoms up. Run casing to 9206', unable to get past this point. Circulate bottoms up and pump hi-vis sweep and SAPP pill, circulate hole clean. Rotate casing. 11/01/00 (D25) MW: 8.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12775/5076 ( 0) DISPLACING WELL W/SEAWATER (24 HR HI-LINE) SUPV:R.W. SPRINGER Circulate and condition mud. PJSM. Pump cement. Drop plug. Bump plug, floats held. Set packoff, test to 50009. R/U to run completion. Run 3.5" completion. 11/02/00 (D26) MW: 8.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12775/5076 ( 0) NIPPLE DOWN BOPE, NIPPLE UP TREE (24 HR HI-LINE POWER) SUPV:R.W. SPRINGER Finish running 3.5" tubing. Test casing to 3500 psi, OK. circ hole clean and displace w/ clean seawater. Freeze protect well. PJSM. 11/03/00 (D27) TD/TVD:12775/5076 ( SUPV:R.W. SPRINGER MW: 8.6 VISC: 0 PV/YP: 0/ 0 0) RIG RELEASED TO 2N-303 APIWL: 0.0 PJSM. Change top pipe rams from 3.5" to 4". PJSM. Nipple down BOPE and remove, N/U tree, test pack-off to 50009, tree and close all valves on tree. Rig released @ 1200 hrs. 11/03/00. PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-326(W4-6)) WELL JOB SCOPE JOB NUMBER 2N-326 DRILLING SUPPORT-CAPITAL 1103001612.2 DATE 11/06/00 DAILY WORK 10' PERF 2.5"4 SPF BH - STATIC PRES/TEMP DAY OPERATION COMPLETE I SUCCESSFUL 2 YES I YES Initial Tbg Press I Final Tbg Press I Initial Inner Ann 0 PSII 0 PSII 0 PSI DAILY SUMMARY KEY PERSON SWS-BARTZ Final Inner Ann I I 0 PSI UNIT NUMBER 2150 SUPERVISOR FERGUSON Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI IPERFORATE 12,306'-12,316' USING 2 1/2" BH HSD CHARGES. 4 SPF AT 180 DEG PHASING. PERF EOB WITH 4000 PSI WHP. PRESSURE DROP TO 1000 PSI AFTER SHOOTING. RUN STATIC PRESSURE/TEMP. PRESSURE 2066 PSI @ 12311' MD TIME LOG ENTRY 08:00 MIRU SWS UNIT 2150 & CREW. NOTIFY DSO RE: PERF. 08:50 CHECK SAFE SYSTEM ON SURFACE. MAKE UP GUN. 2.5" WHEELS BELOW HEAD & 2.5" WHEELS BELOW GUN. PT TO 3000#. ALL OK. 09:00 RIH. 10:30 10:45 11:30 TIE IN TO JEWELRY. ADD 6' DEPTH. TIE IN ACROSS ZONE. ADD 3' DEPTH. VERIFY TIE IN. CCL-TOP SHOT DEPTH = 9.7'. CCL DEPTH @ SHOT: 12296.3'. 1000# TP DUE TO DISPALACEMENT BEFORE SHOT. PRESSURED UP TBG TO 4000# USING TR~?_LEX..~. · ,~i~ PERFORATED INTERVAL: 1~306'-1~316'. TP=1000# SHORTLY AFTER SHOT. POOH. GUN AT SURFACE. TP--0. RD GUN; ALL SHOTS FIRED.MAKE UP PSP FOR PRES-TEMP. CHECK TOOLS. ALL OK. 11:45 RIH WITH 2 SETS. 2.5" WHEELS ABOVE. PSP & 2.125" WEIGHT. 13:00 TIED IN. START STATION LOG FOR SIBP/SITP @ 12311'MD. SBHP=2066, SBHT=134. 14:00 VERIFY TIE IN. STATIC PRESSURE/TEMPERATURE @ 11994' MD. SBHP=2020, SBHT=128. 14:20 POOH 15:00 AT SURFACE. RD. 16:00 LEAVE LOCATION. NOTIFY DSO. PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-326(W4-6)) WELL 2N-326 JOB SCOPE DRILLING SUPPORT-CAPITAL JOB NUMBER 1103001612.2 DATE DAILY WORK UNIT NUMBER 11/07/00 FRACTURE TREATMENT KEY PERSON DS-YOAKUM Final Inner Ann I 0 PSI I DAY OPERATION COMPLETE I SUCCESSFUL 3 YES I YES Initial Tbg Press I Final Tbg Press I Initial Inner Ann 821 PSII 800 PSII 0 PSI DAILY SUMMARY SUPERVISOR FERGUSON Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI PUMP BREAKDOWN AT 35 BPM AND 8000 PSI. GOT GOOD BREAKBACK. PERFORM SDT AFTER BD AND SCOUR STAGES. XS FRICTION CONSTANT AT 1100 PSI. PUMP DATAFRAC FOR ANALYSIS AND MATCH DESIGN. PUMP BRACKETFRAC FOLLOWED BY FRAC PER ORIGINAL PAD DESIGN OF 700 BBLS. GET GOOD NET PRESSURE DEVELOPMENT IN FLAT 4 PPA STAGE AND ELECT TO RAMP EARLY. INCREASE CONC TO 10 PPA AND GO TO FLUSH. SCREENOUT 59 BBLS INTO 104 BBL FLUSH. PLACE 222,2644f'S BEHIND PIPE WITH MAX CONC OF 10.1 PPA ON FORMATION. LEFT 16162#'S OF 12/18 IN WELLBORE.[ Frac-Refrac] TIME 08:20 09:45 10:30 11:00 11:30 11:40 LOG ENTRY ARRIVE LOCATION. DOWELL RU PUMP EQUIPMENT. SAFETY MEETING. PRIME UP PT LINES TO 9500 PSI START BREAKDOWN WITH 20# LINEAR GEL.. GOOD BREAK BACK A 35 BPM AND 8700 PSI. PERFORM SDT. ISIP=826 PSI. FG--0.61. XS FRICTION IS 1000 PSI AT 26 BPM. START SCOUR STAGES AT 35 BPM PERFORM SDT AFTER SCOUR STAGES. ESSENTIALLY NO CHANGE. XS FRICTION STILL AT 1100 PSI AT 26 BPM, ALL PERF FRICTION. ISIP=893 PSI, FG--0.62 PSI/FT 12:05 START 300 BBL DATAFRAC OF 50# X/L GEL AT 35 BPM. 12:20 SD FOR DF ANALYSIS 12:45 DATAFRAC RESULTS TC--8.9 MIN, PC=920 PSI, EFF= 41%, PNET=208 PSI. STIMPLAN CRASHING IN ANALYSIS MODULE. CLOSURE TIME MATCHES ORIGINAL DESIGN. WILL PUMP FRAC PER ORIGINAL PLAN 13:03 START 350 BBL PAD OF 50~ X/L FOR BRACKETFRAC AT 35 BPM 13:20 WELL PRESSURING UP SHARPLY WITH BRACKET FRAC ON FORMATION. OVER 2000 PSI INCREASE AT 35 BPM. SLOW RATE TO 22 BPM FOR FLUSH 13:45 START 700 BBL PAD FOR FRAC OF 50# X/L GEL AT 35 BPM 14:08 COMPLETE PAD AT 35 BPM AND SLOW RATE TO 25 BPM FOR SLURRY STAGES 14:40 APPEAR TO BE BULLING SOME NET PRESSURE MIDWAY THRU THE FLAT 4 PPA STAGE TIME 14:45 15:00 15:05 15:10 15:15 17:00 LOG ENTRY ELECT TO STAGE EARLY WITH GOOD NET PRESSURE BUILD. START RAMPING TO 8 PPA AT 400 BBLS INTO THE 500 BBL FLAT 4 PPA STAGE START WORKING RAMP UP TO 8 PPA MANUAL. START RAMPING TO 10 PPA MANUAL STARTED REDUCING RATE ON FLUSH WITH 10 PPA ON FORMATION. SCREENOUT 59 BBLS INTO 104 BBL FLUSH. PLACE 222,264#'S BEHIND PIPE WITH 10.1 PPA ON FORMATION. LEFT 16162#'S OF 12/18 PROP IN WELLBORE RDMO 17-Nov-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-326 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 12,775.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) .North SlOpe Alaska AlaSka State. Plane 4 Kuparuk 2N, Slot 2N-326 2N-326 Surveyed: 29 October, 2000 SURVEY'REPORT 17 November, 2000 Your Ref: APl 501032035100 Surface Coordinates: 59f1929.71 N, 4607'56.90 E {7'0' 10' f3. f88?' N, 209' 4f' O3.005?' E) " KellyBushing: 155.03ft above Mean Sea Level . A H,,lllburton Company Survey Ref: svy9335 North Slope Alaska Measured Depth - (ft) Incl. 386.00 3.200 295.000 421.92 4.280 297.120 452.91 5.310 294.120 483.01 6.590 292.950 512.85 8.090 291.150 540.95 9.560 575.55 11.180 603:78 .12.790 634.22 14.510 665.04 16.300 291.530 292.510 293.O0O 292.100 291.560 695.28 18.350 291.380 725.12 20.310 291.670 814.14 24.620 291.870 905.43 23.940 292.200 992.16 29.110 291.820 1087.89 35.000 290.610 1182;86 38.510 291.180 1283.00 45.540 290.530 1371.89 48.910 290.180 1466.43 '55.530 -288.940 1561.46 59.200 1656.53- 63.660 1750.89 62.840 1846.09 62.030 1940.87 63.040 289.360 290.140 290.200 290.600 290.180 Sub-Sea Depth (ft) 230.91 266.75 297.63 327.57 357.16 384.93 418.96 446.58 476.16 505.87 534.73 562.89 645.14 728.35 805.93 887103 963.10 1037.45 1097.81 -1155~69 1206.93 1252.39 1294.86 1338.91 1382.62 SPerry-Sun Drilling Services Survey Report for 2N-326 'Your Ref: APl 50f O32035 f O0 Surveyed: 29 October, 2000 Vertical Depth (ft) 385.94 421.78 452.66 482.60 512.19 . 539.96 573.99 ' 601.61 631.19 660.90 -689.76 717.92 800.17 883.38 ' 960~96 1042.06 1118.13- 1192.48 1252.84 1310.72' 1361.96 1407.42 1449,89 1493.94 1537.65 Local Coordinates Northings Eastings (~) (~) 0.16 N 3.86 W 1.19 N. ; 5.97 W 2.31 N -- 8.30 W 3.55 N 11.17 W 4.97 N 14.70 W 6.54'N 8.88 N -11.15 N 13.90 N 16.95 N GlObal Coordinates Northings Eastinga (~) (~) 20.24 N · 23.87 N 36.48 N 50.57 N 65.07 .N 5911929.89 N 460753.04 E 5911930.93 N 460750.94 E 5911932.06 N 460748.61 E 5911933.32 N .450745.75 E 5911934.76 N 450742.23 E 83.40 N 103.68 N '127.50 N 150.19 N- · 175.16 N 18.72 W 5911936.35 N 460738.22 E 24.49 W 5911938.72 N 460732.46 E 29.89 W 5911941.02 N 460727.07 E 36.53 W '5911943.80 N 460720.45 E 44.13 W 5911946.88 N 450712.86 E 201.41 N 229.63 N 258.68 N 288.10 N 317.40 N 52.51 W 5911950.22 N 460704.50 E 61;70 W 5911953.90 N 460695.33 E ' 93.28 W . 5911966.68 N 460663.81 E 128.07 W- 5911980.94 N 460629.09 E 163.97 W 5911995.63 N 460593.27 E 211.33 W - 5912014.21 N 460546.00 E 264.41 W 5912034.76 N 460493.03 E 327.03 W . 5912058.91 N 460430.64 E 388.19 W 5912081.91 N ' 450369.49 E 458.57 W 5912107.24 N 460299.24 E 534.16W 5912133.89 N 450223.80 E 612.71W 5912162.51N 460145.39 E 691.81W 5912191.98 N 450066.44 E 770.91W 5912221.80 N 459987.50E 849.73W 5912251.51N 459908.82 E Dogleg Rate (°/lOOft) 3.03 3.42 4.27 5.08 5.24 4.71 5.71 5.69 5.83 6.78 6.58 4.64 0.76 5.96 6.19 3.71 7.03 3.80 7.08 3.88 4.75 . 0.87 0.93 1.14 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 3.65 Tied on to Gyro 5.98 AK-6 BP_IFR-AK 8.57 11.69 15.50 19.81 26.04 31.90 39.08 47.27 56.27 66.15 100.16 137.69 176.41 227.19 284.01 350.99 416.21 490.64 570.77 654.19 738.42 822.79 906.87 Continued... .17 November, 2000 - 9:43 . . -2- DrillQuest 2.00.05 North Slope Alaska Measured Depth eft) Incl. 2035.83 2130.99 2225.33- 2320.22 2415.04 64.250 . 67.020 70.950 71.330 69.530 2510.17 2604.67 2699.49 2795.83 2827.84 70.480 71.940 72.820 71.590 70.930 2922134 72.290 3016.53 72.040 3111.84 72.490 3206.12 71.770. 3300.71 71.330 3395.39 71.130 3490.13- 71.690 3585.17 71.370 3680.52 72.200 3774.97 71.530 3870.15 72.690 3965.00 72.950. 4059.37 72.010 4154.23 73.310 4193.11 73.240 289.060 '289.000 2'88.940 288.980 288.690 289.440- 290.100 290.200 '290.640 290.380 290.880 291.040 . 292.000 . 292.460 291.760 29i.740 290.490 290.630 288.290 288.870 -288~540 288.58O 288.970 289.280 289.360 Sub-Sea Depth (ft) 1424.78 1464.03 1497.86 1528.53 1560~9 1592.82 1623.26 1651.96 1681.40 1691.69 1721.50 1750.35 1-779.38 1808.31 'i838.25 1868.7i 1898.92 1929.03 1958.83 1988.23 2017.47 · 2045.49 2073.90 -- 2102.17 2113.36 ! . . Sperry-Sun Drilling. Services Survey Report for 2N~326 Your Ref: AP150fO32035fO0 Surveyed: 29 October, 2000 Vedical -Depth (~) 1579.81 1619.06 1652.89 1683.56 1715.32 1747.85 1778.29 1806.99 '1836.43 '1846.72 · 1876.53 1905.38 1934.41 1963.34 1993.28- -' '2023.74 2053.95 · 2084.06 2113.86 2143.26 2172.50 2200.52 2228.93 2257.20 2268~9 Local Coordinates Nodhings Easflngs" (~) (~) - 345.96 N 929.88 W 374.23 N 1011.82W 402.85 N 1095.09W 432.02N 1180.01W 460.87N ' . 1264.57W 490.07N 1349.06W -520.33 N ' 1433.24W 551.46 N 1518.08W '583.46 N 1604.05W 594.08 N. 1632.44W 625.68 N 657.75 N 691.05 N 725.0O N ' 758.77 N' 1716.36W 1800.09W 1884.54W 1967.0OW 2050.73W 791.99 N 824.34 N 856.0O N 886.16 N 914.76 N 943.81 N 972.65 N 1001.61 N 1031.28 N 1043.60 N 2133.99W 2217.76W 2302.16W 2387.55W 2472.63W 2558.42 W 2644.33 W ' 2729.53 W ' 2815.08 W - 2850.22 W ' . . Global Coordinates 'Northings Eastinga (~) (~) 5912280.49 N 459828.82 E 5912309.18 N 459747.03 E 5912338.23 N 459663.92 E 5912367.85 N 459579.15 E -5912397.13 N 459494.74 E 5912426.77 N 459410.40 E 5912457.46 N 459326.38 E 5912489.03 N 459241.70E 5912521.48 N 459155.90 E 5912532.25 N 459127.56 E 5912564.28 N 459043.81 E 5912596.79 N 458960.25 E 5912630~53 N 458875.97 E 5912664.90 N - 458793.09 E 5912699.11 N 458710.13 E 5912732.76 N 458627.04E 5912765.54N 458643.45 E 5912797.63 N 458459.21E 5912828.24N 458373.97E 5912857.28 N 458289.04E 5912886.77 N 458203.40 E 5912916.06 N . 458117.65 E 5912945.46 N ' 458032.60 E 5912975.57 N 457947.20 E -5912988.08 N 457912.13 E Dogleg Rate ('llOOft) 1.66 2.91 4.17 0.40 1.92 1.24 1.68 0.93 1.35 2.20 1.52 0.31 1.07 0.89 0.84 0.21 1.38 0.36 2.49 O.92 1.26 0.28 1.07 1.41 0.27 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 991.89 1078.48 1166.42 1256.11 1345.34 1434.64 1524.05 1614.38 1706.09 1736.39 1826.05 1915.70 2O06.48 2096.21 2185.93 2275.58 2365.37 2455.49 2545.99 2635.61 2726.06 2816.54 2906.41 2996.87 3034.07 Continued... 17 November, 2000 - 9:43 -3- DrillQuest 2.00.05 Sperry. Sun Drilling Services Survey Report for 2N-326 Your Ref: AP1501032035100 Surveyed: 29-October, 2000 North Slope Alaska Measured Depth - -(ft) 4236.41 4372.41 4467.40 4562.07 4657.14 4751.56 4846,55 4941~36 5036.34 5130.74 5225.68 5320.55 5414.65 5510.15 5609.85 5704.66 5793--44 '- 5893.49 5988.39 6077.58 6172.05 6266.74 . 