Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
198-163
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\4MY18Q6V\2025-08-20_24024_KRU_2N-325_EVCamera_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 198163 KRU 2N-325 50-103-20269-00 EV Camera 20-Aug-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 198-163 T40798 8/25/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.25 08:56:38 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, October 14, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2N-325 KUPARUK RIV U TARN 2N-325 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/14/2024 2N-325 50-103-20269-00-00 198-163-0 W SPT 5015 1981630 3900 2050 2050 2050 2050 50 50 50 50 REQVAR P Josh Hunt 8/6/2024 2-Year MIT-IA requried by AIO 16.001 Required test pressure to pass is the max anticipated injection pressure of 3000 psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U TARN 2N-325 Inspection Date: Tubing OA Packer Depth 1010 3280 3200 3200IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240806162032 BBL Pumped:1.2 BBL Returned:1.3 Monday, October 14, 2024 Page 1 of 1 9 9 9 9 99 9 99 9 9 9 9 9 9 92-Year MIT-IA AIO 16.001 James B. Regg Digitally signed by James B. Regg Date: 2024.10.14 16:17:05 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 29, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2N-325 KUPARUK RIV U TARN 2N-325 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2022 2N-325 50-103-20269-00-00 198-163-0 W SPT 5015 1981630 3000 2000 2000 2000 2000 50 50 50 50 REQVAR P Adam Earl 8/1/2022 MIT-IA tested as per AIO 16.001 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U TARN 2N-325 Inspection Date: Tubing OA Packer Depth 730 3320 3250 3250IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220803211838 BBL Pumped:1.5 BBL Returned:1.6 Monday, August 29, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 AIO 16.001 James B. Regg Digitally signed by James B. Regg Date: 2022.08.29 15:57:37 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Wednesday, August 12, 2020 C �/ P.I. Supervisor �� �(`t 2Lt?.Q SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2N-325 FROM: Lou Laubenstein KUPARUK RIV U TARN 2N-325 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2N-325 API Well Number 50-103-20269-00-00 Inspector Name: Lou Laubenstein Permit Number: 198-163-0 Inspection Date: 8/3/2020 Insp Num: mitLOL200804122933 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2N-325 Type Inj -TVD 5015 Tubing 1975 1975 - 1975 - 1975 - PTD 1981630 Type Test! SPT' Test psi 3000 IA 600 3320 3230 - 3220 ' BBL Pumped: 1.4 - BBL Returned: 1.3 OA 45 - 50. 50 - 50 - 50' — Interval REQVAR WF P Notes' MIT -IA to Maximum anticipated injection perssure per A10 16.001 Wednesday, August 12, 2020 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,April 21,2017 TO: Jim Regg 4 P.I.Supervisor t ' 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2N-325 FROM: Lou Grimaldi KUPARUK RIV U TARN 2N-325 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name KUPARUK RIV U TARN 2N-325 API Well Number 50-103-20269-00-00 Inspector Name: Lou Grimaldi Permit Number: 198-163-0 Inspection Date: 2/14/2017 Insp Num: mitLG170214150403 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2N-325 ' Type Inj W 1TVD 5015 • Tubing 1925 1925 • 1925 . 1925 - — PTD1981630 _ Type Test_SPT Test psi 1500 ' IA 420 3300 - 3230 - 3220 .. BBL Pumped: 1.6 - BBL Returned_ 1.5 . OA 50 50 - 50 50 - Interval Required by Variance P/F Pass Notes: Test required by AIO 16.001.All required paperwork supplied on location.Good test.During test bubbling was noticed in cellar.Well historically has bubbling in cellar that tested showed not to be lift gas composition. SCANNED AUG 1 5201 Friday,April 21,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,January 04,2016 TO: Jim Regg ,---)I. PRe= P.I.Supervisor et 7 SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA INC 2N-325 FROM: Chuck Scheve KUPARUK RIV U TARN 2N-325 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ,f C— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2N-325 API Well Number 50-103-20269-00-00 Inspector Name: Chuck Scheve Permit Number: 198-163-0 Inspection Date: 12/27/2015 Insp Num: mitCS151228062616 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ------------- Well 2N-325 . Type In' W-TVD 5015 Tubing 1740 1750 - 1750 - 1750 J PTD 1981630 - Type Test SPT Test psi 3000 - , IA 460 3300 3250 - 3250 - I � y IntervallREQvAR P/F P ✓I OA 50 50 50 50 Notes: Tested per A1O 16.001. Slow flange leak on the well head during initial test attempt. Flange was retorqued and test completed. ,, SCANNED SEP 1 6 2016. Monday,January 04,2016 Page 1 of 1 F • • 4,9 P * \ \I %%�s THE STATE �'d g Gil Gas - 9� f cs„..ionservation Commission : -ice 7 = - -= -- GOVERNOR SEAN PARNELL 333 West Seventh Avenue � F ..4i :' Anchorage, Alaska 99501 -3572 t a \, Main: 907.279.1433 `U Fax: 907.276.7542 Martin Walters SC°P*4° J Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. 1 P.O. Box 100360 8 ' 1 Anchorage, AK 99510 �/ g � ` f Re: Kuparuk River Field, Tarn Oil Pool, 2N -325 Sundry Number: 313 -310 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, i9; Cathy P. erster Chair S DATED this day of June, 2013. Encl. STATE OF ALASKA : 07 7v "� /.T • ALL OIL AND GAS CONSERVATION COMOSION . y �� I N. 20 1`�, '� 00. :.�+ APPLICATION FOR SUNDRY APPROVALS (0' I 20 AAC 25.280 � 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 d 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 198 -163 • 3. Address: 6. API Number: Stratigraphic r Service r7 P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20269 -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 - 325 •• 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0380054 , 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): 8182 • 5459 Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 108' 108' 1640 630 SURFACE 2633 7 -5/8 2662' 2317' 6890 4790 PRODUCTION 7368 5 -1/2 7397' 5061' 7000 4990 PRODUCTION 765 3 -1/2 8162' 5448' 10160 10540 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7690 -7708, 7714 -7728, 7734 -7750, 5186 -5196, 5200 -5208, 5211 -5221, 5221- 7750 -7770, 7778 -7784, 7794 -7802, 5231, 5236 -5240, 5245 -5250, 5260 -5269 3.5 L -80 7395 7819 -1835 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) BAKER 80 -40 CASING SEAL ASSEMBLY • MD= 7396 TVD= 5016 CAMCO DS NIPPLE • MD = 517 TVD = 517 12. Attachments: Description Summary of Proposal • F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service P''' 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 �. 