6361.76 6461.83 6557.21 Incl. 72.640 70.670 70.120 73.150 72.690 70.550 70.450 70.810 73.190 71.130 71.180 69.710 69.450 68.85O 70.520 '70.410 70,780 70.870 70.290 '71.160 70.080 70.640 68.960 67.240 68.310 28~540 288.230 289.160 293.100 293.660 291.490 291.150 291.600 293.400 293.250 292.560 292.730 292.880 292.660 · -292.780 292.820 292.150 292.070 292.470 -292.320 290.850 289.750 '290.480 291'.500 292.360 Sub,Sea Depth (ft) 2125.99 2168.57 2200.44 2230.27 2258.20 2287.97 2319.68 2351.12 2380.47 2409.39 . 2440.06 . 2471.81 2504.64 2538.63 2573.25 2604.95 .2634.45' . 2667.31 2698.86 2728:30 2759.65- 2791.48 2824.29- 2861.61 2897.69 Vertical Depth (ft) 2281.02 2323.60 2355.47 2385.30 '2413.23 2443.00 .2474.71 2506.15 2535.50 2564.42 .- - 2595.09 2626.84 2659.67 2693.66 2728.28 2759.98 2789.48 2822.34 2853.89 2883.33 2914.68 2946.51 2979.32 3016.64 3052.72 Local Coordinates Northings EaStings (ft) (ft) 1057.39 N 1099.20 N 1127.88 N 1160.29 N - 1196.35 N 2889.27W 3011:47W 3096.23W 3180.00W 3263.41W 1230.75 N' 1263.31N 1295.91N 1330.48 N 1366.06 N Global Coordinates 1401.03 N 1435.45 N 1469.63 N 1504.17 N · 1540.28 N Northings Eastings 5913002.07 N 457873.15 E 5913044.51 N 457751.17 E 5913073.63 N 457666.58 E 5913106.47 N .457582.96 E 5913142.96 N 457499.73 E 1574.90 N 1606.93 N 1642.50 N 1676.41 N- 1708.49 N 3346.14 W 5913177.80 N 457417.19 E 3429.55 W 5913210.78 N 457333.95 E 3512.84 W 5913243.81 N 457250.83 E 3596.28 W 5913278.82 N 457167.57 E 3678.79 W 5913314.82 N 457085.24 E 1'741.27 N 1772.21N 1802.88N 1836.13 N 1869A1N 3761.56 W 5913350.22 N 457002.66 E 3844:06 W 5913385.07 N' 458920.33 E 3925,36 W . 5913419.67 N 456839.22 E 4007.65 W- 5913454.64 N 456757.11 E 4093.89 W 5913491.20 N 456671.06 E 4176.26 W 4253.63 W 4341.18 W 4424.00 W 4501.84 W 4584.71-W 4668.35 W 4752.08 W' 4838.76 W 4920.67 W 5913526.25 N 456588.87 E 5913558.67N 456511.66E 5913594.69N 456424.30 E 5913629.04N '456341.65 E 5913661.52N 456263.98 E 5913694.74 N 456181.29 E 5913726.11 N 455097.81 E 5913757.20 N 458014.23 E 5913790.91 N 455927.72 E 5913824.31 N 455845.99 E Alaska State Plane 4 Kuparuk 2N Dogleg Vertical Rate Section Comment ('/loo~) · 1.01 3075.45 1.64 3204,45 1.09 3293.81 5.08 3383.62 0.74 3474.46 3.15 3564.04 0.35 3653.58 0.59 3743.02 3.09 3833.33 2.19 3923.15 0.69 4012.98 1.56 4102.37 0.31 4190.54 0.66 4279.77 1.68 4373.25 0.12 4462.58 0.82 4546.31 0.12 4640.81 0.73 4730.31 0.99 4814.49 1.86 1.24 1.91 1.96 1.40 4903.60 4992.75 5081.89 5174.73 5263.02 Continued,,. DrillQuest 2.00.05 17 November, 2000' 9:43 .4 - North Slope Alaska Measured Depth 6651.73 6740.78 6841.02 6935.53 7030.39 7120.04 7220.54 7309.20 7407.28 7501.72 7596:94 7694.04 7789.04 7882.94 7976.64 Incl. 70.640 69.890 69.850 70.800 71.420 72.820 70.940 71.210 71.220 72.040 72.530 ~.72.220 71.410 69.420 68.670 8070.80 71.130 8163.37- 71.680 8261.25 70.880 8355.04 72.590 8452.75 74.140. .8548.04 73.020 8636.30 72.850 8736.87 71,950. 8831.93 70.920 8923.87 70.780 Azim. 291.610 292~150 293.110 293.930 296.100 295.640- 295.020 294;750 294.650 294.160 292.880 292.090 291.470 ' 291.180. 291.550 293.1'90 292.860 292.050 291.440 292.120 29i.500 290.800 291.300 292.950' 294.260 Sub-Sea Depth (ft) 293O.83 2960.90 2995.40 3027.22 3057.93 308.5,46 3116,71 3145.47 3177.05 3206.81 3235.79 3265.19 3294.84 3326.31 3359.82 3392.18 3421.70 3453.11 3482.51 3510.48 3537.41 3563.31 3593.72 3623.99 3654.15 Sperry-Sun Drilling Services Survey Report for 2N~326 Your Ref: AP150fO32035fO0 Surveyed: 29 October, 2000 Vertical Depth (It) 3085.86 3115.93 315O.43 3182.25 3212.96 3240.49 3271.74 3300.50 '3332.08 3361.64 3390.82 3420.22 3449.87 3481.34 .3514.85 .- 3547.21 3576.73 3608.14 3637.54 3665.51 3692.44 . 3718.34 3748.75 3779.02 38O9.18 Local Coordinates Northings (ft) 1902.24 N 1933.47 N 1969.69 N 2005.20 N 2043.15.N 2080.38 N 2121.24 N 2156.54 N 2195.34 N 2232.37 N 2268.56 N 2303.95 N 2337.44 N 2369.62 N .. 2401.49 N 2435.15 N 2469.47 N 2504.88 N 2537.87 N 2572.61 N Eastlnga (ft) · 5002.74.W · ' 5080.52 W 5167.39 W 5248.99 W · 5330.32 W Global Coordinates Northings Eaatings (ft) (ft) 5913857.86 N 455764.09 E 5913889.50N 455686.47 E 5913926.17 N 455599.79 E 5913962.10 N 455518.38 E -5914000.48 N 455437.25 E 5407.08W 5914038.10 N 455360.68E -5493A1W 5914079.41N 455274.56E 5569.49W 5914115.10 N 455198.67E 5653.85W -5914154.33 N 455114.51E · 5735.47W 5914191.79 N 455033.08 E 2606.57N 2637.01N 2671.44N 2705.37'N 2740.15 N 5818.64 W 5914228.41 N 454950.10 E 5904.14 W 5914264.25 N 454864.78 E 5987.95 W .5914298.17 N 454781.15 E 6070.36 W 5914330.77 N 454698.91 E 6151.85 W 5914363.07 N 454617.59 E 6233.61 W 5914397.15-N 454536.01 E 6314.35 W 5914431,89 N 454455.44 E 6400.02 W 5914467,74 N 454369.95 E 6482.75 W 5914501,16 N 454287.40 E 6569.68 W 5914536.35 N 454200.65 E 6654.54 W 6733.23 W 6822.69 W 6906.17 W ' 6985.75 W 5914570.75 N 454115.97 E 5914601.60 N 454037.43 E 5914636.49 N 453948.15 E 5914670.86 N 453864.85 E 5914706.05 N 453785.45 E Dogleg Rate ('/100ft) 2.57 1.02 0.90 1.30 2.26 1.64 1.96 0.42 0.10 1.00 1.38 0.84 1.05 2.14 0.88 3.08 0.68 1.13 1.92 1.72 1.33 0.78 1.01 1.97 1.35 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 5351.53 6435.35 5529.45 5618.40 5707.99 5793.09 5888.41 5972.15 6O64.88 6164.41 6245.06 6337.60 6427.85 6516.31 6603.81 6692.22 6779.93 6872.63 6961.69 7055.30 7146.71 7231.08 7326.93 7417.04 7503.84 Continued... 17 November, 2000 - 9:43 DrillQuest 2.00.05 SPerry. Sun Drilling Services Survey. Report for 2N-326 Your Ref: AP1'501032035100 Surveyed: 29-October, 2000 North Slope Alaska Measured Depth ' '(ft) Incl. 9016.35 69.960 '9111.04- 69.010 9205.91 68.140. 9300.50 68.740 9400.97 68.490 .. 9492.00 68.800 9584:53 .68.110 9684.50 68.370 9779.51 69.150 9874.53 71.180 9969.91 71.630 10084.18 71.200 10155.90 70.970 10250.54 71,880 10345.53 70.280 10440.33 70.710 10537~97 72,550 10633.23 72~330 10728.13 71.680 10822.86 .71.930 -10918.26 7i.600 11010.71- 71.270' 11105.92 70.880 11202.84 70.130' 11292.24' 70.550 Azim~ 293~490 293.830 292.810 292.940 293.720 294.2O0 293.600 292.650 292.680 292.850 292.750 '291.800 29O,750 291.230 290.640 289.840 290.300 291,690 292.830 293.350 .. 293.790 293,740 294.770 294.340 295.150 . . SUb-Sea Depth 3685~22 3718.40 3753.06 3787.82 3824.45 3857.60 3891,58 3928.84 3963.06 3995.30 4025.72 4055.76 4085.50 4115.64 4146.44 4178.10 4208.87 4237.61 4266.93 -4296,51 4326.36 4355.79 4386.67 4419.02 4449.09 Vertical Depth (ft) 3840.25 3873,43 3908,09 3942.85 3979.48 4012.63 4046.61 4O83,67 4118.09 4150.33 4180~75 4210,79 4240,53 4270,67 4301.47 .. 4333,13 4363,90- 4392,64 4421,96. 4451,54' 4481,39 4510,82 4541,70 4574.05 4604,12 Local Coordinates Northings Eastings (ft) (ft) 2775,41 N 2811,00 N 2845,96 N 2880,15 N ' 2917,20 N Global Coordinates Northings Eastings (ft) (ft) 2951,63 N 2986,50 N 3022,96 N 3057.09N 3091.67N 7065,40 W 5914741,72 N 453705,98 E 7146,63 W 5914777,73 N 453624,94 E 7227,73 W 5914813,11 N 453844,03 E 7308,78 W 5914847.73 N 453463,15 E 7394,68 W 5914685,22 N 453377,44 E 3126.71 N 3160.58 N 3192.06 N 3224:19 N 3256,30.N 7472,16W 5914920,05 N 453300,15 E 7550,84W 5914955,33 N 453221,65 E 7636,23W 5914992.23 N 453136,45 E 7717,94W 5915026,78 N 453054,91E ~800,36W 5915061,79 N 452972,68 E 3287,07 N 3318,72 N 3351,26 N 3385,44 N' 3420,74 N 7683,70 W 5915097,25 N 452689,52 E 7966,38 W 5915131,55 N 452807.02 E 8047,23 W. 5915163,45 N 452726,33 E 8130,99 W' 5915196,02 N 452642,74 E 8214,91 W 5915228,57 N 452558,99 E 3456,97 N 3492,29 N 3529,28 N 3567,25 N 3602,49 N 8298,81 W 8385,89 W 8470,68 W 8554,21 W 8637,00 W 8720.04 W 6800,25 W 8882,36 W 8965,46 W 9041,92 W 5915259,77 N 452475,25 E 5915291,87 N 452388,33 E 5915324,84 N 452303,71 E 5915359,47 N ' 452220,36 E 5915395,19 N 452137,76 E 5915431,85 N 452054,90 E 5915467,58 N 451974,87 E 5915505,00 N 451892,96 E 5915543,40 N 451810,05 E 5915579,04 N 451733,78 E Dogleg Rate (,lt00ft) 1,18 1,06 1,36 0,65 0,76 0,60 0,96 0,92 0,82 2,14 0.48 1,06 1,11 1,08 1,78 1,09 1.99 1,41 1,33 0,58 0,56 0,36 1,10 0,88 0,97 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 7590.88 7679,51 7767.79 7855.75 7949,26 8033,97 8119.98 8212,79 8301.34 8390,70 8481,08 8570,43 8657.20 8746,90 8836.74 8926.07 9018,68 9109,50 9199,75 9289,71 9380.28 9467,86 9557,83 9849.08 973~3,15 Continued.,, - 17 November, 2000 - 9:43 · . -6- DrillQuest 2.00.05 Sperry-Sun Drilling-Services Survey Report for 2NL326 ' Your Ref: APl 501032035100 Surveyed: 29 October, 2000 North Slope Alaska Measured Depth .(ft) Incl. Azim. Sub-Sea Depth (ft) 11387.09 70.000 .294.460 4481.11 11482.98 68.760 293.860 4514.88' 11581.27 70.610 291.890 4549.00 11677.53 70.860 290.040 4580.76 11772.75 70.720 288.870 4612~10 70.390 71.050 72.050 71.690 70.990 70.490 71.660 72.620 74.670 75.440 11865.84 11961.79 12060.71 12156.86 12249.39 288.890 4643.09 -288.870 4674.77 287.880 4706.07 287.420 4735.99 289~420 4765.60 289.71o 4797.29 '289.590 4828.31 289.670 4858.12 289.890 4884.85 289.600 4903.90 12345145 12441.11 12538.31 12633.24 127O7.09 Vertical DePth - 4636.14 '4669.91 4704.03 4735.79 4767.13 4798.12 4829.80 4861.10 4891.02 4920.63 4952.32 4983.34 5013.15 5039.88 5058.93 Local Coordinates NOrthings Eastings (ft)' -' 3639.95 N 3676.68 N 3712.50 N 3745.01 N 3774.96 N Global Coordinates Northings Eastings (fi) 3803.36 N 3832.67 N 3862,25 N 3889.95 N 3917.65 N 9122.97W 5915616.92 N 451652.93 E 9204.85W 5915654.07 N 451571.24E 9289.77W 5915690.33 N 451486.50 E 9374.62W 5915723.28 N 451401.82E 9459.40W '5915753.67N - 451317.20E 3948.02 N 3978.44 N 4009.52 N 4040.35 N 4064.45 N 9542.46 W 5915782.50 N 451234.29 E 9628.16 W 5915612.25 N 451148.75 E 9717.21 W 5915542.29 N 451059.85 E 9804.28 W '5915670.45 N 450972.92 E 9887.45 W. 5915898.58 N 450889.90 E 9972.90W 10056.12W 10145.25W 10230.96W 10298.12W 5915929.39 N 450804.61 E 5915960.26 N 450719.55 E 5915991.79 N 450632,57 E 5916023.06 N 450547.03 E 5916047.51 N 450479.99 E 12775.00 75.440 '289.600 4920.97 -5076.00- 4086.50 N 10360.04 W . All data is in feet unless otherwise stated. Directions and Coordinates are' relative to True North. Vertical depths are relative to Well.- Northings and Eastings are relative to Well. Magnetic Declination at surface is 25.876° (0_6-0ct-00) .. . The DOgleg Severity is in Degrees 'per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 291.720° (True). 5916069.88 N 450418.19 E Based upon Minimum Curvature type Calculations, at a Measured Depth of 12775.00ft., The Bottom Hole Displacement is 11136.87ft., in the Direction of 291.527° (True). - Dogleg Rate ('/lOOft) 0.90 1.42 2.66 1.83 1.17 0.36 0.69 1.39 0.59 2.18 0.59 1.23 0.99 2.17 1.11 0.00 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 9822.31 9911.97 10004.12 10094.98 10184.82 10272.49 10362.95 10456.62 10547.77 10635.28 10725.90 10816.33 10908.78 10999.82 11071.13 11136.81 Projected to TD Continued... 17 November, 2000 - 9:43 -7" DrillQuest 2.00.05 Sperry. Sun Drilling Services Survey.Report for 2N-326 Your Ref: APl 501032035100 Surveyed: 29 October, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 2N · Comments -Measured Depth (ft) Station coordinates . TVD Northings EastingS (ft) (ft) (~t) 386.00 385.94 .0.16 N' 3.86 W 12775.00 5076.00 4086.50 N 10360.04 W Comment .. . Tied on to Gyro Projected to TD Survey tool program 'for 2N-326 From To" .Measured Vertical. Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 421.92 421,78 421.92 421.78 12775.00 5076.00 Survey TOol Description . AK-2 BP_CG AK-6 BP_IFR-AK 17 November, 2000 - 9:43 -8. DrlllQuest 2.00.05 North Slope Alaska Alaska State Plane 4 Kuparuk 2N, Slot 2N-326 2N-326 MWD Surveyed: 29 October, 2000 S UR VEY REPORT 17 November, 2000 Your Ref: AP1501032035100 Surface Coordinates: 5911929.71 N, 460756.90 E (70° 10' 13.1887' N, 209' 41' 03.0057' E) Kelly Bushing: 155.03fl above Mean Sea Level o II- I I~ ' ~ VI s A H~lllburton Company Survey Ref: svy9336 Sperry-Sun Drilling Services Survey Report for 2N-326 MWD Your Ref: APl 50f032035100 Surveyed: 29 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. 386.00 3.200 295.000 421.92 4.280 297.210 452.91 5.310 294.250 483.01 6.590 293.070 512.85 8.090 291.260 540.95 9.560 291.660 575.55 11.180 292.660 603.78 12.790 293.280 634.22 14.510 292.550 665.64 16.300 291.920 695.28 18.350 292.170 725.12 20.310 292.060 814.14 24.620 291.660 905.43 23.940 291.890 992.16 29.110 291.980 Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northlngs Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 230.91 385.94 0.16 N 3.86W 266.75 421.78 1.20 N 5.96W 297.63 452.66 2.31N 8.30W 327.57 482.60 3.56 N 11.16W 357.16 512.19 4.99 N 14.69W 384.93 539.96 6.57 N 18.70W 418.96 573.99 8.93 N 24.47W 446.58 601.61 11.22 N 29.87W 476.16 631.19 14.01N 36A8W 505.87 660.90 17.10 N 44.06W 534.73 689.76 20.49 N 52.41W 562.89 717.92 24.20N 61.56W 645.14 800.17 36.86 N 93.12W 728.35 883.38 50.78 N 127.98W 805.93 960.96 65.25 N 163.90W 1087.89 35.000 290.940 887.03 1042.06 1182.86 38.510 291.340 963.10 1118.13 1283.00 45.540 290.530 1037.45 1192.48 1371.89 48.910 290.070 1097.81 1252.84 1466.43 55.530 288.480 1155.69 1310.72 1561.46 59.200 288.830 1206.93 1361.96 1656.53 63.660 289.690 1252.39 1407.42 1750.89 62.640 289.830 1294.86 1449.89 1846.09 62.030 290.470 1338.91 1493.94 1940.87 63.040 290.180 1382.63 1537.66 5911929.89N 460753.04 5911930.94N 460750.94 5911932.07N 460748.61 5911933.33 N 460745.76 5911934.78 N 460742.23 5911936.38 N 460738.23 5911938.76 N 460732A8 5911941.08 N 460727.09 5911943.91N 460720.49 5911947.04 N 460712.93 5911950.47 N 460704.60 5911954.23 N 460695.47 5911967~05 N 460663.97 5911981.15 N 460629.18 5911995.81 N 460593.34 83.79 N 211.18W 5912014.59 N 460546.16 104.29N 264.17W 5912035.37 N 460493.27 128.20 N 326.75W 5912059.60 N 460430.81 150.83 N 387.94W 5912082.54N 460369.74 175.43 N 458.45W 5912107.52 N 460299.37 201.03 N 534.26W 5912133.51N 460223.69 228.58N 613.05W 5912161.46 N 460145.04 257.06 N 692.35W 5912190.36 N 460065.89 286.13 N 771.58W 5912219.84N 459986.82 315.34N 850.44W 5912249.46 N 459908.11 Dogleg Rate (°ll00ft) E E 3.03 E 3.42 E 4.27 E 5.09 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 3.65 Tie on to Gyro 5.98 MWD Magnetic 8.57 11.69 15.50 E 5.24 19.81 E 4.71 26.O4 E 5.72 31.90 E 5.68 39.O8 E 5.83 47.26 E 6.78 56.27 E 6.57 66.14 E 4.84 100.15 E 0.75 137.69 E 5.96 176.41 E 6.18 E 3.70 E 7.04 E 3.81 E 7.13 227.19 284.01 351.00 416.22 490.82 E 3.87 570.72 E 4.76 654.12 E 0.88 738.33 E 1.04 822.69 E 1.10 906.76 Continued... 17 November, 2000 - 9:48 - 2 - DrillQuest ZOO.05 Sperry-Sun Drilling .' Services Survey Report for 2N.326 MWD Your Reh AP1501032035100 Surveyed: 29 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates. Global Coordinates Depth Northings Eastings Northings Eastings (~t) (ft) (ft) (ft) (ft) 2035.83 64.250 289.000 1424.78 1579.81 2130.99 67.020 288.930 1464.04 1619.07 2225.33 70.950 288.400 1497.86 1652.89 2320.22 71.330 288.690 1528.54 1683.57 2415.04 69.530 288.520 1560.29 1715.32 2510.17 70.480 289.450 1592.82 1747.85 2604.67 71.940 290.110 1623.26 1778.29 2699.49 72.820 290.060 1651.96 1806.99 2795.83 71.590 290.790 1681.41 1836.44 2827.84 70.930 290.880 1691.69 1846.72 2922.34 72.290 290.800 1721.50 1876.53 3016.53 72.040 291.010 1750.35 1905.38 3111.84 72.490 291.940 1779.38 1934.41 3206.12 71.770 292.110 1808.31 1963.34 3300.71 71.330 291.550 1838.25 1993.28 3395.39 71.130 291.700 1868.72 2023.75 3490.13 71.690 290.040 1898.92 2053.95 3585.17 71.370 290.210 1929.03 2084.06 3680.52 72.200 288.390 1958.84 2113.87 3774.97 71.530 288.890 1988.23 2143.26 2017.47 2045.49 2073.90 2102.17 2113.36 3870.15 72.690 288.730 3965.00 72.950 288.890 4059.37 72.010 289.750 4154.23 73.310 289.990 4193.11 73.240 289.690 343.87 N 930.60 W 5912278.40 N 459828.09 E 372.03 N 1012.57 W 5912306.99 N 459746.27 E 400.21 N 1095.99 W 5912335.60 N 459663.00 E 428.77 N 1181.12 W 5912364~60 N 459578.02 E 457.27 N 1265.79 W '5912393.64 N . 459493.49 E 486.35 N 1350.32 W 5912423.06 N 459409.12 E 516.63 N 1434.51 W 5912453.77 N 459325.09 E 547.67 N 1519.38 W 5912485.25 N 459240.38 E 579.67 N 1605.34 W 5912517.70 N 459154.59 E 590.46 N 1633.67 W 5912528.63 N 459126.31 E 622.36 N 1717.48W 5912560.97 N 459042.67 E 654.35 N 1801.24W 5912593.39 N 458959~8 E 687.59 N 1885.72W 5912627.06 N 458874.78 E 721.24N 1968.90W 5912661.15 N 458791.77 E 754.60 N 2052.19W 5912694.94 N 458708.65 E 787.64N 2135.53W 5912728.41N 458625.49E 819.63 N 2219.43W 5912760.83 N 458541.75E 850.64N 2304.07W 5912792.29 N 458457.27E 880.57N 2389.55W 5912822.66N 458371.95 E 909.26 N 2474.60W 5912851.79 N 458287.05 E 2172.50 938.46 N 2560.34W 5912881.44N 458201.47 E 2200.52 967.68 N 2646.11W 5912911.10 N 458115.84E 2228.93 997.45 N 2731.94W 5912941.31N 458031.07 E 2257.20 1028.23 N 2816.19W 5912972.53 N 457946.08 E 2268.39 1040.87 N 2851.22W 5912985.35 N 457911.12 E Dogleg Rate ('/lOOft) 1.69 2.91 4.20 0.49 1.91 1.36 1.68 0.93 1.47 2.08 1.44 0.34 1.04 0.78 0.73 0.26 1.76 0.38 2.01 0.87 1.23 0.32 1.32 1.39 0.76 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 991.79 1078.36 1166.28 1255.94 1345.15 1434.44 1523.85 1614.18 1705.89 1736.20 1825.86 1915.51 2006.29 2096.02 2185.75 2275.39 2365.18 2455.29 2545.77 2635.40 2725.86 2816.36 2906.27 2996.77 3033.99 Continued... November, 2000 - 9:48 - 3 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for 2N-326 MWD Your Ref: AP1501032035100 Surveyed: 29 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates ~ Depth Northings Eastings (~t) (ft) (ft) 4236.41 72.840 288.780 2125.99 2281.02 4372.41 70.670 288.360 2168.57 2323.60 4467.40 70.120 289.330 2200.44 2355.47 4562.07 73.150 293.070 2230.27 2385.30 4657.14 72.690 294.150 2258.20 2413.23 4751.56 70.550 291.540 2287.97 2443.00 4846.55 70.450 291.160 2319.68 2474.71 4941.36 70.810 291.270 2351.12 2506.15 5036.34 73.190 293.620 2380.48 2535.51 5130.74 71.130 293.350 2409.40 2564.43 5225.68 71.180 292.780 2440.06 2595.09 5320.55 69.710 292.860 2471.82 2626.85 5414.65 69.450 292.920 2504.65 2659.68 5510.15 68.850 292.890 2538.64 2693.67 5609.85 70.520 293.030 2573.25 2728.28 5704.66 70.410 293.880 2604.95 2759.98 5793.44 70.780 292.260 2634.45 2789.48 5893.49 70.870 292.190 2667.31 2822.34 5988.39 70.290 292.400 2698.87 2853.90 6077.58 71.160 292.570 2728.31 2883.34 2759.66 2791.48 2824.29 2861.62 2897.70 6172.05 70.080 291.200 6266.74 70.640 289.930 6361.76 68.960 290.790 6461.83 67.240 291.850 6557.21 68.310 292.560 Global Coordinates Northings Eastings (ft) (ft) 1054.51N 2890.32W 5912999.19 N 457872.09 E 1095.64N 3012.75W 5913040.96 N 457749.87E 1124.55 N 3097.44W 5913070.30 N 457665.34E 1157.05 N 3181.17W 5913103.24N 457581.78 E 1193.45 N 3264.44W 5913140.07 N 45749820 E 1228.24N 3346.99W 5913175.29 N 457416.32 E 1260.84N 3430.39W 5913208.32 N 457333.10 E 1293.21N 3513.77W 5913241.12 N 457249.88 E 1327.70 N 3597.24W 5913276.05 N 457166.59E 1363.51N 3679.65W 5913312.28 N 457064.37 E 1398.71 N 3762.32 W 5913347.91 N 457001.88 E 1433.38 N 3844.72 W 5913383.01 N 456919.66 E 1467.68 N 3925.96 W 5913417.73 N 456838.60 E 1502.42 N 4008.17 W 5913452.89 N 456756.57 E 1538.89 N 4094.26 W 5913489.81 N 456670.68 E 1574.45 N 4176.23 W 5913525.80 N 456588.89 E 1607.26 N 4253.26 W 5913559.01 N 456512.03 E 1643.01 N 4340.74 W 5913595.20 N 456424.73 E 1676.96 N 4423.55 W 5913629.59 N 456342.10 E 1709.16 N 4501.34 W 5913662.19 N 458264.48 E 2914.69 1742.38 N 4584.03W 5913695.84N 456181.96 E 2946.51 1773.70 N 4667.53W 5913727.59N 456098.63 E 2979.32 1804.72 N 4751.13W 5913759.05 N 456015.19 E 3016.65 1838.48 N 4837.62W 5913793.25 N 455928.88 E 3052.73 1871.84N 4919.36W 5913827.04N 455647.31E Dogleg Rate ('/lOOft) 2.21 1.62 1.12 4.93 1.19 3.47 0.39 0.40 3.44 2.20 0.57 1.55 0.28 0.63 1.68 0.85 1.77 0.11 0.65 0.99 1.78 1.39 1.96 1.98 1.32 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 3075.36 3204.32 3293.69 3383.51 3474.33 3563.90 3653.44 3742.88 3833.19 3923.01 4012.83 4102.21 4190.38 4279.61 4373.08 4462.39 4546.10 4640.60 4730.09 4814.27 4903.39 4992.55 5081.69 5174.53 5262.82 Continued... November, 2000 - 9:48 - 4 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for 2N-326 MWD Your Ref: AP150fO32035fO0 Surveyed: 29 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth fit) Vertical Local Coordinates Global Coordinates Depth Northings Eastlngs Northings Eastings (~t) fit) (ft) (ft) (ft) 6651.73 70.640 291.660 2930.83 3085.86 6740.78 69.890 292.190 2960.90 3115.93 6841.02 69.850 293.130 2995.40 3150.43 6935.53 70.800 294.160 3027.22 3182.25 7030.39 71.420 296.290 3057.94 3212.97 7120.04 72.820 295.920 3085.46 3240.49 7220.54 70.940 295.110 3116.72 3271.75 7309.20 71.210 294.910 3145.47 3300.50 7407.28 71.220 294.750 3177.05 3332.08 7501.72 72.040 294.190 3206.82 3361.85 7596.94 72.530 292.780 3235.79 3390.82 7694.04 72.220 292.060 3265.19 3420.22 7789.04 71.410 291.590 3294.84 3449.87 7882.94 69.420 291.280 3326.32 3481.35 7976.64 68.670 291.630 3359.83 3514.86 8070.80 71.130 293.250 3392.18 3547.21 8163.37 71.680 292.830 3421.70 3576.73 8261.25 70.880 292.040 3453.12 3608.15 8355.04 72.590 291.420 3482.51 3637.54 8452.75 74.140 292.200 3510.48 3665.51 8548.04 73.020 291.620 3537.42 3692.45 8636.30 72.850 290.860 3563.32 3718.35 8736.87 71.950 291.430 3593.73 3748.76 8831.93 70.920 293.120 3623.99 3779.02 8923.87 70.780 294.520 3654.16 3809.19 1905.15 N 5001.37W - 1936.45 N 5079.13W 1972.71N 5165.98W 2008.40 N 5247.50W 2046.65N 5328.68W 2084.19 N 5405.30 W 2125.34 N 5491.49 W 2160.79 N 5567.49 W 2199.79 N 5651.76 W 2236.91 N 5733.34 W 2273.05 N 5816.53 W 2308.35 N ' 5902.08 W 2341.90 N 5985.86 W 2374.23 N 6068.20 W 2406.24 N 6149.64 W 2440.00 N 6231.36 W 2474.34 N 6312.10 W 2509.71 N 6397.78 W 2542.69 N 6480.51 W 2577.47 N 6567.43 W 2611.58 N 6652.23W 2642.14 N 6730.87W 2676.72N 6820.28W 2710.87 N 6903.66W 2745.95 N 6983.12W 5913860.77 N 455765.48 E 5913892.47 N 455687.88 E 5913929.18 N 455601.22 E 5913965.30 N 455519.89 E 5914003.97 N 455438.90 E 5914041.90 N 455362.48 E 5914083.49 N 455276.50E 5914119.35 N 455200.69 E 5914158.77 N 455116.62 E 5914196.32 N 455035,24E 5914232.90N 454952.23 E 5914268.63 N 454866.87E 591430Z62N 454783.26 E 5914335.38 N 454701.09 E 5914367.81N 454619.82 E 5914401.99 N 454538.28 E 5914436.74 N 454457.72 E 5914472.57 N 454372.22 E 5914505.97 N 464289.66 E 5914541.20 N 464202.92 E 5914575.75N 454118.30 E 5914606.72 N 454039.82E 5914641.76 N 453950.59E 5914676.35 N 453867.39 E 5914711.83 N 453788.12 E Dogleg Rate (oll00ft) 2.62 1.01 0.88 1.44 2.22 1.61 2.02 0.37 0.15 1.03 1.50 0.78 0.97 2.14 0.87 3.07 0.73 1.12 1.93 1.76 1.31 0.85 1.05 2.00 1.45 Alaska State Plane 4 Kupamk 2N Vertical Section Comment 5351.33 5435.15 5529.25 5618.19 5707.77 5792.84 5888.14 5971.87 6064.59 6154.11 6244.77 6337.30 6427.56 6516.02 6603.52 6691.93 6779.64 6872.33 6961.39 7055.01 7146.41 7230.78 7326.64 7416.74 7503.53 Continued... 17 November, 2000 - 9:48 - 5- DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for 2N-326 MWD Your Ref: AP1501032035100 Surveyed: 29 October, 2000 North Slope Alaska Measured Depth (ft) Incl. 9016.35 69.960 293.290 9111.04 69.010 293.940 9205.91 68.140 292.700 9300.50 68,740 294,140 9400.97 68.490 293,980 Sub-Sea Depth (ft) 3685.23 3718.41 3753.06 3787.83 3824.46 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 3840.26 2781.25 N 7062.74 W 5914747.54 N 453708.67 E 3873.44 2816.77 N 7144.00 W 5914783.49 N 453627.60 E 3908.09 2851.73 N 7225.10 W 5914818.87 N 453546.69 E 3942.86 2886.70 N 7305.82 W 5914854.26 N 453466.15 E 3979.49 2924.84 N 7391.24 W 5914892.84 N 453380.92 E 9492.00 68.800 294,410 3857.61 4012.64 9584.53 68,110 293,570 3891.59 4046.62 9684.50 68.370 292,640 3928.65 4083.68 9779.51 69.150 292.610 3963.07 4118.10 9874.53 71.180 292,630 3995.31 4150.34 9969.91 71.630 292.430 4025.72 4180.75 10064.18 71.200 291,590 4055.77 4210.80 10155.90 70.970 290,980 4085.50 4240.53 10250.54 71.880 290.810 4115.65 4270.68 10345.53 70.280 290,710 4146.45 4301.48 10440.33 70.710 289.630 4178.10 4333.13 10537.97 72.550 290.590 4208.87 4363.90 10633.23 72.330 291.890 4237.61 4392.64 10728,13 71.680 292.970 4266.93 4421.96 10822.86 71.930 293,680 4296.51 4451.54 10918.26 71.600 295.470 4326.37 4481.40 11010.71 71.270 294,360 4355.80 4510.83 11105.92 70.880 294.860 4386.68 4541.71 11202.84 70.130 294.270 4419.03 4574.06 11292.24 70.550 295.360 4449.10 4604.13 2959.59 N 7468.58W 5914927.99 N 453303.77 E 2994.58 N 7547.20W 5914963.39 N 453225.33 E 3031.01N 7632.60W 5915000.26N 453140.12 E 3065.08 N 7714.34W 5915034.75 N 453058.56 E 3099.46 N 7796.84W 5915069.56N 452976.23 E 3134.10 N 7880.35W 5915104.63 N 452892.91E 3167.58 N 7963,19W 5915138.54N 452810.25 E 3199.08 N 8044.03W 5915170.46 N 452729.56E 3231.08 N 8127.84W 5915202.89 N 452645.92E 3262.93 N 8211.86W 5915235.17 N 452562.07 E 3293.74 N 8295.74W 5915266.42 N 452478.35 E 3325.60 N 8382.75W 5915298.73 N 452391.51E 3358.50 N 8467.40W 5915332.07 N 452307.03 E 3392.93 N 8550.83W 5915366.94 N 452223.78E 3428.57 N 8633.47W 5915403.00 N 452141.33 E 3466.25 N 8715.86W 5915441.11N 452059.13 E 3503.17 N 879135W 5915478.44N 451979.84E 3540.67N 8877.23W 5915516.37 N 451898.15 E 3578.65N 8960.32W 5915554.78 N 451815.26 E 3613.99 N 9036.73W 591559~51N 451739.03 E Dogleg Rate (°/'lOOft) 1.53 1.19 1.52 1.55 0.29 0.56 1.13 0.90 0.82 2.14 0.51 0.96 0.68 0.98 1.69 1.17 2.10 1.32 1.28 0.76 1.82 1.19 0.64 0.96 1.24 Alaska State Plane 4 Kupamk 2N Vertical Section Comment 7590.57 7679.21 7767.48 7855.41 7948.89 8033.59 8119.59 8212.40 8300.95 8390.32 8480.71 8570,06 8656.82 8746.52 8836.36 8925.69 9018.31 9109.13 . 9199.38 9289.33 9379.83 9467.33 9557.28 9648.53 9732.59 Continued... f7 November, 2000 - 9:48 - 6 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for 2N.326 MWD Your Ref: AP1501032035100 Surveyed: 29 October, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 11387.09 70.000 294.690 4481.12 4636.15 3651.76 N 9117.64 W 11482.98 68.760 294.040 4514.89 4669.92 3688.78 N 9199.39 W 11581.27 70.610 292.440 4549.01 4704.04 3725.14 N 9284,08 W 11677.53 70.860 290.040 4580.77 4735.80 3758.06 N 9368,77 W 11772.75 70.720 288.830 4612.11 4767.14 3787.98 N 9453.56 W 11865.84 70.390 288.640 4643.10 4798.13 3818.17 N 9536.69 W 11961.79 71.050 288.810 4674.78 4829.81 3645.25 N 9622.46 W 12060.71 72.050 287.530 4706.08 4861.11 3874.51 N 9711.62 W 12156.86 71.690 286.930 4736.00 4891.03 3901.57 N 9798.89 W 12249.39 70.990 289.370 4765.61 4920.64 3928.87 N 9882.19 W 12345.45 70.490 289.850 4797.30 4952.33 3959.31 N 9967.61 W 12441.11 71.660 289.740 4828.32 4983.35 3989.95 N 10052.76 W 12538.31 72.620 289.840 4858.13 5013.16 4021.28 N 10139.81 W 12633.24 74.670 289.860 4884.86 5039.89 4052.20 N 10225.48 W 12707.09 75.440 289.760 4903.91 5058.94 4076.38 N 10292~61 W 12775.00 75.440 289.760 4920.98 5076.01 4098.61 N 10354.47 W Global Coordinates Northings Eastings (ft) (ft) 5915628.70 N 451658.32 E 5915666.15 N 451578.77 E 5915702.95 N 451492.26 E 5915736.30 N 451407.74 E 5915766.66 N 451323.11 E 591~795.28 N 451240.13 E 5915824.80 N 451154.50 E 5915854.52 N 451065.50 E 5915882.04 N 450978.37 E 5915909.77 N 450895.21 E 5915940.65 N 450809.95 E 5915971.74 N 450724.97 E 5916003.51 N 450638.08 E 5916034.88 N 450552.57 E 5916059.41 N 450485.57 E 5916081.95 N 450423.83 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.876° (06-Oct-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 291.720° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12775.00ft., The Bottom Hole Displacement is 11136.14ft., in the Direction of 291.595° (True). Dogleg Rate (°/'lOOft) 0.88 1.44 2.42 2.37 1.21 0.40 0.71 1.59 0.70 2.61 0.70 1.23 0.99 2.16 1.05 0.00 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 9821.72 9911.37 10003.51 10094.37 10164.21 10271.87 10362.32 10455.97 10547.07 10634.55 10725.17 10815.61 10908.07 10999.11 11070.42 11136.11 Projected to TD Continued.,. 17 November, 2000 - 9:48 - 7 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for 2N-326 MWD Your Ref: AP1 50'i032035'100 Surveyed: 29 October, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 2N Comments Measured Station Coordinates Depth TVD Northings Eastings (~) (~t) (ft) (ft) 386.00 385.94 0.16 N 3.86 W 12775.00 5076.01 4098.61 N 10354.47 W Comment Tie on to Gyro Projected to TD Survey tool program for 2N-326 MWD From To Measured Vertical Measured Depth Depth Depth (~t) (~t) (~t) Vertical Depth (ft) 0.00 0.00 421.92 421.78 421.92 421.78 12775.00 5076.01 Survey Tool Description AK-2 BP_CG MWD Magnetic November, 2000 - 9:48 - 8 - DrillQuest 2.00.05 North Slope Alaska Alaska State Plane 4 Kuparuk 2N, Slot 2N-326 2N-326 GYRO Surveyed: 29 October, 2000 S UR VE¥ REPORT 17 November, 2000 Your Ref: AP1501032035100 Surface Coordinates: 5911929.71 N, 460756.90 E (70° 10' 13.1887' N, 209° 41'03.0057' E) Kelly Bushing: 155.03fl above Mean Sea Level A Halliburton Company Survey Ref: svy9333 Sperry-Sun Drilling Services Survey Report for 2N-326 GYRO Your Ref: AP150'1032035'i00 Surveyed: 29 October, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (~t) (~t) (fi) (~t) (ft) 0.00 0.000 0.000 -155.03 0.00 0.00 N 0.00 E 118.00 0.000 0.000 -37.03 118.00 0.00 N 0.00 E 144.00 0.500 205.000 -11.03 144.00 0.10 S 0.05 W 206.00 0.350 219.000 50.97 206.00 0.50 S 0.28 W 265.00 0.500 251.000 109.97 265.00 0.72 S 0.64 W 326.00 1.400 280.000 170.96 325.99 0.68 S 1.62 W 386.00 3.200 295.000 230.91 385.94 0.16 N 3.86 W Global Coordinates Northings Eastings (ft) (ft) 5911929.71 N 460756.90 E 5911929.71 N 460756.90 E 5911929.61 N 460756.85 E 5911929.22 N 460756.62 E 5911928.99 N 460756.26 E 5911929.04N 460755.27 E '5911929.89 N 460753.04 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.876° (06-Oct-00) The Dogleg Severity is in Degrees per 100 feet. Vedical Section is from Well and calculated along an Azimuth of 291.720° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 386.00ft., The Bottom Hole Displacement is 3.87ft., in the Direction of 272.354° (True). Dogleg Rate (°/lOOft) 0.00 1.92 0.29 0.47 1.63 3.14 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 0.0o 0.00 0.01 0.08 0.33 1.26 3.65 AK-2 BP CG Continued... November, 2000 - 9:21 - 2- DrillQues! 2.00.05 Sperry-Sun Drilling Services Survey Report for 2N-326 GYRO Your Ref: AP150'1032035'100 Surveyed: 29 October, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 2N Survey tool program for 2N-326 GYRO From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (rt) (fi) (ft) 0.00 0.00 386.00 385.94 Survey Tool Description AK-2 BP_CG November, 2000 - 9:21 - 3 - DrillQuest 2.00.05 MEMORANDUM TO: Dan Seamount Commissioner THRU: Blair Wondzell ~ P.I. Supervisor ~¢>((0{ Ob FROM: JeffJon~-~t~/ ~' J,. Petroleum Inspector State oi~laska Alaska Oil and Gas Conservation Commission DATE: October 8, 2000 SUBJECT: Diverter Function Test Nabors 19E Phillips Alaska Inc. 2N-326 200-155 KRF/Tarn NON- CONFIDENTIAL Operator Rep.: Ray Sprin.qer Op. phone: 263-3140 Op. e-mail: Contractor Rep.: John West Rig phone: 263-3141 Rig e-mail: MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: P Well Sign: P Systems Pressure: 2900 .psig P Housekeeping: P (Gen.) Drlg. Rig: P Pressure After Closure: 1850 psig P Reserve Pit: NIA Flare Pit: NIA 200 psi Recharge Time: 10 min:sec F FullRecharge Time: NIA min:sec F Nitrogen Bottles: 4 ~ 1900 psi avg. PIF MUD SYSTEM INSPECTION: DIVERTER SYSTEM INSPECTION: Light Alarm Diverter Size: 20 Trip Tank: P P Divert Valve(s) Full Opening: YES Mud Pits: P P Valve(s) Auto & Simultaneous: YES Flow Monitor: P P Vent Line(s) Size: 16 Vent Line(s) Length: 85 GAS DETECTORS: Line(s) Bifurcated: NIA Light Alarm Line(s) Down Wind: YES Methane P P Line(s) Anchored: YES H2S: p P Tums Targeted I Long Radius: N/A in. Vent Line ,~, ,4-~~~ / Wind Direction Rig 19ES ~O I North JCamp . J Pad Access t Test's Details Sunday~ October 8~ 2000: I traveled to Phillips Alaska Ino.'s Kuparuk River Field, 2N Pad, to Witness a Diverter Function Test on Nabors Rig 19E, preparing to drill well 2N-326. Nabors personnel were ready to test on my arrival and performed the tests in a safe and proficient manner. The twenty inch annular preventer closed in 1 minute 40 seconds and the knife valve opened in 18 seconds, operating simultaneously. The 16 inch vent line was of sturdy construction and ample length, with warning signs in place. Nabors personnel were anchoring the line during the test. The layout of the vent line was such that it allowed for escape from the pad if necessary. The location, though crowded, was well organized. The accumulator failed the recharge tests, but John West (Nabors Toolpusher) quickly diagnosed and repaired the problem. The accumulator passed a rs-test with a 200 psi recharge time of 40 seconds and a full recharge time of 2 minutes 50 seconds. The gas detection system was tested and operated properly. Summary: I witnessed the Diverter Function Test on Nabors Rig 19E. The accumulator failed the recharge tests, but was repaired and passed the retest. Total Test Time: 1.5 hrs. . Number of failures: 2_ Attachments: 0 cc'. Diverter Nabors 19E 10-8-00 JJ1 .xls ALASILA OIL AND GAS CONSERVATION CO~ISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 James Trantham Drilling Engineering Supervisor Phillips Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Kuparuk River Unit 2N-326 Phillips Alaska Inc. Permit No: 200-155 Sur Loc:: 79'SNL, 836'FEL, Sec. 3, T9N, R7E, UM Btmhole Loc. 1282'FNL, 499'FEL, Sec. 32, T10N, R7E, 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 umil all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 2N-326. 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 aamular disposal on Drill Site 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. Sincerely, Commissioner BY ORDER OF THE COMMISSION DATED this ~ ~ day of October, 2000 dlf/Enclosures cc: Depamnent of Fish & Gmne, Habitat Section w/o encl. Department of Enviromnental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of wo~k: Drill r~-'~Redrill U I ~b. Typeofwe". Exp~oretory r'-] StretigraphicTastF-i Development Oil r'~ Re-entry E]Deepen F~I Service r-~ Development Gas F'~ Single Zone [~] Multiple Zone 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 ADL 375108 ALK 4309 ~ Tam Pool 4. Location of well at surface 7. Unit or property Name .