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: N1878( cop.com Printed Name Martin Walters 4 Title: Well Integrity Projects Supervisor Signature WOW f ftr / / / Phone: 659 -7043 Date: 06/16/13 Commission Use Only Sundry Number: 3 3, 0 Conditions of approval: Notify Commission so that a representative may witness / Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: ABDMS JUN 26 20(3) Spacing Exception Required? Yes ❑ No L.iJ Subsequent Form Required: l _ 4 ti t_ (10 � ' / APPROVED BY Approved by: , 2 `� - 1-4 -, Y--'� COMMISSIONER THE COMMISSION Date: G - � -- 2012 Submit Form and Attachments Approved application is valid for 12 months trom the date of approval. `� Form 10 -403 (Revise 10/s in Duplicate ` , kr - /zi/)3 ORIGINAL � 1 � LIN • Conoco Phillips � -; 11 0 Alaska 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-325, PTD 198 -163 conductor extension. Please contact Martin Walters or MJ Loveland at 659 -7043 if you have any questions. Sincerely, 0 4 - 7WW /i - Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 ConocoPhillips Alaska, Inc. Kuparuk Well 2N -325 (PTD 198 -163) SUNDRY NOTICE 10 -403 APPROVAL REQUEST June 16, 2013 This application for Sundry approval for Kuparuk well 2N -325 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 10 3 /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 .,per 1 KUP • 2N -325 ' ConocorhMips Well Attributes Max Angle & MD TD Alaska Inc Wellbore API /UWI ' Field Name ell Status Inc! ( °) MD (ftKB) Act Btu (ftKB) oPnm p. $ 501032026900 TARN PARTICIPATING AREA � 57.34 4,097.08 8,182.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date -' SSSV: NIPPLE Last WO: 34.59 9/18/1998 Well Config: -2N- 325.3/2/101080403 AM - -- Schematic -Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: RKB 7,962.6 6/21/2009 Rev Reason: WAIVERED WELL _ _- Imosbor 3/2/2010 -.. Casing Strings_ Casing Description String 0... Sting ID ... Top (960) ' Set Depth (1... Set Depth (TVD) .. String Wt... String ... String Top Thrd HANGER, 26 • ' CONDUCTOR 16 15.062 34.6 108.0 108.0 62.58 H Welded Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 75/8 6.875 29.1 2,661.7 2,317.3 29.70 L BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.950 27.5 8,162.0 5,448.4 15.50 L -80 LTC MOD `+. 5 5 "x3.5 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 25.8 7,412.8 5,025.5 9.30 L -80 EUE9rd Completion Details Top Depth (TVD) Top Intl Nomi... CONDUCTOR Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 35.106 25.8 25.8 -1.38 HANGER FMC GEN V TUBING HANGER 3.500 ' 517.2 517.2 0.23 NIPPLE CAMCO DS' NIPPLE 2.875 NIPPLE, 517 - - 7,286.7 4,952.3 54.45 SLEEVE -C BAKER CMU SLIDING SLEEVE (CLOSED 11/26/1998) 2.813 7,387.7 5,010.9 54.61 NIPPLE CAMCO 'D' NIPPLE 2.750 7,394.7 5,015.0 54.61 LOCATOR LOCATOR 2 7,396.2 5,015.9 54.60 SEAL ASSY BAKER 80-40 CASING SEAL ASSEMBLYw /15' STROKE 2.985 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment 7,690 7,708 5,186.5 5,196.9 S -5, 2N-325 6/20/1999 6.0 APERF 2.5" HC/DP, 60 Deg phasing 7,714 7,728 5,200.3 5,208.4 S -5, 2N -325 11/24/1998 6.0 IPERF 2.5" HC /DP, 60 Deg phasing 7,734 7,750 5,211.9 5,221.1 S -5, 2N -325 11/25/1998 6.0 IPERF 2.5" HC /DP, 60 Deg phasing SURFACE, 29.2,662 7,750 7,770 5,221.1 5,231.8 S -3, 2N -325 11/25/1998 6.0 IPERF 2.5" HC/DP, 60 Deg phasing 7,778 7,784 5,236.5 5,240.0 S -3, 2N -325 11/25/1998 6.0 IPERF 2.5" HC/DP, 60 Deg phasing SLEEVE 7,287 7,794 7,802 5,245.8 5,250.4 S - 3, 2N - 325 11/25/1998 6.0 IPERF 2.5" HC/DP, 60 Deg phasing I. 7,287 7,819 7,835 5,260.2 5,269.3 S -3, 2N -325 11/24/1998 6.0 IPERF 2 5" HC /DP, 60 Deg phasing N otes: General & Safety GAS LIFT, End Date Annotation 7.334 6/3/2009 NOTE: ZONES NOT LOADED TO WELLVIEW YET 6/22/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 2/15/2010 NOTE: WAIVERED WELL - OAxOOA COMMUNICATION, SURFACE CASING LEAK NIPPLE. 7,388 E LOCATOR, 7,395 SEAL ASSY, `1/ 7,396 '.,.\ APERF, 7,690-7,708 - i= IPERF, _ ' - 7,7147,728 _ IPERF, __ 7,7347,750 - - IPERF, 7.750 -7,770 PERF, - 7,779.7.784 Mandrel Details Top Depth Top Port IPERF, (TVD) Intl OD Valve Latch Size TRO Run 7794 -7802 - Stn Top (RKB) (MB) ("1 Make Model (in) Sery Type Type (in) (pal) Run Dote Com... 1 7,334.3 4,980.0 54.52 CAMCO KBG - 2 - 9 1 GAS LIFT DMY INT 0.000 0,0 9/1/1998 IPERF, 7,819.7,835 PRODUCTION 5 5 "e3.5', 2&8,182 A ■ TD, 8.182 . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission � TO: DATE: Monday, December 19, 2011 Jim Reg P.I. Supervisor Ne , q L i / z— SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2N -325 FROM: Matt Herrera KUPARUK RIV U TARN 2N -325 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry : Igo NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV U TARN 2N - 325 API Well Number: 50 103 - 20269 - 00 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH111219084952 Permit Number: 198 - 163 - Inspection Date: 12/17/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well biliType Inj. W - TVD 5016 , IA 740 3000 ' 2930 2900 P.T.D 1981630 " TypeTest SPT Test psi 3000 , OA 45 50 50 50 Interval REQVAR p/F P ' Tubing 2050 2050 2050 2050 Notes: MITIA performed to 3000 psi ✓L\t ('cue icy l'sv ) µ -`I-tiC Gut- ^C t p e�l t' L'.�; c . P R' SS Luc A 3o 1 (C ,ex) I a FEB C t ZU12 Monday, December 19, 2011 Page 1 of 1 • • 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 ~ ~i~~'` ~ To: Regg, James B (DOA) ~2 Subject: RE: State MITIA test results for 2N pad on 8/24/10 r,-~ Follow Up Flag: Follow up I'"~ I~~~~~~ Flag Status: Red K,~(,t ~-3z~; 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 1 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 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 -.~J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks~alaska.gov; tom maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhiliips Alaska Inc. ~ ,,~ ~ t ~ r/v FIELD /UNIT /PAD: Kuparuk /KRU / 2N ~ DATE: 08/24/10 OPERATOR REP: Ives/Mouser AES AOGCC REP: Packer De th Pretest Initial 15 Min. 30 Min. Well 2N-302 T e In'. W ND 5,185' Tubin 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2011150 T etest P Test si 1500 Casin 1,210 2,540 2,520 2,520 P/F P Notes: OA 235 265 260 260 Well 2N-306 T e In'. W ND 5,174' Tubin 2,150 2,150 2,150 2,150 Interval 4 P.T.D. 2040620 T etest P Test si 1500 Casin 1,245 2,820 2,760 2,760 P/F P Notes: OA 375 550 520 520 Well 2N-307 T e In'. W TVD 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 PIF P Notes: OA 250 350 300 300 Well 2N-309 T e In'. W ND 5,042' Tubin 1,600 1,600 1,600 1,600 Interval 4 P.T.D. 1990210 T etest P Test si 1500 Casin 775 2,225 2,100 2,080 P/F P Notes: OA 300 365 340 340 Well 2N-310 T e In'. W ND 5,004' Tubin 1,550 1,550 1,550 1,550 Interval 4 P.T.D. 2070900 T e test P Test si 1500 Casin 440 2,300 2,250 2,250 P/F P Notes: OA 270 390 350 350 Well 2N-314 T e In'. W ND 5,046' Tubin 1,600 1,600 1,600 1,600 Interval 4 P.T.D. 2001930 T e test P Test si 1500 Casin 600 2,300 2,270 2,270 P/F P Notes: OA 225 240 240 240 Well 2N-321A T e In'. W ND 4,915' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 1981730 T e test P Test si 1500 Casin 575 2,280 2,250 2,250 P/F P Notes: OA 250 450 450 450 Well 2N-326 T e In'. W ND 4,821' Tubin 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2001550 T e test P Test si 1500 Casin 1,150 2,760 2,720 2,710 PIF P Notes: OA 360 460 460 460 Well 2N-331 T e In'. W ND 4,770' Tubin 1,460 1,460 1,460 1,460 Interval 4 P.T.D. 1981170 T etest P Test si 1500 Casin 460 2,200 2,150 2,150 P/F P Notes: OA 300 480 480 480 Well 2N-335 T e In'. W TVD 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 ND 4,937' Tubin 3,350 3,350 3,350 3,350 Interval 4 P.T.D. 1980920 T e test P Test si 1500 Casin 850 2,780 2,630 2,620 P/F P Notes: OA 400 420 420 420 Well 2N-348 T e In'. W TVD 4,374' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 2011420 T e test P Test si 1500 Casin 630 2,280 2,240 2,240 P/F P Notes: OA 190 320 320 320 Well 2N-349A T e In'. G ND 5,078' Tubin 1,625 1,625 1,625 1,625 Interval 4 P.T.D. 2001390 T e test P Test si 1500 Casin 280 2,320 2,250 2,250 P/F P Notes: OA 150 250 250 250 Well 2N-325 T e In'. W ND 5015' ~ Tubin 1,975 1,975 1,975 1,975 Interval 4 P.T.D. 1981630 T etest 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 Fonn BFL 11/27/07 MIT KRU 2N Pad 08-24-10 Revisedl.xls • • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] I .~ Sent: Thursday, becember 24, 2009 3:16 PM ~ [ ~~` z~(c-~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (D A) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2N-325(PTD 198-163)Report of suspected SC leak Attachments: 2N-325 schematic.pdf ~ Tom, Jim, Guy ., Kuparuk injector 2N-325 (PTD 198-163) has a suspected subsidence induced surface casin leak at 120'. The TIO is 2690/600/0. The initial diagnostics have indications of a su ace ea around 120'. However due to an open OA shoe, there are some complications with the diagnostics. Further testing will be done to confirm the leak. It is ConocoPhillips intention to leave the well on injection for further diagnostics. A 10-403 will be submitted if an OA shoe is needed or the appropriate paperwork for continued injection will be submitted once a leak has been confirmed. Attached is a schematic and a 90 day TIO plot. ~ Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 12/28/2009 KRU 2N-325 PTD 198-163 12/24/2009 • u CO('iOCi3P~'14~I!}~S _ ~ ~Well Attributes -- j Wellbore aPuu'vvl Field Name Well Status ~~ ( 501032026900 TARN PARTICIPATING AREA (INJECTING comment H25 (ppm) Date Annotation End Da weu co r r -,:_i F~a SSSV: NIPPLE 0 1/1/2009 Last WO: ~ _ _ _ _ _ .. , ~ - __ Ann .~. ~_ Depth (ftK8) End DMe Annotation - - iLast ~; =.KB 7,962.6 6/21/2009 Rev Reason: TAG, 128'RATHOLE Casing Strings Casin -~- it Stan O Strin ID To ttKB Sel De th t Set De t 2N-325 & MD TD Imosbor I 6222009 ~~ ~' ~ - I I ~ ~' y.,...,,.~.p.., CONDUCTOR 9 . 16 .. g ... 15.062 PI 1 34.6 P (... 108.0 p ., ....°... 108.0 ,......a ...... 62.58 _.....e ... _. H-40 ....n ._r ... ._ Welded ~ ~ - Caaing Description String 0. .. String ID ... Top (ftK8) Set Depth (t... Set Depth (ND) ... String Wt... String ... St ring Top Thrd f RANGER Z6 -- SURFACE 75/8 6.875 29.1 2,661.7 2,317.3 29.70 L-80 BTC Casing Description String 0. ., String ID ... Top (ftK8) Set Depth (t... Set Depth (ND) ... String Wt... String ... St ring Top Thrd PRODUCTION 5 1/2 4.950 27.5 8,162.0 5,448.4 15.50 L-80 LTC MOD 5,5"x3.5" ITubin Strings es s1 1 . ubin9 at o .. 51x _. ToP K sI se1 r set D TVDl st t~ sc str ln ra ~ c i ~ ~T 312 2992 ~ ~ 1417B S 025 930 L 80 EUE3rd I . _._ Com letion Details _. . - . ~ Top Depth _ IND) ToP Incl F j ~ Top (ftK8) (ftK8) (°) Item Description Comment ID lint cor4DUCroR, 3s1oe i 25.8 25.8 -1.38 HANGER FMC GEN V TUBING HANGER I 517.2 517.2 0.23 NIPPLE CAMCO'DS' NIPPLE 7,286.7 4,952.3 54.45 SLEEVE-C BAKER CMU SLIDING SLEEVE ff 7,387.7 5,010.9 54.61 NIPPLE CAMCO'D'NIPPLE NIPPLE, 517 ,~ } t 1111 7,394.7 5,015.0 54.61 LOCATOR LOCATOR j 7,396.2 5,015.9 54.60 SEAL ASSY BAKER 80-40 CASING SEAL AE I ~ suRFACE. Perfora tions & Slots 29-2.662 it ----_. _-- Shot ~ Top (ND) etm (ND) Dens ;.. _.: Top (ftK8) Btm (ftK8) (ftK8) (ftK8) Zone Date (sh... SLEEVE-C F 7,690 7,708 5,186.5 5,196.9 S-5, 2N-325 6/20/1999 6.0 , 7,ze7 ' 1 I, 7,714 7,728 5,200.3 5,208.4 S-5, 2N-325 11/24/1998 6.0 -- 7,734 7,750 5,211.9 5,221.1 S-5, 2N-325 11/25/1998 6.0 7,750 7,770 5,221.1 5,231.8 S-3, 2N-325 11/25/1998 6.0 NIPPLE. 7.388 ~t .l LOCATOR, 7,395 \~ SEAL ASSV, ;.........,, 7,396 APERF, 7,690.7.708 IPERF, . 7,714-7.728 IPERF, 7,734-7,750 IPERF, 7,750-7,no IPERF. 7.778-7.784 IPERF, . 7 794-7,802 6/3/2009 NOTE: ZONES NOT LOADED TO WELLVIEW YET 6/222009 NOTE: VIEW SCHEMATIC w/Alaska Schemafic9.0 Mandrel Details _____., r ~- -~-- - Port ToP Depth Top (ND) Inel OD Valve Latch Size TRO Run Stn Top (ftK8) (RKB) (°) Make Motlel (inl Serv Type Type IiN (psi) Run Date Com... 1 7,334.3 4,980.0 54.52 CAMCO KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 9/1/1998 IPERF, 7.819-7,835 PRODUCTION 5.5"x3.5". 28-8.162 TD, 8.182 . . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, AlASKA 99510-0360 ReceIVED SEP 1 2 2007 . 'on Alaska Oil & Gas Cons. CommlSSI Anchorage September 07, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 5(;;.A.ì'4NED SEP 1 2 2007 a<3 - \\0"3 ~ \L'd-Ñ - ô 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 con-osion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of fonn 10-404, Report of Sundry Operations. The cOlTosion 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, C~~~ ~~d ConocoPhiIlips Well Integrity Field Supervisor . . ConocoPhillips Alaska Inc. Surface 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 Dumped cement date inhibitor sealant date ft bbls ft gal 2N-320 199-001 4" nla 4" nla 2 9/5/2007 2N-321 198-173 6" nla 6" nla 2 9/5/2007 2N-323 198-071 1" nla 1" nla 1 9/5/2007 2N-325 198-163 10" nla 10" nla 2 9/5/2007 2N-326 200-155 9" nla 9" nla 3.5 9/5/2007 2N-337 206-163 6" nla 6" nla 1 9/5/2007 2N-339 198-100 8" nla 8" nla 2.5 9/5/2007 2N-341 198-103 3" nla 3" nla 1 9/5/2007 2N-342 207-068 18" nla 18" nla 4.5 9/5/2007 2N-343 198-092 4" nla 4" nla 2 9/5/2007 2N-345 204-034 9" nla 9" nla 3.5 9/5/2007 Date 9/7/2007 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation CommissIOn TO: Jim Regg P.I. Supervisor -¡:) (," C¿I<.r.