~ 11. Type Bond (see 20 AAC 25.0251) 79' FNL, 836' FEL, Sec. 3, TDN, R7E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number INumber 1436' FNL, 134' FEL, Sec. 32, T10N, R7E, UM 2N 326 #U-630610 At total depth 9. Approximate spud date Amount 1282' FNL, 499' FEL, Sec. 32, T10N, R7E, UM October 4, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 499 @ TD feetI 2N 325 12.1' @270' MD feet 2560 12679 ' MD / 5094' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.03S (e)(~)) Kickoff depth: 250 MD Maximum hole angle 73 Maximum surface 1907 psig At total depth (TVD) 2400 psig 18. Casing program Setting Depth size Specifications Top Bottom Qua_ntity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sterile ~_t~_) 24" 16" 62.5# H-40 Weld 83' 35' 35' 118' 118' 9 cy High Early 9.875" 7.625" 29.7# L-80 BTCM 4366' 35' 35' 4401' 2300' 420 sx AS III L & 240 sx Class G 6.75" 5.5" x 15.5# L-80 LTC Mod 11884' 35' 35' 11919' 4802' 630 sx Class G 6.75" 3.5" 9.3# L-80 8rd DUE 760' 11919' 4802' 12679' 5094' see above 19. To be completed for Redrill, Re-entry, and Deepen Operations. 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 Surface Intermediate Production RECEIVED Perforationdapth: measured 0 RIG INA L S"* .000 true vertical Alaska Oil & Gas C, oris. Cofnmission Anchorage 20. Attachments Filing fee L~J Property Plat [~ BOP Sketch F~ Diverter Sketch E] Drilling program Drilling fluid program F~ Time vs depth plot [--]Refraction analysis E] Seabed report F~ 20 AAC 25.050 requirements 21. I hereby cl~rtify that the foregoing is true and correct to the best of my knowledgl Questions? Call Brian Noel 265-6979 Signed. Title: Drilling Engineering Supervisor Date Pr~.n~r~d hv'"Tnrq ~r~.q.~fi~.ld Commission Use Onl~ Permit Number APl number [ [See cover letter 2.-~- I-5"~-' 5o- /~ :~- 20 ~ ~' I- 40, Approval date ~/ ~0 -- ~,~ "' DO ~for other requirements Conditions of approval Samples required L.J Yes [~ No Mud log required r--] Yes ~ No Hydrogen sulfide measures r-] Yes ~ NO Directional survey required ~] Yes ~ NO Required working pressure for DOPE F"]2M; r'~ 3M; [~] 5M; r~ 1OM: [~ [~ 3, ~" Other: ORIGINAL SIGNED ~Y by order of Approvedb¥ ~ Ts¥lorSeamouRt Commissioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate Phillips Alaska, Inc.ir~''' Post Office Box 100360 Anchorage, Alaska 99510-0360 September 27, 2000 Daniel T. Seamount, Jr., Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-326 Surface Location: 79' FNL 836' FEL Sec 3 T9N R7E, UM or ASP4, NAD 27 coordinates of X=460,757 & Y=5,911,930 Target Location: 1436' FNL, 134' FEL Sec. 32, T10N, R7E, UM Bottom Hole Location: 1282' FNL, 499' FEL Sec. 32, T10N, R7E, UM Dear Commissioner Seamount: Phillips Alaska, Inc. hereby files this Application for Permit to Drill the development well KRU 2N-326. Nabors Rig 19e will drill the well. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 2N, or hauled to an approved Prudhoe or GKA Class II disposal well. This well will be a producer in the Tarn formation. Though all operations will be monitored for H2S, there has not been any H2S encountered on this pad. Phillips Alaska, Inc. requests an exemption from the H~S requirements. The following are Phillips' designated contacts for reporting responsibilities to the Commission: 1) Completion Report Sharon AIIsup-Drake, Drilling Technologist 263-4612 (20 AAC 25.070) 2) Geologic Data and Logs Bill Morris, Geologist 263-4588 (20 AAC 25.071) If you have questions or require additional information, please contact Brian Noel at 265- 69~'9 or me at 265-6434 in our Anchorage office. Sincerely,~ --- , --- ' J~u3~es-Trantham ' Drilling Engineering Supervisor Attachments: Information as required cc: KRU 2N-326Well File ?.,- RECEIVED SEP 2 7 000 Alaska 0il & G~s Cons. C0mmissJ0n Anchorage Phillips Alaska, Inc. is a Subsidiary of]Phillips 66 Philhps Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD- PRODUCER/Injector KRU 2N-326 1. Move in and rig up Nabors 19e. 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 to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface. If cement does not circulate to surface, a Top Job will only be performed after consulting with the AOGCC. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. 5. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 6. Drill 6-3/4" or 6-1/2"x7.1/2', hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. No~te: If significant hydrocarbon zones are present above the Tam, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(¢). 7. Run and cement 5-1/2" k-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 8. Pressure test casing to 3,500 psi. 9. Run 3-.1/2" L-80 8rd EUE~Mod completion. . bore with seal assembl _ _..assembly. Stln into · Y and Pressure tes[ [uDi a nfl ~,.,,,.,,.g.,. ,_ ~_o/i?hed seal n~ a ..... ,, ,u,u~ [o ~,~uo psi. 10. Set TWC, ND BOPE and install production tree. 11. Secure well. Rig down and move out. 12. Handover well to Operations Personnel. RECEIVED SEP 27 000 A.]aska Oil & Gas Cor~s. ¢om.q'~iss]on Anchorage LEAK OFF TEST PROCEDURE (' Tarn After cementing casing and nippling up BOPE, RIH to top of cement and pressure test the casing to 2000 psi for 30 minutes and record on chart (AOGCC required casing integrity test). Record the information on the PAl LOT form (you can locate on the drilling web page). Plot Casing Pressure Test (volume vs. pressure and time holding pressure on casing). Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. 2. Drill 20' to 50' of new hole below the casing shoe. . Circulate the hole to establish a uniform mud density throughout the system (required for a good FIT or LOT). PU into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill stem at 1/4 to 1/2 bpm. Sm , On the LOT form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. Note: If 16.0 ppg EMW is reached, shut down and hold the pressure there. This becomes the data for a formation integrity test (FIT) instead of a LOT At leak off pump 3 bbls of mud into formation prior to shutting down the pump. Shut down when the leak-off point is clearly seen and 3 bbls of mud has been pumped into the formation. Record initial shut-in pressure. With the pump shut down monitor, record and report the shut -in pressures for a minimum of 10 minutes or until the shut -in pressure stabilizes. Record time vs. pressure in 1-minute intervals and plot information. Bleed the pressure off and record the fluid volume recovered. Forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the Agencies. TJB 5/19/00 Phillips Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N-326 Drilling Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.5-10.2 ppg 16-26 25-35 50-120' 10-20 15-40 7-15 9.5-10 _+10% Drill out to TD 9.0 - 11.0 ppg 6-20 5-20 35-50 2-6 4-8 <6 through Tam 9.0-10 <11% RECEIVED SEP,;-° ,.,. qjt & Gas 6o7~s. Drillin,q Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser IPit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a reservoir pressure of 2400 psi at a target mid-point of 4929' TVD. Gas gradient is anticipated to be 0.1 psi/ff. Using this data, the M^SP is calculated to be: MAS P=((2400/4929)-0.1 )*4929 MASP=1907 psi Therefore PAl will test the BOP equipment to 3500 psi after setting surface casing. Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,400 psi (0.49 psi/fi). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.95 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 4929'. Target (Midpoint T2 T3) (2400+150)/(0.052'4929)=9.95. Phillips Alaska, Inc. (' Well Proximity Risks: The nearest well to 2N-326 is 2N-325. The wells are 12.1' from each other at a depth of 270' MD. This well does meet with the Phillips ellipse separation criteria. Drillinq Area Risks: One identified risk in the Tarn 2N-326 drilling area is the shallow gas hydrates below the permafrost. To date the hydrates encountered while drilling the Tarn Phase 3 wells 2N 347 & 2N 332, 2N 316, 2N 318, 2N 349, & 2N 305 have been minimal. Standard SOP's have been developed to minimize the hydrate impacts i.e. maintaining Iow mud viscosities, pre-treating with Driltreat (Lecithin) and DriI-N-$1ide, using cold make-up water for the mud, control drilling, and optimized flow rates. The surface hole will be drilled with weighted mud (9.5 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is possible lost circulation at approximately 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.0-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well through the reservoir. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Recent information has indicated the possibility of gas migration from the reservoir to a shallower sand interval. However, NO overpressured zones were encountered while drilling 2N-347, 2N-332, 2N-316, 2N-318, or 2N-349 wellbores. Log, tracer, pump-in test, and offest BHPBU evaluations indicate migration has not occurred outside of the wellbore interval and is most likely isolated below the TOC and/or below the Iceberg interval. In the event gas migration has occurred into the Iceberg interval at 4270' TVD, the highest required MW would be 10.8 ppg. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2N-326 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. Following drilling operations, Phillips Alaska, Inc. will submit application for approval of 2N-326 for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical Phillips Alaska, Inc. barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5Y2" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3~" 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi ,8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). Creoted by floch For: B Noel Dote plotted: 26-Sep-2000 I Plot Reference is 326 Vers~onf3. I I Coord;notes om in feet reference slot ~1326. I Phillips Alaska, Inc. Structure: Tarn Drill Site 2N Well: 326 field: Tarn Development Field Location: North Slope. Alaska 500 500 ~ 1000 ~' 1500 2000 2500 3000 I-- 35oo - 4000 - 4500 - 5000 - 5500 RKB ELEVATION: 15.3' KOP 4.00 12.00 20.00 DLS: 4.00 deg per 100 f[ 28.00 Port Collar 56.00 44.00 Base Permafrost 52-0600.(~8p West Sok 72.00 EOC MAXIMUM ANGLE 73 DEG Bose West Sok 7 5/8 Cosin9 Begin Turn 72.99 End Turn C80 Comp SS 291.72 AZIMUTH 10617' (TO TARGET) ***Plane of Proposal*** Begin Drop 70.17 EOC C50 C40 C57 TARGET ANGLE ,cebe~g 67.42 DEG ~ Target- Mid Bermuda T2/C35 TD - Csg T3.1 T3 500 0 500 1000 1500 2000 2500 3000 ,.35004000 4500 5000 5500 6000 6500 7000 7500 8000 8500 go00 9500 10000 10500 1 100011500 Verficol Section (feet) -> Azimufh 291.72 wifh reference 0.00 N, 0.00 E from sial #526 Phillips Alaska, Inc. Structure: Tarn Drill Site 2N Well: 526 Fie d: Tarn Development Field Location: North Slope. Alaska <- West (feet) 10550 9900 9450 9000 8550 81 O0 7650 7200 6750 6300 5850 5400 4950 4500 4050 5600 5150 2700 2250 ! 800 1550 go0 450 0 i i i i i i i I i i i i i i I i i i i i I I i i i i i i i i i i i i i i i i i i i i i i i i i i TD - Csg Pt. Mid Bermuda T3.1 T7 TD LOCATION: I 1282' FNL, 499' FEL SEC, 52, TION, R7E C57 C40 C50 Begin Drop TARGET LOCATION: 1456' FNL, 154' FEL SEC. 52, TI ON, R7E 291.72 AZIMUTH 10617' (TO TARGET) ***Plane of Proposal*** TRUE Camp SS Turn in Turn 7 5/8 Casing Bose West Sak EOC Base Permafrost Port Collar SURFACE LOCATION: 79' FNL, 836' FEL SEC. 5, T9N, R7E 4500 4050 5600 3150 2700 A I 2250 1800 1550 900 450 450 Creoted by finch For: B Noel D~te plotted: 26-Sop-2000 Plot Refe~nce is 326 Verslon~L~. Coordinotes are in feet reference slot ~1326. rme Ve~col Depths ~ce RKB c~ot.