í S? ' j-....., . <-1 '..> { ¡" \ ~ DATE: Wednesday, August 09, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2N-325 KUPARUK RIV U TARN 2N-325 \ 1\£6 ~ \ ""3 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :JB{?- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U TARN 2N-325 API Well Number 50-103-20269-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060808 I 90244 Permit Number: 198-163-0 Inspection Date: 8/8/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 2N-325 IType Inj. i G : TVD ! i , I 5015 IA 500 I 1870 , 1850 1850 I I ~ , I : =T- i ; I --;------ P.T. ' 1981630 ¡TypeTest i SPT i Test psi I 1500 I OA I 250 350 350 350 , I _----L.- I , -----------+----- Interval 4YRTST PIF P ./ ,/ Tubing i 3200 3200 -: 3200 3200 I I '0. Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. SCANNED AUG 2 4 2006 Wednesday, August 09, 2006 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor ¢ DATE: August 3, 2002 Chair ..j. sUBJECT: Mechanical Integrity Tests Phillips Alaska THRU: Tom Maunder P.I. Supervisor 2N Pad FROM: John Crisp Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Well J "p'.T.b.i Notes: Packer Depth Pretest Initial 15 Min. 30 Min. 'Welli 2N-307 ITyPelnj. I GI T.v.o.I'5141 I-rubnngl315o1'31501 3150I3200 llnter~all 4 P.T.D.I 1990170 ITypetestI P ITestpsiI 1500 ICasingl 2275 I' 2900 I 2900 I 29'00 I 'P/F I P Notes: we,,J 2N-321A IType,nj.I s'1 T.V.D. 14915 ]T'ubing] 1700 11700 I' 17°° I 17°°']'nte~all"4 P,T.D.I 1981730 ITypetestl P ITestpsil 1500 I Casingl 100 I 2150 I 2150 I 2150 I pIE Notes: 2N-328 I TyPe..I.j.I. G I ~.V.O. I ~0~ IT.brai 2.65° I 2650 I ~"~°1 ~0 ],l,ntervalI ,4, 1981630 ITypetestl, P ITestpsi[ 1500 I Cas, ingl 1075I 1950I 1,940 I 1940,1 PIF I P, ".we,!l 2N-331 IType!nJ.I S IT'V'D' I 4770 i Zub,ngl 1675 '1 1,,75 I 18751 1675 I,nte~a~l 4 P.T.D.I 1981170 ITypetestl .P ITestpsiI 1500 I Casingl. 800 I 2(~25 I 2025 I 2025 I P/F I P~, Notes: .... we,,I2N-343IType'nj.I G IT'V'rD'I 4938 I Tubingl 2550I 2550i 2550 I'2550 Ilnte~all 4 P.T.,D.I 1980920 ITyp'etestI P ITestpsil 15°.°.,ICasingl.2°°° I 2925 I 2925 I 2925 I piF I B 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) Te~t's Details ] traveled to PAl's Kuparuk River Field to witness 4 year MIT's on 2N Pad. No failures witnessed. SCANNED AUG ! g 2002 M.I.T.'s performed: _5 Attachments: Number of Failures: O Total Time during tests: 4 hrs. cc.' MIT report form 5112/00 L.G. 020803-MIT KRU 2N JC.xls 8/5/2002 W ll Compliance Rep°rt File on Left side of folder 198-163-0 KUPARUK RIV U TARN 2N-325 50- 103-20269-00 PBILLIPS ALASKAINC Roll/41: Start: Stop Roll #2: Start Stop MD 08!.8__2 TVD 05459 Completion Date: 9/18/98 Completed Status: 1WINJ Current: WAGIN Name C 9353 c 9712 D 8806 L CBL/SCMT L CNTD Interval SCHLUM RST 1 CH 1 SCHLUM CNTD CH 2 SPERRY MPT/GR/EWR4/CNP/SLD OH FINAL 7212-7934 CH 2 FINAL 2600-7924 CH 5 Sent Received T/C/D ~ 10/21/99 10/27/99 9/6/00 9/8/00 12/23/98 12/23/98 12/21/98 1/5/98 9/6/00 9/8/00 L DGR/CNP/SLD-MD FINAL 2675-8182 L DGR/CNP/SLD-TVD FINAL 2325-5459 L DGR/EWR4-MD L DGR/EWR4-TVD L GR-TEM/PRES L INJP L INJP L INJP-PSP MI INJP L MI INJP-SPIN/TEM L RST WFL L RST-WTR FLOW TEM-SPIN/TEM/ R GYRO CONT.MULTI R SRVY CALC OH OH FINAL 2675-8182 OH FINAL 2325-5459 OH FINAL 50-7930 CH 5 FINAL 7590-7914 CH 2 FINAL 0-7924 CH 5 FINAL 7550-7932 7/9/99 CH 5 FINAL 7546-7820 6/25/99 CH 5 FINAL PRES 7650-7902 CH 2 FINAL 500-7918 9/24/99 CH 5 FINAL 7400-7928 8/29/99 CH 5 FINAL PRES 3000-7926 CH 5 GYRODATA TBNG 0-7298 CH BHI 108.-8182. OH Daily Well Ops . . - .... Was the well cored? yes ¢o~ . Comments: 12/30/98 12/30/98 12/30/98 12/30/98 12/30/98 12/30/98 12/30/98 12/30/98 4/20/00 4/28/00 12/21/98 1/5/99 4/27/00 5/12/00 8/11/99 8/19/99 7/27/99 8/13/99 2/17/00 2/25/00 10/6/99 10/13/99 9/17/99 9/22/99 9/17/99 9/22/99 1/14/99 1/14/99 12/30/98 12/30/98 Are Dry Ditch Samples Required? yes ,~ And Received? yes no Analysis Description Received? yes ~ Sample Set # Wednesday, November 08, 2000 Page 1 of 1 9/6/00 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 486 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD 2H-11 PRODUCTION PROFILE 000829 I 1 2X-11 PRODUCTION PROFILE 000828 I 1 30-19 ~l.t (._ INJECTION PROFILE 000827 I 1 3Q-21 ~ INJECTION PROFILE 000826 I 1 2N-325 L~lc--, ~O~/~V CNTD ~. C~I'~.--- 000328 I I I - RE SEP 05 .,000 SIGNE DATE: Alaska 0il & Gas [:07,~. uummissi0n' _. An~h0ra0e Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. ~nanK you." 4~27/O0 Schlumberger iq $ '/03 / 'gq. 3W.,~ Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 121413 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 2N-321A ~/~ INJECTION LOG 000412 I 1 2N-325 ~! E-- INJECTION LOG 000414 I 1 3F-01 PRODUCTION PROFILE 000415 I 1 3F-05 PRODUCTION PROFILE 000416 I 1 DI:F SIGNE DATE: Alaska 0il & Gas (;0~,~s· bummissi0rl Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 4~2O~OO Schlumberger NO. 121394 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 2N-321A L{.i 4_. GAMMA RAY BASELINE 000411 I 1 2N-325 ,-,L.~ GAMMA RAY BASELINE 000411 I I , , ,, APR g 8 2000 SIGNE DATE: Alaska 0il & Gas (;u~s. Uum~',iss~n Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of reques'Abandon Suspend __ Operation Shutdown. Alter casing __ Repair well __ Plugging __ Change approved program Pull tubing __ Variance __ Reenter suspended well __ Time extension __ Stimulate Perforate __ Other X 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development X. Exploratory~ Stratagrapic ~ Service ~ 4, Location of well at surface: 75' FNL, 821' FEL, Sec. 3, TgN, R7E, UM At top of productive interval: 1647' FSL, 139' FEL, Sec. 33, T10N, R7E, UM At effective depth: At total depth: 1841' FSL, 660' FEL, Sec. 33, T10N, R7E, UM 6. Datum of elavation (DF o~ KB) 28' KB Pad 121' feet 7. Unit or Property: Kuparuk River Unit 8. Well number: 2N-325 9. Permit number: 98-163 10. APl number: 50-103-20269 11. Field/Pooh Kuparuk River Field/Tarn Oil Pool 12, Present well condition summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Length Conductor 110' Surface 2662' Production 7397' Liner 765 8182 feet Plugs (measured) 5459 feet 8000 feet Junk (measured) 5361 feet Size Cemented Measured depth 16" 10 CY High Early 110' 7.625" 563 s× AS III LW, 2662' 240 sx Class G, 50 sx AS II 5.5" 245 sx Class G 7397' 3.5" included above 7397'-8162' ORIGINAL True vertical depth 108 2317 5016 5448 Perforation Depth measured 7714' - 7728', 7734' - 7770', 7778' - 7784', 7794' - 7802', 7819' - 7835' true vertical 5200' - 5208', 5212' - 5233', 5237' - 5240', 5246' - 5251', 5260' - 5269' Tubing (size, grade, and measured depth) 3-1/2" Wt. 9.30 Grade L-80 Thread EUE 8rd @ 7412' MD Packers and SSSV (type and measured depth) Packer, Baker CSA 80-40 @ 7395' MD RECEt', APR 12 2 Alaska Oil & Gas Cons. Anch0ra~e 13. Attachments Description summary of proposal_ Detailed operations program __ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: 4/8/2000 Run RA Tracer down Inner Annulus I Oil _ Gas __ I 16. If proposal was verbally approved Blair Wondzell 4/5/00I Name of approver Date approvec~ Service WAG 17, I hereby certify that the forgoing is true and correct to the best of my knowledge. Suspended__ Signed Title: Engineering Tech FOR COMMISSION USE ONLY Date 4/08/00 Conditions of approval: Notify Comission so representitive may witness Approval No.~.~)O Plug integrety __ BOP test __ Location clearance __ Mechanical integrety test __ Subsequent form required 10- ]'?~ ,~'~ ('~l.~j~,~lr:~--~ ORIGINAL SIGNED-BY Robert N. Chdstenson Approved by order of the Commission Commissioner Date CED )00 ~0mm~ Form 10-403 Rev 06/15/88 Approved Oopy SUBMIT IN TRIPLICATE Attachment 1 Kuparuk Well 2N-325 ARCO Alaska, Inc. is seeking AOGCC approval to inject RA material in the outer annulus of Tarn injectors 2N-325 and 2N-321A as part of an ongoing program to diagnose how injection fluids are being transported to producer 2N-345. AAI initiated Tarn MI injection during late 98. A water injection test was conducted during the summer of 99. At the time of the test, no Tam producer had experienced MI breakthrough. After approximately three weeks of water injection, water production was observed in 2N-345. Water tracer suggested that 2N-321A, and possibly 2N-325, were communicating with producer 2N-345.(See net pay map below for well locations.) Given that (1) no previous MI break through had been detected, (2) the quick water breakthrough time, and (3)the location of injector 2N- 32 lA relative to producer 2N-345, communication through the reservoir was difficult to explain. One possibility was that the transport path of injected fluids to 2N-345 involved channeling up the outside 2N-321A?s casing, through a shallow zone (where 2N-321A and 2N-325 wellbores are closer together), and down the outside of 2N-345?s casing to its open perforations. A variety of injection logs and production logs were subsequently run; however, they all failed to detect channeling. Furthermore, there were no elevated pressures in the annuli of any Tarn wells indicating communication with injected fluids. After completing the water injection test, MI injection at Tarn was resumed. Well tests on 2N- 345 were closely monitored for any sign of MI breakthrough. MI breakthrough in 2N-345 has recently been confirmed. Proposal The RA injection proposal is two-fold. First, we plan to inject RA material (i.e., Iodine 131, which has a half-life of 8.5 days) down the surface casing by production casing annulus of injectors 2N-321A and 2N-325. The purpose of this is to identify the "weak zone" that breaks down during annular pump-ins. (This will be the zone that cuttings are injected into during annular disposal operations.) This information will be used to help formulate drilling plans of future wells. We know that this "weak zone" is not transporting injected fluids To 2N-345. We can pump diesel into the "weak zone" at pressures that range between 700 psi and 1200 psi. After completing pumping operations, the outer annulus pressures bleed down. If the "weak zone" were transporting injection .fluids, it would be at an elevated pressure (-3000 psi). This elevated pressure is not consistent with the relatively low pressure outer annulus pump-ins and subsequent pressure bleed-offs. Second, we plan to inject solid RA tagged particles (i.e., Antimony and Scandium, which have half-lives in the 60 - 80 days range) into the outer annulus and then let gravity allow these particles to settle. The purpose of this is to identify the deepest point that is in hydraulic communication with the outer annulus. This information will also be used to help formulate drilling plans of future wells. RECEIVED APR 12 -000 Ala~ka Oil & Gas Cons. Commission Re: Tam RA Injection Subject: Re: Tarn RA Injection Date: Wed, 05 Apr 2000 15:11:01 -0800 From: Blair Wondzell <blair wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Lamont C Frazer <LFRAZER~mail.aai.arco.com> Lamont, Thanks for the data. As we discussed, I think this request should be by a 10-403. Contingent on your furnishing a 403 to this office by Monday, April 10, I am giving you verbal approval so that the work can start this weekend. Blair Wondzell, 4/5/00. Lamont C Frazer wrote: Blair, As per our phone discussion on 4/4/00, we are seeking AOGCC approval to inject RA material in the outer annulus of Tarn injectors 2N-325 and 2N-32iA as part of an ongoing program to diagnose how injection fluids are being transported to producer 2N-345. For your convenience, the original e-mail message on Ehis subject and a brief umdate of recent data collection acuivities are provided below. Data Collection Update Gas tracers indicate Ehat a small fraction of MI injection from wells 2N-325, 2N-331 and 2N-321A is transported to 2N-345 within a few days. The logging program outlined below has not provided any indication of ouu of zone injection, with one exception--the CNL run in injector 2N-321A indicated that the iceberg interval in the near-wellbore region of this injector has increased its gas~MI saturation since the well :vas drilled. At this point in time, it remains unclear as to how injection fluids are being transported to 2N-345. Schematics of injecuors 2N-321A & 2N-325 and fracture stimulated producer 2N-345 are also shown below. Logs suggest good cement bonding up to the crossover in 2N-325. (Cement bonding above the crossover is unknown.) Logs suggest ~hat 2N-321A and 27~I-345 boEh have some degradation in cement bonding prior to reaching their crossovers. Producer Logging * Production - DEFT (2~J-345) - Water Flow Log (2N-345) * Behind Pipe Flow Evaluation - CNL (2N-345) - Noise (2N-345) - Cement EvaluaEion Log (2N-345) > Injector Logging > * Water InjecEion > -Spinners (2N-307, 23,3-3£1A, 2N-325, 2N-331 & 2N-343) > - Temperature (lN-321A, 2N-325 & 2N-343) > - Borax P~..!L (2N-325 & 2N-343) > - Near-~/eilbore Iodine i31 RA Tracer (lN-321A, 2N-325 & 2N-343) > * Gas InjecEi~n z.