~ by *inc~ For: B Noel Dote plotted: 26-$ep--2000 Plot Reference is 325 Verslon~,% ~r~not~ ore ;n f~t ~n~ s~t ~326. T~ Ve~al ~pths O~RKB (Nabo~ Phillips Alaska, Inc. Structure: Tarn Drill Site 2N Well : 326 Reid : Tarn Development Field Location: North Slope, Alaska Point KOP Port Collar Base Permafrost Top West Sok EOC Base West Sak 7 5/8 Casing Pt Begin Turn End Turn C80 Camp SS Begin Drop EOC C50 C40 C57 Iceberg T7 TS. 1 T5 Target- Mid Bermuda T2/C55 TD - Csq Pt. PROFILE COMMENT DATA MD Inc Dir TVD North 250.00 0.00 289.00 250.00 0.00 10`39.55 51.57 289.00 1000.00 69.0,3 1292.67 41.71 289.00 1205.00 118.19 1 610.55 54.42 289.00 141 5.00 195.02 2075.00 75.00 289.00 1619.81 `3,30.00 `3520.66 75.00 289.00 1984.00 71 7.82 4401.47 75.00 289.00 2`300.00 1054.5`3 4521.47 7`3.00 289.00 2`3`35.08 1091.69 4649.42 75.00 295.01 2572.51 1155.54 5017'.08 75.00 295.01 2480.00 1275.00 5266.76 75.00 295.01 2555.00 1566.55 8505.79 7`3.00 295.01 5500.00 2577.5`3 8691.9`3 67.42 295.01 `3565.01 2645.78 8824.72 67.42 295.01 `3614.00 2695.71 9`352.47 67.42 295.01 5809.00 2876.98 9759.51 67.42 295.01 5975.00 5051.12 0552.86 67.42 295.01 4270.00 5510.27 1077.07 67.42 295.01 4479.00 5506.70 2092.58 67.42 29,3.01 4869.00 587`3.26 2118.62 67.42 295.01 4879.00 5882.66 2248.81 67.42 295,01 4929.00 5929.65 2579.01 67.42 295.01 4979.00 ,3976.64 2679.01 67.42 295.01 5094.21 4084.9`3 Eost 0.00 -200.49 -545.25 -566.58 -958.38 -2084.71 -3061.98 -31 70.49 -3284.69 -3608.30 -3828.07 -6679.03 -6840.18 -6953.02 -7384.5`3 -7747.44 -8404.66 -8867.15 -9750.17 -9752.30 -9862.95 -9973.59 -10228.54 V. Sect 0.00 211.81 562.62 598.`3`3 1012.46 2202.54 52`34.76 3`349 .`39 5471.71 5825.21 4061.92 7158.63 7555,67 7456.24 7924.94 8519.15 9055.00 9555.55 10472.75 10496.78 10616.96 10737.14 11014.07 Deg/1 O0 0.00 4.00 4.00 4.00 4.00 0.00 0.00 0.00 5.00 0.00 0.00 0.00 `3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Creoted by F;nch ~'0~': ~ ~1'0~][ I Dote plotted: 26-~p-20~ I P~t flefe~nce ~ 326 Ve~n~3. I ~rd~notes om in ~et refem~ ~t ~26. I r~ V.~l Depth ...... ~ RKB (Nobo~ 19~.I Phillips Alaska, Inc. Structure: Torn Drill Site 2N Well : 526 Field: Torn Development Fleld Locotion: North Slope, Alosko <- West (feet) 380 360 540 520 500 280 260 240 220 200 180 160 140 22O 2OO 180 160 1800 1000 1700 1500 120 100 80 60 40 20 0 20 40 60 22o 1400 2OO 1100 180 1500 1900 160 140 1600 1400 1200 140 120 lOO 80 ~0 1200 ~ ~1100 1300 '~ ~ ~ 1200 1100 1 lOO 1200 1100 0 1000 900 · 800 500 300 700 600 2o ~ .~oo 3OO e. 5oo 3O0 ~. 7OO <- Wost 120 1500 11 O0 y " '- .. 100 z 1400 0 80O ~'- ~,? 600 80:~_ ,oo-,, - .~ 900 '~ 700 ~ " 500 ~~.800 ~ ~ "~. I --_. ",,,/lOO ~oo ~ ',. 1000 ~ ~ ~ 700 "~ "" -?, -,.~ooo ~ooX,, ,~, 2o 800 900 ~ ~ .~ ~00 X,~ ~n 400 ~ ~oo 8oo "-- -.~ ~_o,o ~ "~ 700~ ~ "~ ~ o 20 40 6O 60 600 560 _ 520 - - 480 - 4-40 40O ~o ,~_ 320 '*~ 280 0 Z 240 200 160 120 Created by finch FOl': B Noel Dote plot~d : 26--Sep-2000 Plot Re~erence is 326 Verslon~5. Coo~Jnokes ore ;n feet reference slot ~326. IT~e Ve~icol Oepth~~RKB (Nobom 19E). Phillips Alaska, Inc. Structure : Tarn Drill Site 2N Well : 526 Flsld : Tarn Deve opmenf Field Location : North Slope, Alaska <- West (feet) 1040 1000 960 920 880 840 800 760 720 680 640 600 560 520 480 440 400 .360 .:320 280 240 200 I I I I I I I I I I I II II I I I I II I 2400 I I I I I I I I I I I I I I I I I I 600 560 ' ~ ~ ~ 2200 520 ' ~ 1700 %,~ ',2600 ~ ooo :, -. '.~oo % ~oo~ '-.....900 ''' ' ~. ~8~~___ ~ / ~ ~ ~ 1800 , oo 480 400 1500 2`300 -. ' -. 360 I 2200 320 2100 1700 11 1500 1700 1800 - 1500 1700 ~ ~ ~ ~ ~ ~ ,~ 1400 1600 ~ ~ ~ ~. ~ 1500 ~ ~' 1 `300 1900 1600 1500 ! - 1600 10~ 1200 1400 1800 240 2O0 1040 1000 960 920 880 840 800 760 720 680 640 600 560 520 <- West (feet) 1700 160 400~ ~ I 120 1 1.300 1.300 -~ 11 O0 ~~ 60 '-"'- 1200 4O 480 440 400 ,350 320 ~80 240 200 Creot*d h, f;nch For: B Noel Dote plotted: 26-Sep--2000 Plot Reference is 326 Verslonj;3. Coord;notes ore in i~eet reference slot ~t326. True VerUcol Depths ore~RKB (Nobors 19E). Phillips Alaska, Inc. Sfruofure : Tarn DHII Site 2N Well : 526 Field : Tarn Deve opmenf Field Location : North Slope, Aloske <- West (feet) 5100 5000 2900 2800 2700 2600 2500 2400 2500 2200 2100 2000 1900 1800 1700 1500 1500 1400 1300 1200 1100 1000 1700 II II II II II II II II II II II I I I I I I I I I I I I I I ~ I ~ ~ ~ I 1700 5100 ~ ~ ~ ~ ~ 500 ~ 1300 1500 ~ ~ 1400 ~ , 2700 ~4100 1300 ~ ~ ~' 1300 1200 2100-~ 1100 lOOO 2ooo~~..~._~ ~5~oo -... lOOO 900 2100 900 800 800 ~. 2500 400 ' ~ ~ ~ 400 500 500 5100 5000 2900 2800 2700 2600 2500 2400 2500 2200 2100 2000 1900 1800 1700 1600 1500 1400 1500 1200 1100 1000 <- West (feet) /X I z Created by finch For; B Noel Dote plotted : 26--Sep--2000 Plot Reference ;s 326 Verslonf3. Coordlnotes ore in Feet reference slot ~326. Phillips Alaska, Inc. Structure : Tarn Drill Site 2N Well : 326 Field : Tarn Development Field Location : North Slope, Alaska 5600 5400 5200 5000 2800 2600 I - 2400- 2200 Z 2000 1800 1600 1400 1200 1000 <- West (feet) 7200 7000 6800 6600 5400 6200 6000 5800 5600 5400 5200 5000 4800 4600 4400 4200 4000 5800 5600 3400 3200 3000 i i i i i i i i i i i i i i I i i i i i i i i i i i i i i i i i i i i i i i i i i i i / %' \ f ~ ~ ~ ~ ~ ~ 5100 450(~ ~. 37 O0 4900 3400 1 .... _ ~ ~oo - ~oo ---.... ---.... ~ ~~ ~oo - 2400 ~ - 2200 500 2000 ~,__ 1800 0 1400 0 1000 i ! i i i i ! i ~ ~ i i i i i i i ! i i [ i i i ~ i i , i i i i , , , , , , i ! , , , 7200 7000 6800 6600 6400 6200 6000 5800 5600 5400 5200 5000 4800 4600 4400 4200 4000 3800 3600 .3400 .3200 .3000 <-- West (feet) Created by Rnch FO["- B Noel Ck]te plotted: 26-Sep-2000 Plot Reference is 326 Verslonjl3. Coondlnotes ore in feet rePerence slot ~326. True Vertlcol Depths .~e RKB (Nobors 19L=). Phillips Alaska, Inc. Structure : Tarn Drill Site 2N Well : 326 IField : Tarn Development Field Location : North Slope, Alaska <- West (feet) 10800 10600 10400 10200 10000 9800 9600 9400 9200 9000 8800 8600 8400 8200 8000 7800 7600 7400 7200 7000 6800 6600 6400 4800 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 4600 4400 4200 4000 380O 3600 ,+.. 3400 '~ 3200 O Z 3000 -2800 2600 2400 4900 '"'e, 4100 ~ ~ ~ 3900 I I I I I I I I I 4.500 .3700 4800 4600 4400 4200 40OO 3800 3600 3400 3200 3000 28OO 2600 Z400 2200 ~ 2200 2000 , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , !000 10800 i 0600 10400 10200 10000 9800 9600 9400 9200 9000 §800 8600 8400 8200 8000 7800 7600 7400 7200 7000 6800 0600 0400 O0 700 5',50 \ 320 310 3OO Phillips Alaska, Inc. Structure: Torn Drill Site 2N Well : 526 Field: Tarn Development Field Location: North Slope, Alaska 340 TRUE NORTH 350 0 10 2O 1500 3O 4O 2500 5( 1100 6O 29O 7O 280 8O 270 9O 260 100 250 110 24 120 2: 1700 2300 140 180 2500 2900 160 150 2500 700 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well PhilliDs Alaska, Inc. Tarn Drill Site 2N 326 slot %326 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref = 326 Version#3 Our ref : prop4027 License = Date printed : 26-SED-2000 Date created : 18-Aug-2000 Last revised = 26-Sep-2000 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is n70 10 13.189,w150 18 56.994 Slot Grid coordinates are N 5911929.737, E 460756.910 Slot local coordinates are 77.84 S 836.10 W Projection tyDe= alaska - Zone 4, Spheroid= Clarke - 1866 Reference North is True North Object wellpath PMSS <0-6043'>,,349,Tarn Drill Site 2N PMSS <2520-6498'>,,349A,Tarn Drill Site 2N PMSS <0-12735'>,,347,Tarn Drill Site 2N PMSS <10920 - 11225'>,,331,Tarn Drill Site 2N PMSS <7387 - 8182'>,,325,Tarn Drill Site 2N PMSS <0-8500'>,,317,Tarn Drill Site 2N PMSS <0-12077'>,,335,Tarn Drill Site 2N PMSS <0-9553'>,,323,Tarn Drill Site 2N PMSS <0-7039'>,,319,Tarn Drill Site 2N PMSS <266°-11061'>,,320,Tarn Drill Site 2N PMSS <5303 - 11526'>,,321,Tarn Drill Site 2N PMSS <9235 - 10028'>,,32IA,Tarn Drill Site 2N PMSS <8085-8239'>,,339,Tarn Drill Site 2N PMSS <0-10520'>,,308,Tarn Drill Site 2N PMSS <0-8960'>,,307,Tarn Drill Site 2N PMSS <288-8750'>,,309,Tarn Drill Site 2N PMSS <0-12339'>,,341,Tarn Drill Site 2N PMSS <9483 - 9631'>,,343,Tarn Drill Site 2N PMSS <0-7431'>,,345,Tarn Drill Site 2N PMSS <0-9134'>,,313,Tarn Drill Site 2N PMSS <0-9690'>,,329,Tarn Drill Site 2N PMSS <0-10655'>,,337PB1,Tarn Drill Site 2N PMSS <7090-10245'>,,337,Tarn Drill Site 2N PMSS <0-11197'>,,315,Tarn Drill Site 2N PMSS <0-11456'>,,318,Tarn Drill Site 2N PMSS <0-13692'>,,316,Tarn Drill Site 2N PMSS <0-8683'>,,332PB1,Tarn Drill Site 2N PMSS <6209 - 12026'>,,332,Tarn Drill Site 2N PMSS <0-???'>,,305,Tarn Drill Site 2N Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Divergin~ from M.D. 19-Sep-2000 19-Sep-2000 7-Jun-2000 10-May-2000 21-Dec-1998 14-Aug-1998 27-0ct-1998 15-Aug-2000 9-Oct-1998 9-Feb-1999 29-Feb-2000 21-Dec-1998 9-Oct-1998 24-Feb-1999 8-Mar-1999 30-Mar-1999 30-Sep-1998 28-Feb-2000 21-Ju1-1998 4-Aug-1998 10-May-2000 27-Jun-2000 27-Jun-2000 18-Jul-2000 1-Sep-2000 10-Aug-2000 6-Jul-2000 18-Jul-2000 26-Sep-2000 213.3 213.3 257.7 51.4 12.1 135.0 80.9 43.7 '104.7 90.2 73.0 73.0 167.3 270.1 284.4 254.2 205.0 232.3 215.7 194.8 20.8 147 5 147 5 164 6 120 2 150 1 81 1 81 1 315 i 1258.5 1258.5 1350.0 940.0 270.0 260.0 790.0 280.0 260.0 0.0 280.0 280.0 690.0 0.0 260.0 250.0 710.0 710.0 1019.5 270.0 620.0 640.0 640.0 270.0 100.0 100.0 770.0 770.0 100.0 1258.5 1258.5 1350.0 940.0 270.0 260.0 790.0 280.0 260.0 0.0 280.0 280.0 690.0 0.0 260.0 250.0 710.0 710.0 1019.5 270.0 620.0 640 0 640 0 270 0 320 0 100 0 770 0 770 0 100 0 Phillips Alaska, Inc. Tarn Drill Site 2N 326 slot %326 Tarn Development Field North Slope, Alaska 3-D M I N I M U M D I S T A N C E C L E A R A N C E R E P O R T INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : 326 Version#3 Our ref : prop4027 License : Date printed : 26-Sep-2000 Date created : 18-Aug-2000 Last revised : 26-Sep-2000 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is n70 10 13.189,w150 18 56.994 Slot Grid coordinates are N 5911929.737, E 460756.910 Slot local coordinates are 77.84 S 836.10 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS <0-6043'>,,349,Tarn Drill Site 2N PMSS <2520-6498'>,,349A,Tarn Drill Site 2N 303 Version %5,,303,Tarn Drill Site 2N PMSS <0-12735'>,,347,Tarn Drill Site 2N PMSS <10920 - 11225'>,,331,Tarn Drill Site 2N PMSS <7387 - 8182'>,,325,Tarn Drill Site 2N PMSS <0-8500'>,,317,Tarn Drill Site 2N PMSS <0-12077'>,,335,Tarn Drill Site 2N PMSS <0-9553'>,,323,Tarn Drill Site 2N PMSS <0-7039'>,,319,Tarn Drill Site 2N PMSS <266'-11061'>,,320,Tarn Drill Site 2N PMSS <5303 - 11526'>,,321,Tarn Drill Site 2N PMSS <9235 - 10028'>,,32iA,Tarn Drill Site 2N PMSS <8085-8239'>,,339,Tarn Drill Site 2N PMSS <0-10520'>,,308,Tarn Drill Site 2N PMSS <0-8960'>,,307,Tarn Drill Site 2N PMSS <288-8750'>,,309,Tarn Drill Site 2N PMSS <0-12339'>,,341,Tarn Drill Site 2N PMSS <9483 - 9631'>,,343,Tarn Drill Site 2N PMSS <0-7431'>,,345,Tarn Drill Site 2N PMSS <0-9134'>,,313,Tarn Drill Site 2N PMSS <0-9690'>,,329,Tarn Drill Site 2N PMSS <0-10655'>,,337PB1,Tarn Drill Site 2N PMSS <7090-10245'>,,337,Tarn Drill Site 2N PMSS <0-11197'>,,315,Tarn Drill Site 2N PMSS <0-11456'>,,318,Tarn Drill Site 2N PMSS <0-13692'>,,316,Tarn Drill Site 2N 322 Version #35,,322,Tarn Drill Site 2N PMSS <0-8683'>,,332PB1,Tarn Drill Site 2N PMSS <6209 - 12026'>,,332,Tarn Drill Site 2N 305 Version %5,,305,Tarn Drill Site 2N PMSS <0-???'