~-321A, 2N-325, 2N-331 & 2N-343) > - Spinners (2N-307, > - CNL (2~t-321A, 2N-325 & 2N-331) > (Embedded image moved Uo file: pic17230.pcx) 1 of 3 4/5/00 3:11 PM Re: Tam RA Injection Proposal The RA injection proposal is E~,,o-fold. First, ~qe ulan to inject RA material (i.e., Iodine 131, which has a half-life of 8.5 days) down ihe surface casing by oroduction casing annulus of injectors 2N-32iA and £~i-325. i:~e purpose of this is uo identify u~e %,Teak zone" Ehat breaks down durin~ annuiar pump-ins. (This will be the zone that zuEtings are injected into during annu£ar disposal operations.) This information will be used to help formulate drilling plans of future ~ells. ~e kno~z uhat zhis "weak zone" is not uranspor~ing injected fluids to 2N-345. We can pumm diesel into the "weak zone" aE pressures Ehat range beuween 700 psi and 12~0 psi. After completing pumping oper~uions, the outer annulus pressures bleed down. If the '%~eak zone" ~,~ere transporting injection fluids, it would be au an elevaued pressure (~3000 psi). This elevated pressure is not consistenE with uhe relaEiveiy low pressure ouEer annulus pump-ins and subsequent pressure bleed-offs. Second, ~e plan to inject solid RA tagged particles (i.e., =~_~imonv and -7 q in the 60 - 80 days range) i_~_~o uhe outer Scandium, which have half __yes annulus and then let gravity allow these particles to settle. The purpose of Ehis is to identify the deepest point that is in hydraulic c~mmunication with the outer annulus. This information will also be used to held formulate - drilling plans of future wells. If you have any questions, or would like additional information on this subject, please contact either myself (263-4530) or Ryan Stramp (265-6~06). ~]e would welcome an opportunity ~o meet with you to discuss t~e matter in more detail. Sin cerely, Lamont Frazer AAI Tarn Reservoir Engineer Forwarded by Lamont C Frazer/A_~I/ARCO un 04/05/2000 09:08 Au'4 ..................... Lamont C Frazer 01/11/2000 04:14 PM To: Blair Wondzell~admin.sEaEe.ak. us -- cc: Ryan L StramD/~.~i/ARCO~ARCO Subject: Tarn Injection Blair, As per our phone discussion cn !/I0/00, this e-mai! message provides a brief description ouElining events relating to the production of injected fluids in Tarn producer 2N-345. The reason for alerting the AOGCC to ~his situation is that it - ?s possible that out of zone injection may be involved in t~_e transport of injected fluids to 2N-345. Background ~_~I initiated Tarn MI injection ,during late ?98. A water injection test was conducted during the summer of ?99. A~ the time of the test, ~_~o Tarn producer had experienced MI breakthrough. After approximately three :.;eeks of water injection, water production was observed in 2N-345. ?Zater ~racers suggested uhaE 2N-321A, and possibly 2N-325, .-were communicating with ~roducer 2N-345. (See net pay map below for well locations.) Given that (i) no previous MI breakthrough had been detected, (2) the quick water breakthruugh Eime, and (3) the location of injecEor 2N-32!A relative to producer 2N-345, communication Ehrough the reservoir ~as difficult ~o explain. One possibility was that the 2 of 3 4/5/00 3:12 PM Re: Tam RA Injection transporu path of injected fluids to 2N-345 involved channeling up the outside 2N-321A?s casing, ~hrough a shallow zone (where 2N-321A and 2N-325 weiibores are closer together), and down the outside of 2N-345?s casing to its open uerforations. A variety of injection logs and production logs were subsequently run; however, they ali failed to de~ecE channeling. Furthermore, there were no elevaEed uressures in ~he annuli of any Tarn wells indicaEing communication with injected =~uids. After comp!eEing the ~,qater injection .~esE, MI injection at Tarn was resumed. Nell tesEs on 2N-345 ~zere closely monitored for any sign of MI break~hrough. MI breakthrough in 2N-345 has recently been confirmed. Ongoing Diagnosis A comprehensive plan has been developed to help understand the transport path of injected fluids to 2N-345. Ongoing activities include (1) additional logging, (2) use of gas tracers and (3) attempting uo inject into the outer annuli of Tarn ~]el?-~ ~ determine ;,~hether they remain open to shallow horizons. If you have any questions, or would like additional information on this subject, please conuact either myself (263-4530) or Ryan Stramp (265-6806). ~qe would welcome an ~mportuni~y to meet with you Eo discuss the matter in more detail. Sincerely, Lamont Frazer AAI Tarn Reservoir Engineer (Embedded image moved to file: picOO589.~cx) > Name: pic!7230.pcx > pic1723S.mcx Type: PCX Image Document (appl i ca tion/'x - unknown -con ten t - type -PCXImage. Documen t) > Encoding: base64 > > Name: picOO589.pcx > picOO5~9.pcx Type: PCX Image Documenz ( app l i ca E i o n / x -unknown -con E en t - t ype- PCXIma ge . Documen t) > Encoding: base64 3 of 3 4/5/00 3:12 PM 2Nw321A Tabasco 2350':2'380' 2N-325 2N-345 2/17/00 Schlumberger NO. 121203 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 2L-323 Ut 4._ MEM INJECTION PROFILE 000204 I 1 2N-307 [ MI INJECTION PROFILE 000203 1 1 2N-321AL MEM INJECTION PROFILE 000205 I 1 2N-325 MI INJECTION PROFILE 000206 I 1 31-06 L~t ~ INJECTION PROFILE 000207 I 1 3J-17 PRODUCTION PROFILE 000208 I 1 3M-07 LLI C_ INJECTION PROFILE 000207 I I ', ~ .... . I~EL ' , FEB 25 ~000 SIGN DATE: ~iaska 0ii & G~,.~ Please sign and return dne copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. ~nanK you. 10/21/99 j~q. Schhlmberger NO. 12878 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: Tarn Pool Color Well Job # Log Description Date BL Sepia Print CD 1E-36 DEPTH CONTROL MEMORY GR/CCL 991010 I 1 2C-10 PRODUCTION PROFILE W/PSP 991010 I 1 2G-11 PRODUCTION PROFILE W/PSP 991012 I 1 2N-325 c.~, c_. 99354 RST ~ q ','~'~ '~ 990829 I I 1 1999 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Th~l~ Schlmberger NO. 12843 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 CD 2L-307 FBHP/TEMP SURVEY 990919 I 1 2N-321A ~1 ~-- RSTWATER FLOW LOG 990925 I 1 2N-325 t~,.i c._ RST WATER FLOW LOG 990924 I 1 2N-343 O- I ~ EST WATER FLOW LOG 990923 I 1 3G-26 -~L{ I 99346 AIT/GPIT 990816 1 3G-26 99346 AIT/GR/CCL 990816 I 1 3G-26 99346 CONTINUOUS SURVEY W/GPIT 990816 I I , , ........ RECEIVE , ,.J 10/6/99 SIGNED: DATE: f:l'l'T !3 1999 ~ Oil & Gas C, ons. ¢omlnisaon Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Schlumberger NO. 12800 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 lC-26 .... ~ 9'339 III ~CMT ...... ~e0e~0 .......... 1 2A'02 ~ ~ ' 'l INJECTI.ON P R O FI LE 'il ' ' I 990e22 I Il 1 Ill '' ' I i fill l[[ 2A-09 LEAK DETECTION LOG 990826 1 1 2A-10 PEODUCTION PROFILE 990830 1 1 2L-315 TEMPERATURE SURVEY 990910 I 1 ~i~1-01 ..... PRODUCTION PROFILE 9901~30 ' '1 i .... 2N-325 l.~i C.. RST WATER FLOW LOG 990829 1 1 2N~32~ ~.~ :' WA'EM BA~'K TEMP LOG ' . 990908 ..... i ...... 1 ....... ......................... 2~343 ~ ~ .: .... RSTWATER FLOW LOG 9908.27 1 .... 1 ...i .... 2N-343 ~ WARM BACK TEMP LOG 990909 I 1 2v-oeA ~ ~ ,, ' ' , .' ' ' ~NJ~CTION PROFILE " ..' ....990821 1., I '~ ........ ['-' ,., 3G-17 , ,, ~hODUCTION PROFILE eg0S2S I I ,,,: ........................ 3M-02 ~..~. INJE~TIONPROFILE' 99~825 .. I .. 1 3U. ylO . .~ ~ INJECTION P~OFILE 990906 I 1 ........... ] .... i .............. ....... ............................ , ................. .................... J .......... ......... ................... i ~ "~l~ ~ ~ .............. SlGNE Please sign and return one cody of this transmittal to Sherrie at the above address or fax to (907) 561-8317. 9/17/99 8/11/99 ,gq. o~ ~ ~q 'z. Schlumberger NO. 12742 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: Tarn Pool Kuparuk,Tabasco Pool Color Well Job if Log Description Date BL Sepia Print 1A-10 J,A.I (.--- INJECTION PROFILE 990719 I 1 1A-11 ~ I t.~ INJECTION PROFILE 990707 I 1 1Y-10 ~,[I (L. MI INJECTION PROFILE 990716 I 1 2A-03 Ll.t ~ INJECTION PROFILE WlPSP 990708 I 1 2M-20 PRODUCTION PROFILE 990702 I 1 2M-30 tX! ~ INJECTION PROFILE W/PSP 990722 I 1 2N-321A [Z.! q.~ INJECTION & STATIC PROF W/PSP 990710 I 1 2N-325 ~ i ~ INJECTION & STATIC PROF W/PSP 990709 I 1 2N-335 PRODUCTION PROFILE 990705 I 1 2T-28 tJ,.I (..- MEMORY INJECTION PROFILE 990715 I 1 2T-202 PRODUCTION PROFILE 990706 I 1 2T-210 STATIC BOTTOM HOLE PRESS SURVEY 990721 I 1 2X-10 PROD PROFILE & GAS LIFT SURVEY 990708 I 1 3H-12 tv~l ~_~ INJECTION PROFILE 990706 I 1 3J-04 L~I C-- INJECTION PROFILE W/PSP 990724 I 1 3J-05 ~,~.1 ~ INJECTION PROFILE W/PSP 990725 I 1 3M-04 STATIC BOTTOM HOLE PRESS LOG 990701 I 1 3M-29 STATIC Bo'FrOM HOLE PRESS LOG 990701 I I ..... SIGNED: DATE: 1,11~. 'i ~.)'t999 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. 7~27/99 Schlumberger NO. 12706 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 2N-307 U~LE-. MI INJECTION PROFILE 990624 I 1 2N-325 l,X,t C.. MI INJECTION PROFILE 990625 I 1 2N-335 PRESS/TEMP/GRAD/JEWELRY 990622 I 1 2N-335 SBHP & SPINNER SURVEY 990624 I 1 2T-28 L.~I, c__ MI INJECTION PROFILE 990626 I 1 2T-209 PROD PROFILE ON CTU 990617 I I SIGN DATE: '~'~: [''j(:~ 'j ~5 't??() ,~ ~ ' '~ '" '" '"'" ...... '"¢"[ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Than~B'!~g~ 12/21/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'rN: Sherrie NO. 12181 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia 1 D- 110 CBL-SCMT 981020 1 1 2L-329A CBL-SCMT 981122 1 1 2L-329A PRODUCTION LOG 981205 1 1 2L-329A PRODUCTION LOG 981207 1 1 2N-321A CBL-SCMT 981109 1 1 2N-325 CBL-SCMT 981108 1 1 2N-325 MI INJECTION PROFILE 981205 1 1 2N-331 CBL-SCMT 981123 1 1 1 E-35 CEMENT MAPPING LOG 981203 1 1 1 E-35 PRODUCTION LOG 981208 1 1 1 E-36 STATIC PRESS/TEMP 981123 1 1 1G-16 .1~.~ I~11 INJECTION PROFILE 981202 1 1 1Q-07 STATIC PRESS/TEMP 981119 1 1 1 Y- 15A CBL-SCMT 981109 1 1 2M-34 I~C_. MI INJECTION PROFILE 981110 1 1 2W- 12 PRODUCTION PROFILE 981028 1 1 3F-04 I, At C-- MI INJECTION PROFILE 981203 1 1 3F-12 b~C~ MI INJECTION PROFILE 981204 1 1 3F-19 RST WFL & GLS 981103 1 1 3G-03 PROD PROFILE W/DEFT 981104 1 1 3K-25 ~1,,( ( ~, INJECTION PROFILE 981014 1 1 3K-26 ~ ----~----___ INJECTION PROFILE 981014 1 1 SIGNEI~c~;, ~/~.~/~ ~,Z~/.~. ~ //~/~ DATE: Please sign and ~~.~e co-py~f this transmiltal to Sherrie at the above address. Thank you. 0 I::t I I--I-- I I~1G SG I::t~ I ~-- E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 q December 30, 1998 RE: MWD Formation Evaluation Logs 2N-325, AK-MM-80377 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2N-325: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20269-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20269-00 2" x 5" MD Neutron & Density Logs: 50-103-20269-00 2" x 5" TVD Neutron & Density Logs: 50-103-20269-00 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ARCO Alaska, Inc. ' ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 30, 1998 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-325 (Permit No. 98-163) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2N-325. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Tarn Drilling Team Leader AAI Drilling PM/skad . STATE OF ALASKA .- ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-163 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20269 4 Location of well at surface 9 Unit or Lease Name 75' FNL, 821' FEL, Sec. 3, T9N, R7E, UM~/'~/' '-q2 '~~ i. ~ ~:=t~T_~[¢~ Kuparuk River Unit At Top Producing Interval .... _ "- i ' ~ Ii 10 Well Number 1647' FSL, 139' FEL, Sec. 33, T10N, R7E, UM '.-'~' ' ~'~ i': ~ 2N-325 At Total Depth :~ .. .-... .i ~':: _~... ,..1:. _~__.:~ ,~' ~"~"~ ~ 11 Field and Pool 1841' FSL, 660' FEL, Sec. 33, T10N, R7E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) [ 6 Lease Designation and Sedal No. Tarn Oil Pool RKB 28', Pad 121'I ADL 380054 ALK 4602 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 12-Sep-98 17-Sep-98 18-Sep-98 NA feet MSL 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 8182' MD & 5459' TVD 8000' MD & 5361' TVD YES M NO U N/A feet MD 1050 APPROX 22 Type Electric or Other Logs Run GR/Res, GP,/CCL, CBL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF. 110' 24" 10 CY High Early 7.625" 29.7# L-80 SURF. 2662' 9.875" 563 sx AS 111 LW, 240 sx Class G, 50 sx AS II 5.5" x 15.5# L-80 SURF. 7397' 6.75" 245 sx Class G 3.5" 9.3# L-80 7397' 8162' 6.75" (included above) 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 7413' 7397' (CSR) 7714'-7728' MD 5200'-5208' TVD 7734'-7770' MD 5212'-5233' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 7776'-7784' MD 5237'-5240' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7794'-7802' MD 5246'-5251' TVD N/A 7819'-7835' MD 5260'-5269' TVD ~. 6 spf 27 PRODUCTION TEST' ' ^ L Date First Production Method ofOperation (Flowing,lnjectorgaS lift, etc.) U 15 I k7 I I NI I Date of Test Hours Tested PRODUCTION FOFtOIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOB Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE: 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A ~i¥~issior~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T-3 7510' 5082' T-2 7840' 5272' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. " ' t_.