>,,305,Tarn Drill Site 2N Closest approach with 3-D Minimum Distance method Last revised Distance 19-Sep-2000 19-SeD-2000 31-Aug-2000 7-Jun-2000 10-May-2000 21-Dec-1998 14-Aug-1998 27-0ct-1998 15-Aug-2000 9-0ct-1998 9-Feb-1999 29-Feb-2000 21-Dec-1998 9-0ct-1998 24-Feb-1999 S-Mar-1999 30-Mar-1999 30-Sep-1998 28-Feb-2000 21-Ju1-1998 4-Aug-1998 10-May-2000 27-Jun-2000 27-Jun-2000 18-Jul-2000 1-Sep-2000 10-Aug-2000 22-Aug-2000 6-Jul-2000 18-Jul-2000 1-Sep-2000 26-Sep-2000 )200.5( )200.5( )343.2( )233.7( )41.1( )9.5( )133.0( )74.8( )41.5( ) 102.7 ( )88.8( )70.3( )70.3( )160.5( )269.1( )282.4( )252.0( )198.8( )225.1( )206.6( )192.7( )16 0( )142 0( )142 0( )162 5( ) 117 0 ) 148 4 )47 2 )73 4 )73 4 ) 313 2 )313.9 M.D. Diverging from M.D. 1267.1 1267.1 1267.1 1267.1 270.0 270.0 1584.6 11050.0 969.9 6900.0 290.0 290.0 270.0 6600.0 790.0 12180.0 300.0 1990.0 270.0 270.0 200.0 9460.0 300.0 11620.0 300.0 11460.0 690.0 10240.0 250.0 12650.0 280.0 12520.0 270.0 9140.0 720.0 12560.0 720.0 720.0 1029.4 1029.4 290.0 7760.0 630.0 6840.0 650.0 12520.0 650.0 10660.0 290.0 12050.0 350.0 11420.0 260.0 12640.0 440.0 3880.0 800.0 12400.0 800.0 11750.0 270.0 270.0 200.0 200.0 PhilliDs Alaska, Inc. Tarn Drill Site 2N 326 slot %326 Tarn DeveloDment Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 326 Version#3 Our ref : proD4027 License : Date printed : 26-Sep-2000 Date created : 18-Aug-2000 Last revised : 26-Sep-2000 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is n70 10 13.189,w150 18 56.994 Slot Grid coordinates are N 5911929.737, E 460756.910 Slot local coordinates are 77.84 S 836.10 W Projection tyDe: alaska - Zone 4, SDheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. Tarn Drill Site 2N,326 Tar~ Development Field,North Slope, A1 PROPOSAL LISTING ~ 1 Your ref : 326~ Last revised : 26-Sep-z000 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 289.00 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 289.00 200.00 0.00 N 0.00 E 0.00 0.00 250.00 0.00 289.00 250.00 0.00 N 0.00 E 0.00 0.00 KOP 350.00 4.00 289.00 349.92 1.14 N 3.30 W 4.00 3.49 450.00 8.00 289.00 449.35 4.54 N 13.18 W 4.00 13.92 550.00 12.00 289.00 547.81 10.19 N 29.60 W 4.00 31.27 650.00 16.00 289.00 644.82 18.07 N 52.47 W 4.00 55.43 750.00 20.00 289.00 739.91 28.12 N 81.68 W 4.00 86.29 850.00 24.00 289.00 832.61 40.32 N 117.09 W 4.00 123.70 950.00 28.00 289.00 922.47 54.59 N 158.53 W 4.00 167.48 1039.35 31.57 289.00 1000.00 69.03 N 200.49 W 4.00 211.81 Port Collar 1050.00 32.00 289.00 1009.05 70.86 N 205.80 W 4.00 217.41 1150.00 36.00 289.00 1091.94 89.06 N 258.66 W 4.00 273.25 1250.00 40.00 289.00 1170.73 109.10 N 316.86 W 4.00 334.74 1292.67 41.71 289.00 1203.00 118.19 N 343.25 W 4.00 362.62 Base Permafrost 1350.00 44.00 289.00 1245.02 130.88 N 380.11 W 4.00 401.56 1450.00 48.00 289.00 1314.48 154.30 N 448.11 W 4.00 473.40 1550.00 52.00 289.00 1378.74 179.23 N 520.53 W 4.00 549.90 1610.55 54.42 289.00 1415.00 195.02 N 566.38 W 4.00 598.33 Top West Sak 1650.00 56.00 289.00 1437.51 205.57 N 597.01 W 4.00 630.70 1750.00 60.00 289.00 1490.49 233.17 N 677.18 W 4.00 715.39 1850.00 64.00 289.00 1537.43 261.91 N 760.65 W 4.00 803.57 1950.00 68.00 289.00 1578.09 291.65 N 847.01 W 4.00 894.80 2050.00 72.00 289.00 1612.29 322.23 N 935.84 W 4.00 988.64 2075.00 73.00 289.00 1619.81 330.00 N 958.38 W 4.00 1012.46 BOC 2500.00 73.00 289.00 1744.06 462.32 N 1342.67 W 0.00 1418.43 3000.00 73.00 289.00 1890.25 617.99 N 1794.77 W 0.00 1896.04 3320.66 73.00 289.00 1984.00 717.82 N 2084.71 W 0.00 2202.34 Base West Sak 3500.00 73.00 289.00 2036.44 773.66 N 2246.87 W 0.00 2373.65 4000.00 73.00 289.00 2182.62 929.33 N 2698.97 W 0.00 2851.27 4401.47 73.00 289.00 2300.00 1054.33 N 3061.98 W 0.00 3234.76 7 5/8" Casing Pt 4500.00 73.00 289.00 2328.81 1085.00 N 3151.07 W 0.00 3328.88 4521.47 73.00 289.00 2335.08 1091.69 N 3170.49 W 0.00 3349.39 Begin Turn 4600.00 72.99 291.46 2358.05 1117.65 N 3240.95 W 3.00 3424.45 4649.42 73.00 293.01 2372.51 1135.54 N 3284.69 W 3.00 3471.71 End Turn 5000.00 73.00 293.01 2475.01 1266.61 N 3593.27 W 0.00 3806.88 5017.08 73.00 293.01 2480.00 1273.00 N 3608.30 W 0.00 3823.21 C80 5266.76 73.00 293.01 2553.00 1366.35 N 3828.07 W 0.00 4061.92 Camp SS 5500.00 73.00 293.01 2621.19 1453.55 N 4033.36 W 0.00 4284.91 6000.00 73.00 293.01 2767.38 1640.49 N 4473.46 W 0.00 4762.94 6500.00 73.00 293.01 2913.56 1827.42 N 4913.55 W 0.00 5240.98 7000.00 73.00 293.01 3059.75 2014.36 N 5353.65 W 0.00 5719.01 7500.00 73.00 293.01 3205.94 2201.29 N 5793.74 W 0.00 6197.04 8000.00 73.00 293.01 3352.12 2388.23 N 6233.84 W 0.00 6675.07 8500.00 73.00 293.01 3498.31 2575.17 N 6673.94 W 0.00 7153.10 8505.79 73.00 293.01 3500.00 2577.33 N 6679.03 W 0.00 7158.63 Begin Drop 8600.00 70.17 293.01 3529.76 2612.27 N 6761.30 W 3.00 7247.99 8691.93 67.42 293.01 3563.01 2645.78 N 6840.18 W 3.00 7333.67 EOC 8824.72 67.42 293.01 3614.00 2693.71 N 6953.02 W 0.00 7456.24 C50 Ail data is in feet unless otherwise stated. Coordinates from slot %326 and TVD from RKB (Nabors 19B) (153.00 Ft above mean sea level). Bottom hole distance is 11014.07 on azimuth 291.77 degrees from wellhead. Total Dogleg for wellpath is 82.42 degrees. Vertical section is from wellhead on azimuth 291.72 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ PhilliDs Alaska, Inc. Tarn Drill Site 2N,326 Tar~ DeveloDment Field,North SloDe, A1 Measured Inclin. Azimuth True Vert R E C T A N G U L A R DeDth Degrees Degrees DeDth C 0 0 R D I N A T E S PROPOSAL LISTING Your ref : 326 Last revised : 26-SeD-~u00 Dogleg Vert Deg/100ft Sect 9000.00 67.42 293.01 3681.32 2756.98 N 7101.98 W 0.00 7618.04 9332.47 67.42 293.01 3809.00 2876.98 N 7384.53 W 0.00 7924.94 C40 9500.00 67.42 293.01 3873.34 2937.45 N 7526.90 W 0.00 8079.58 9759.51 67.42 293.01 3973.00 3031.12 N 7747.44 W 0.00 8319.13 C37 10000.00 67.42 293.01 4065.36 3117.93 N 7951.82 W 0.00 8541.12 10500.00 67.42 293.01 4257.38 3298.41 N 8376.74 W 0.00 9002.66 10532.86 67.42 293.01 4270.00 3310.27 N 8404.66 W 0.00 9033.00 Iceberg 11000.00 67.42 293.01 4449.40 3478.89 N 8801.66 W 0.00 9464.20 11077.07 67.42 293.01 4479.00 3506.70 N 8867.15 W 0.00 9535.35 T7 11500.00 67.42 293.01 4641.42 3659.36 N 9226.58 W 0.00 9925.74 12000.00 67.42 293.01 4833.44 3839.84 N 9651.50 W 0.00 10387.29 12092.58 67.42 293.01 4869.00 3873.26 N 9730.17 W 0.00 10472.75 T3.1 12118.62 67.42 293.01 4879.00 3882.66 N 9752.30 W 0.00 10496.78 T3 12248.81 67.42 293.01 4929.00 3929.65 N 9862.95 W 0.00 10616.96 Target %3 Rvsd 12-SeD-00 12379.01 67.42 293.01 4979.00 3976.64 N 9973.59 W 0.00 10737.14 T2/C35 12500.00 67.42 293.01 5025.47 4020.32 N 10076.41 W 0.00 10848.83 12679.01 67.42 293.01 5094.21 4084.93 N 10228.54 W 0.00 11014.07 TD - Csg Pt. Ail data is in feet unless otherwise stated. Coordinates from slot 9326 and TVD from RKB (Nabors 19E) (153.00 Ft above mean sea level). Bottom hole distance is 11014.07 on azimuth 291.77 degrees from wellhead. Total Dogleg for wellDath is 82.42 degrees. Vertical section is from wellhead on azimuth 291.72 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ PhilliDs Alaska, Inc. Tarn Drill Site 2N,326 Tarn DeveloDment Field,North SloDe, A1 ~..~ PROPOSAL LISTING [' 3 Your ref : 326 ~ ~n#3 Last revised : 26-Sep-~000 Comments in wellDath MD TVD Rectangular Coords. Comment 250.00 250.00 0.00 N 0.00 E KOP 1039.35 1292.67 1610.55 2075.00 3320.66 4401.47 4521.47 4649.42 5017.08 5266.76 8505.79 8691.93 8824.72 9332.47 9759.51 10532 86 11077 07 12092 58 12118 62 12248 81 12379 01 12679 01 1000.00 1203.00 1415.00 1619.81 1984.00 2300.00 2335.08 2372.51 2480.00 2553.00 3500.00 3563.01 3614.00 3809.00 3973.00 4270.00 4479.00 4869.00 4879.00 4929.00 4979.00 5094.21 69.03 N 118.19 N 195.02 N 330.00 N 717 82 N 1054 33 N 1091 69 N 1135 54 N 1273 00 N 1366 35 N 2577 33 N 2645 78 N 2693.71 N 2876.98 N 3031.12 N 3310.27 N 3506.70 N 3873.26 N 3882.66 N 3929.65 N 3976.64 N 4084.93 N 200.49 W Port Collar 343.25 W Base Permafrost 566.38 W ToD West Sak 958.38 W EOC 2084.71 W Base West Sak 3061.98 W 7 5/8" Casing Pt 3170.49 W Begin Turn 3284.69 W End Turn 3608.30 W CS0 3828.07 W CamD SS 6679.03 W Begin DroD 6840.18 W EOC 6953.02 W C50 7384.53 W C40 7747.44 W C37 8404.66 W Iceberg 8867.15 W T7 9730.17 W T3.1 9752.30 W T3 9862.95 W Target %3 Rvsd 12-SeD-00 9973.59 W T2/C35 10228.54 W TD - Csg Pt. Casing Dositions in string 'A' TOD MD ToD TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 4401.47 2300.00 0.00 0.00 0.00N 0.00E 12679.00 5094.21 Target name 1054.33N 3061.98W 7 5/8 Casing 4084.93N 10228.53W 5 1/2 Casing Targets associated with this wellDath GeograDhic Location T.V.D. Rectangular Coordinates Revised Target 93 Rvsd 12-Se 450915.000,5915909.000,2.0000 4929.00 3929.65N 9862.95W 16-Aug-2000 Phillips Alaska, Inc. Nabors 19e 11" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT r--j MANUAL GATE VALVE ~.,~ _ 3" 5,000 psi WP Shaffer GATE VALVE L. w/hydraulic actuator / / DSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP i 11" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 11" 5,000 psi WP, HYDRIL Magnum BOP w/pipe roms on top and blind roms on bottom 3" 5,000 psi WP Shaffer GATE VALVE ~raulic actuator 3 11" 5,000 psi WP L.~~ DRILLING SPOOL w/two 3" 5M psi WP outlets SINGLE 11" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams Phillips Alaska, Inc. Diverter Schematic Nabors 19e 21 ~" 2,000 psi WP DRILLING SPOOL w/16" Outlet 16-3/4" 2M SOW Starting Head Flowline ~ 21 ~" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER LINE 16-3/4" x 21-1/4" x 2M Psi DSA Flange 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) .. ,. ADMINIST._~____RATION A~ DATE ' ENGINEERING APPR 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 drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. ConduCtorstdng provided ................... (~)N 15. Surface casing protects all known USDWs.. .......... 16. CMT vol adequate to circulate on conductor & surf csg ..... ~) N 17. CMT vol adequate to tie-in long string to surf csg ........ Y~ N 18. CMT will cover all known productive hodzons .......... L~ N 19. Casing 0esigns adequate for C, T, B & permafrost ....... · N 20. Adequate tankage or reserve pit ................. (3~) N 21. If a re-drill, has a 10-403 for abandonment been approved... "N-/b~ 22. Adequate wellbore separation proposed ............. (~ N 23. If diverter required, does it meet regulations .......... ~ N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet'regulation ................ N 26. BOPE press rating appropriate; test to"~,5"O~ psig. N 27. Choke manifold complies w/APl RP-53'~May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued wlo hydrogen ,sulfide measures ..... (~) N 31. Data presented on potential overpressure zones ....... ~Y'"N 32. Seismic analysis of shallow gas zones... ~ /' Y N 33. Seabed conditionsurvey(ifoff-shore).., i'i~i i i ~U~'\ Y N 34. Contact name/phone for weekly progress reports [ex~ratory only] Y N _~ DATE ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and E will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: Y N Y N Y N Y N Y N ENGINEERING: UICIAnnular COMMISSIO__N: Comments/Instructions: 0 Z 0 _2 z -.-i -1- c:~nsoffice~wordian\diana\checklist (rev. 02/17100) 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. .o ,, 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 APPEN. DIX.' 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 $ Sun Sep 23 11:48:29 2001 2N326.tapx Reel Header Service name ............. LISTPE Date ..................... 01/09/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/09/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technicai Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit (Tarn Pool) 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 MWD RUN 4 AK-MM-00217 B. HENNINGSE D. GLADDEN 2N-326 501032035100 Phillips Alaska Inc. Sperry Sun 23-SEP-01 MWD RUN 5 AK-MM-00217 J. MARTIN D. GLADDEN MWD RUN 6 AK-MM-00217 J. MARTIN R. SPRINGER 3 9N 7 E 79 836 155.03 153.70 119.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 16.000 118.0 2ND STRING 9.875 7.625 4295.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 - 3 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED Page 1 2N326.tapx 3, MWD RUNS 4 - 6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITH-DENSITY (SLD). 4. GAMMA RAY LOGGED BEHIND CASING TO 4295' MD, 2299' TVD. 5. CONVENTIONAL BULK DENSITY, STANDOFF CORRECTION, AND PHOTO ELECTRIC ABSORPTION FACTOR ARE PRESENTED FROM 8888' MD, 3797' TVD TO 9485' MD, 4010' TVD DUE TO RAPID SAMPLE MEMORY IN STABILIZED LITHO-DENSITY (SLD) BEING FILLED DURING RUN 4. 6. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. OF 11/28/00. MWD DATA CONSIDERED PDC. 7. MWD RUNS i - 6 REPRESENT WELL 2N-326 WITH API % 50-103-20351-00. THIS WELL REACHED A TOTAL DEPTH OF 12775' MD, 5076' TVD. SROP = SMOOTHED RATE OF PENETRATION 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 SBD2 = SMOOTHED BULK DENSITY RAPID SAMPLE (LOW-COUNT BIN) SCO2 = SMOOTHED STANDOFF CORRECTION RAPID SAMPLE (LOW-COUNT BiN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR RAPID SAMPLE (LOW-COUNT BIN) SBDC = SMOOTHED BULK DENSITY COMPESATED CONVENTIONAL (LOW-COUNT BIN) SCOR = SMOOTHED STANDOFF CORRECTION CONVENTIONAL SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR CONVENTIONAL (LOW-COUNT BIN) TNPS = SMOOTHED THERMAL NEUTRON 'POROSITY (SANDSTONE MATRIX, FIXED HOLE SI CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE ENVIRONMENTAL PARAMETERS USED IN PROCESSING THE NEUTRON LOG DATA: HOLE SIZE: 7.5" & 6.75" MUD WEIGHT: 9.60 - 10.5 PPG MUD FILTRATE SALINITY: 250 - 400 PPM CHLORIDES FORMATION WATER SALINITY: 19,149 PPM CHLORIDES FLUID DENSITY: 1.00 G/CC MATRIX DENSITY: 2.65 Page 2 2N326.tapx G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 4252.5 12721.5 RPX 4285.0 12728.5 RPS 4285.0 12728,5 RPM 4285.0 12728.5 RPD 4285,0 12728.5 FET 4285.0 12728.5 NPHI 4285.0 12684.0 NCNT 4285.0 12684.0 FCNT 4285.0 12684.0 RHOB 4302.5 12700,0 PEF 4302.5 12700.0 DRHO 4302.5 12700.0 ROP 4303.0 12775.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 4 4252.5 MWD 5 9570.5 MWD 6 12176,5 $ REMARKS: 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 DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HR 4 1 68 EQUIVALENT UNSHIFTED DEPTH MERGE BASE 9570.0 12176.0 12775.0 Units Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Page 3 2N326. tapx NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CP30 4 1 68 36 10 NCNT MWD CP30 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 Name Service Unit Min Max DEPT FT 4252.5 12775 ROP MWD FT/H 0 1417.1 GR MWD API 42.18 253.22 RPX MWD OHMM 1.11 1742.41 RPS MWD OHMM 0.79 54.24 RPM MWD OHMM 0.81 2000 RPD MWD OHMM 0.85 2000 FET MWD HR 0.52 56.6 NPHI MWD PU-S 11.28 55.24 FCNT MWD CP30 108,28 1036.34 NCNT MWD CP30 13280.5 34180.9 RHOB MWD G/CM 1.34 2.89 DRHO MWD G/CM -0.28 0.82 PEF MWD B/E 1.65 11.64 First Reading For Entire File .......... 4252.5 Last Reading For Entire File ........... 12775 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1,0.0 Date of Generation ....... 01/09/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Mean Nsam 8513.75 17046 76.0142 16945 137.684 16939 4.68071 16888 4.76191 16888 7.05793 16888 8.40774 16888 2.06366 16888 35.0402 16799 237.387 16799 18859.3 16799 2.24217 16796 0,0354394 16796 3.33702 16796 First Reading 4252.5 4303 4252.5 4285 4285 4285 4285 4285 4285 4285 4285 4302.5 4302.5 4302.5 Last Reading 12775 12775 12721 5 12728 5 12728 5 12728 5 12728 5 12728 5 12684 12684 12684 12700 12700 12700 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/23 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4252.5 9510.0 RPM 4285.0 9517.0 NCNT 4285.0 9472,5 FCNT 4285.0 9472.5 NPHI 4285.0 9472.5 RPD 4285.0 9517,0 RPS 4285.0 9517.0 RPX 4285.0 9517.0 FET 4285.0 9517.0 RHOB 4302.5 8888.0 DRHO 4302.5 8888.0 Page 4 PEF 4302.5 ROP 4303.0 DRHO 8888.5 PEF 8888.5 RROB 8888.5 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 8888.0 9570.0 9484.5 9484.5 9484.5 2N326.tapx 22-OCT-00 Insite 4.05.3 4.15 Memory 9570.0 67.2 73.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01691GRF4 EWR4 ELECTROMAG. RESIS. 4 PB01691GRF4 SLD STABILIZED LITHO DEN PB01686WNL4 CTN COMP THERMAL NEUTRON PB01686WNL4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 7.500 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 46.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2,500 MUD AT MAX CIRCULATING TERMPERATURE: 1.488 MUD FILTRATE AT MT: 2,000 MUD CAKE AT MT: 3.500 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 Page 5 66.0 115.5 62.0 62.0 2N326.tapx RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 NPHI MWD040 PU 4 1 68 32 9 FCNT MWD040 CP30 4 1 68 36 10 NCNT MWD040 CP30 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 B/E 4 1 68 52 14 RHOB MWD040 G/CM 4 1 68 56 15 DRHO MWD040 G/CM 4 1 68 60 16 PEF MWD040 B/E 4 1 68 64 17 Name Service Unit Min Max DEPT FT 4252,5 9570 ROP MWD040 FT/H 0 232..24 GR MWD040 API 42,18 253,22 RPX MWD040 OHMM 1,11 1742,41 RPS MWD040 OHMM 0,79 54.24 RPM MWD040 OHMM 0,8~ 2000 RPD MWD040 OHMM 0,85 2000 FET MWD040 HR 0.52 56,6 NPHI MWD040 PU 18,39 55,24 FCNT MWD040 CP30 108,28 479,25 NCNT MWD040 CP30 13280.5 26208,7 RHOB MWD040 G/CM 1,61 2.67 DRHO MWD040 G/CM -0,12 0,52 PEF MWD040 B/E 1.65 11,64 RHOB MWD040 G/CM 1,34 2,89 DRHO MWD040 G/CM -0,28 0,82 PEF MWD040 B/E 2.14 7,84 Mean Nsam 6911,25 10636 85,0949 10535 134.539 10516 4.61721 10465 4.63569 10465 8,16846 10465 10,2139 10465 1,68616 10465 36,9948 10376 208,411 10376 17923,5 10376 2.17888 9172 0,0276112 9172 2,93023 9172 2,13802 1193 0,089606 1193 3,9379 1193 First Reading For Entire File .......... 4252,5 Last Reading For Entire File ........... 9570 File Trailer Service name ............. STSLIB,002 Service Sub Level Name,,, Version Number ........... 1,0,0 Date of Generation ....... 01/09/23 Maximum Physical Record,,65535 File Type ................ LO Next File Name ........... STSLIB,003 First Reading 4252,5 4303 4252,5 4285 4285 4285 4285 4285 4285 4285 4285 4302,5 4302.5 4302,5 8888.5 8888.5 8888,5 Last Reading 9570 9570 9510 9517 9517 9517 9517 9517 9472,5 9472,5 9472,5 8888 8888 8888 9484,5 9484.5 9484,5 Physical EOF File Header Service name ............. STSLIB,003 Service Sub Level Name,,, Version Number ........... 1.0,0 Date of Generation ....... 01/09/23 Maximum Physical Record,,65535 File Type ................ LO Previous File Name ....... STSLIB,002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files, BIT RUN NUMBER: 5 DEPTH INCREMENT: ,5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 9473,0 12081,5 Page 6 FCNT 9473.0 12081.5 NPHI 9473.0 12081.5 RHOB 9485.0 12097.5 PEF 9485.0 12097.5 DRHO 9485.0 12097.5 GR 9510.5 12119.0 RPX 9517.5 12128.5 RPS 9517,5 12128.5 RPM 9517.5 12128.5 RPD 9517.5 12128.5 FET 9517.5 12128.5 ROP 9570.5 12176.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 2N326.tapx 28-OCT-00 Insite 4.05.3 4.15 Memory 12176.0 68.1 72.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01686WNL4 EWR4 ELECTROMAG. RESIS. 4 PB01686WNL4 SLD STABILIZED LITHO DEN PB01686WNL4 CTN COMP THERMAL NEUTRON PB01686WNL4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 7.500 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.50 MUD VISCOSITY (S): 46.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.200 MUD AT MAX CIRCULATING TERMPERATURE: 1.119 MUD FILTRATE AT MT: 2.000 MUD CAKE AT MT: 2.500 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... 66.0 136.4 66.0 66.0 Page 7 2N326.tapx Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD050 FT/H 4 1 68 GR MWD050 API 4 1 68 RPX MWD050 OHMM 4 1 68 RPS MWD050 OHMM 4 1 68 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1 68 FET MWD050 HR 4 1 68 NPHI MWD050 PU 4 1 68 FCNT MWD050 CP30 4 1 68 RHOB MWD050 G/CM 4 1 68 DRHO MWD050 G/CM 4 i 68 PEF MWD050 B/E 4 i 68 NCNT MWD050 CP30 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 DEPT FT 9473 ROP MWD050 FT/H 3.21 GR MWD050 API 95.01 RPX MWD050 OHMM 1.57 RPS MWD050 OHMM 1.68 RPM MWD050 OHMM 1.84 RPD MWD050 OHMM 1.7 FET MWD050 HR 0.71 NPHI MWD050 PU 11.28 FCNT MWD050 CP30 144.22 RHOB MWD050 G/CM 1.71 DRHO MWD050 G/CM -0.16 PEF MWD050 B/E 2.34 NCNT MWD050 CP30 15660.8 Max 12176 1417.1 196.99 11 26 10 68 14 28 15 12 37 53 50 51 934 45 2 72 0 44 9 26 31988.3 First Reading For Entire File .......... 9473 Last Reading For Entire File ........... 12176 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0,0 Date of Generation ....... 01/09/23 Maximum Physical Record.,65535 File Type ................ LO Next File Name ........... STSLIB.004 Mean 10824,5 58.506 142.748 4.52195 4,7156 5.01637 5.20758 2.55992 32.8082 262.159 2.35287 0.0368064 3.91749 19777.1 Nsam 5407 5212 5218 5223 5223 5223 5223 5223 5218 5218 5226 5226 5226 5218 First Reading 9473 9570.5 9510 5 9517 5 9517 5 9517 5 9517 5 9517 5 9473 9473 9485 9485 9485 9473 Last Reading 12176 12176 12119 12128.5 12128.5 12128.5 12128.5 12128.5 12081.5 12081.5 12097.5 12097.5 12097.5 12081.5 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name.., Version Number ........... 1.0.0 Date of Generation ....... 01/09/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH Page 8 FCNT 12082.0 NCNT 12082.0 NPHI 12082.0 RHOB 12098.0 DRHO 12098.0 PEF 12098.0 GR 12119.5 RPX 12129.0 RPS 12129.0 RPM 12129.0 RPD 12129.0 FET 12129.0 ROP 12176.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 12684 12684 12684 12700 12700 12700 12721 5 12728 5 12728 5 12728 5 12728 5 12728.5 12775.0 2N326.tapx .0 .0 .0 0 0 0 29-OCT-00 Insite 4.05.3 4.15 Memory 12775.0 70.5 75.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01691GRF4 EWR4 ELECTROMAG. RESIS. 4 PB0169iGRF4 SLD STABILIZED LITHO DEN PB01686WNL4 CTN COMP THERMAL NEUTRON PB01686WNL4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 6.750 LSND 10.50 48.0 9.5 25O 4.0 2.200 68.0 1.195 130.9 2.000 66.0 2.400 66.0 Page 9 2N326.tapx Depth Units ....................... Datum Specification Block sub-type. ,,0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD060 FT/H 4 1 68 GR MWD060 API 4 1 68 RPX MWD060 OHMM 4 1 68 RPS MWD060 OHMM 4 1 68 RPM MWD060 OHMM 4 1 68 RPD MWD060 OHMM 4 1 68 FET MWD060 HR 4 1 68 NPHI MWD060 PU-S 4 1 68 FCNT MWD060 CP30 4 1 68 NCNT MWD060 CP30 4 1 68 RHOB MWD060 G/CM 4 1 68 DRHO MWD060 G/CM 4 1 68 PEF MWD060 B/E 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 12082 12775 ROP MWD060 FT/H 3,42 284,54 GR MWD060 API 91,56 177,1 RPX MWD060 OHMM 2,71 26,6 RPS MWD060 OHMM 2,79 25,18 RPM MWD060 OHMM 2,92 23.6 RPD MWD060 OHMM 3 23,73 FET MWD060 HR 0,71 28.06 NPHI MWD060 PU-S 12.48 39,67 FCNT MWD060 CP30 257,02 1036,34 NCNT MWD060 CP30 18134,3 34180,9 RHOB MWD060 G/CM 1,68 2,57 DRHO MWD060 G/CM -0,04 0,34 PEF MWD060 B/E 2,35 6,49 First Reading For Entire File .......... 12082 Last Reading For Entire File ........... 12775 File Trailer Service name ............. STSLIB,004 Service Sub Level Name,,. Version Number ........... 1,0,0 Date of Generation ....... 01/09/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB,005 First Last Mean Nsam Reading Reading 12428,5 1387 12082 12775 72,3313 1198 12176,5 12775 143,204 1205 12119,5 12721,5 5.92554 1200 12129 12728,5 6,06412 1200 12129 12728,5 6,25904 1200 12129 12728,5 6,58481 1200 12129 12728,5 3,19584 1200 12129 12728..5 27,8751 1205 12082 12684 379,616 1205 12082 12684 22942,1 1205 12082 12684 2,34698 1205 12098 12700 0,0354689 1205 12098 12700 3,32101 1205 12098 12700 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/09/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library, Reel Trailer Service name ............. LIST?E Date ..................... 01/09/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library, Scientific Technical Services Scientific Technical Services Page 10 2N326.tapx Physical EOF Physical EOF End Of LIS File Page 11