// Prepared by Name/Number Sharon AIIsup-D~"~e/2--'~7'-4'~'2 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pedinent 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 cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 12/4/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-325 WELL ID: AK9485 TYPE: AFC: AK9485 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:09/12/98 START COMP: RIG:RIG % 141 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20269-00 09/12/98 (D1) TD: 474'( 474) SUPV:M.C. HEIM 09/13/98 (D2) TD: 2675' (2201) SUPV:M.C. HEIM 09/14/98 (D3) TD: 2675'( 0) SUPV:M.C. HEIM 09/15/98 (D4) TD: 4331' (1656) SUPV:D.P.BURLEY 09/16/98 (D5) TD: 6525' (2194) SUPV:D.P.BURLEY 09/17/98 (D6) TD: 8182' (1657) SUPV:D.P.BURLEY 09/18/98 (D7) TD: 8182' ( 0) SUPV:D.P.BURLEY MW: 9.8 riSC: 87 PV/YP: 25/35 APIWL: 8.6 DRLG. & SURVEYS @ 1100' (22 HRS. RIG POWER) (ATTEMPT HI- Move rig from 2N-331 to 2N-325. NU diverter and function test. Accept rig @ 1200 hrs. 9/12/98. Drilling from 108' to 474' MW: 10.0 VISC: 74 PV/YP: 31/29 APIWL: 5.6 RUNNING 7 5/8" CSG. (RIG ON HILINE POWER 9 HRS.-RIG POWER Drilling and surveys from 474' to 2675' MW: 9.1 VISC: 56 PV/YP: 19/18 APIWL: 9.0 TEST 7 5/8" CSG. @ 2461' (24 HRS. HI-LINE POWER) Run 7-5/8" casing. Cement first and second stage. MW: 9.1 VISC: 44 PV/YP: 14/14 DRILLING AHEAD FROM 5085' APIWL: 7.0 Drill out stage collar and wash down to 1470' Clean out cement and float equipment, drill 20' of new hole to 2695' Perform FIT, 16.0 ppg EMW. Drill 6.75" hole from 2695' to 4331' MW: 9.1 VISC: 41 PV/YP: 12/10 DRILLING AHEAD FROM 7240' APIWL: 7.4 Drill 6.75" hole from 4331' to 5710' Perform LOT, EMW=ll.3 ppg. Drill from 5710' to 6525' MW: 9.8 VISC: 50 PV/YP: 23/20 LAYING DOWN DRILL PIPE. APIWL: 4.5 Drill from 6526' to 8182' MW: 9.8 VISC: 44 PV/YP: 14/13 RUNNING 3-1/2" COMPLETION. APIWL: 4.6 Run 5.5" x 3.5" casing. 09/19/98 (D8) TD: 8182' ( 0) SUPV:D.P.BURLEY MW: 8.5 VISC: RELEASED RIG @ 2000 HRS. 0 PV/YP: 0/ 0 APIWL: 0.0 Cemented 5.5" x 3.5" casing. Run 3.5" completion. Freeze protect tubing. ND BOPE, install master valve. Released rig @ 2000 hrs. 9/19/98. ARCO Alaska, Inc. KUPARUK RIVER UNIT ~j, WELL SERVICE REPORT ,~' K1(2N-325(W4-6)) WELL JOB SCOPE JOB NUMBER " 2N-325 PERFORATE, PERF SUPPORT 1022981945.3 DATE DAILY WORK UNIT NUMBER 11/25/98 PERFORATE DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 6 YESI YES SWS-YON GOBER FIELD AFC# CC# Signed ESTIMATE K85113 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 200 PSI 200 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY P WrlME ~6:00 7:00 iP~09:30 711:00 7t2:30 LOG ENTRY RU BOP AND LUBRICATOR - PRESSURE TEST TO 3500 PSI RIH W/8' 2.5" HC/6 SPF/DP/60 DEG PHASING/SAFE SYSTEM - TIE IN W/GR/CCL RUN 11/24/98 AND PERF 7794'- 7802' - POOH - ALL SHOTS FIRED RIH W/6' GUN SAME AS ABOVE - TIE IN W/GR/CCL AND PERF 7778'-7784' - POOH - ALL SHOTS FIRED RIH W/20' GUN SAME AS ABOVE - TIE IN W/GR/CCL AND PERF 7750'-7770' - POOH - ALL SHOTS FIRED RIH W/16' GUN SAME AS ABOVE - TIE IN W/GR/CCL AND PERF 7734'-7750' - POOH - ALL SHOTS FIRED A14:00 RDMO SWS 7' A R IF ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-325(W4-6)) WELL JOB SCOPE JOB NUMBER " 2N-325 PERFORATE, PERF SUPPORT 1022981945.3 DATE DAILY WORK UNIT NUMBER 11/24/98 PERFORATE DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 5 NOI YES ROJAS KRALICK FIELD AFC# CC# Signed ESTIMATE K85113 180KN U2TN InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann IlnitialOuterAnn I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSIII0 PSI 0 PSI DAILY SUMMARY PERFORATE W/2.5" HC/DP/6 SPF/60 DEGREE PHASED FROM 7714' - 7728', 7819' - 7835'[Perf] TIME LOG ENTRY 11:00 MIRU SWS 12:00 P/T BOP & LUB TO 3500 PSI 13:00 RIH W/2.5" HC - 16'/6 SPF/DP/60 DEGREE PHASED/GUN GAMMA/SAFE SYSTEM/5' ROLLER STEM 15:00 TIE IN W/GAMMA - 9.5' FROM CCL TO TOP SHOT - ATTEMPT SHOT - MISFIRE AND POOH 16:30 RIH W/14' GUN SAME AS ABOVE 17:30 TIE IN AND SHOOT FROM 7714'- 7728' W/200 PSI OVERBALANCED - ALL SHOTS FIRED 18:30 RIH W/SAME GUNS 16' - TIE IN AND SHOOT FROM 7819' - 7835' W/200 PSI OVERBALANCED - ALL SHOTS FIRED 20:00 RDFN SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00350 Sidetrack No.__ Page 1 o£ 4 Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILLSITE 2N/325 Survey Section Name SPERRY SUN BHI Rep.KIRT CHRISTENSEN WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -74.28 Grid Correction 0.000 Depths Measured From:RKl~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/W -821.40 Magn. Declination 26.830 Calculation Method MINIMUM CURVATUr Target Direction (DD) Build\Walk\DL p~l~00ft[~ 30m[-] 10m~ Vert. Sec. Azim. 290.21 Magn. to Map Corr. 26.830 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction L}~i[~ TVD Section N(-~T/~S(-) E(+0F/T~W(- DL Build (+) Right (+) Comment Type (FT) (DD) (DD), ~ (FT),--~ ,--~ (Per 100 F2E}rop (-) Left (-) MWD 108.00 0.00 0.00 108.00 0.00 0.00 0.00 TIE IN POINT -- 12-SEP-9~ MWD 166.30 0.98 236.52 58.30 166.30 0.30 -0.28 -0.42 1.68 1.68 8" M1C SET @ 1.4 AKO 12-SEP-9~ MWD 249.53 0.80 242.63 83.23 249.52 1.11 -0.93 -1.53 0.24 -0.22 12-SEP-98 MWD 343.74 0.92 236.71 94.21 343.72 2.00 -1.65 -2.74 0.16 0.13 12-SEP-98 MWD 426.35 0.74 237.48 82.61 426.32 2.72 -2.30 -3.75 0.22 -0.22 13-SEP-98 MWD 517.42 0.23 4.17 91.07 517.39 3.13 -2.44 -4.23 0.98 -0.56 31' SLIDE 180 TF 13-SEP-98 MWD 608.26 0.59 23.55 90.84 608.22 3.15 -1.83 -4.03 0~42 0.40 13-SEP-98 MWD 705.36 1.90 327.05 97.10 705.30 4.41 -0.02 -4.70 1.70 1.35 60'" 13-SEP-98 MWD 794.67 3.70 3'15.26 89.31 794.50 8.20 3.27 -7.54 2.11 2.02 45'" 13-SEP-98 MWD 886.18 5.83 308.50 91.51 885.69 15.29 8.26 -13.25 2.40 2.33 -7.39 45'" 13-SEP-98 MWD 976.99 8.06 305.48 90.81 975.83 25.82 14.83 -22.05 2.49 2.46 -3.33 64'" 13-SEP-98 MWD 1067.64 11.22 307.15 90.65 1065.19 40.39 23.85 -34.26 3.50 3.49 1.84 75'" 13-SEP-98 MWD 1156.85 15.35 307.73 89.21 1151.99 59.96 36.32 -50.52 4.63 4.63 0.65 45' " 13-SEP-9 MWD 1250.44 17.79 309.33 93.59 1241.69 85.28 52.96 -71.38 2.65 2.61 1.71 30 13-SEP-9~ MWD 1345.60 20.42 309.87 95.16 1331.60 114.66 72.82 -95.37 2.77 2.76 0.57 30'" 13-SEP-9~ MWD 1439.43 22.37 309.78 93.83 1418.96 146.90 94.74 -121.66 2.08 2.08 -0.10 20'" 13-SEP-9[ MWD 1533.44 24.39 306.69 94.01 1505.25 182.37 117.79 -150.97 2.51 2.15 -3.29 45'" 13-SEP-9~ MWD 1628.68 26.76 301.56 95.24 1591.16 222.26 140.77 -185.02 3.40 2.49 -5.39 45'" 13~SEP-9~ MWD 1724.40 29.32 298.17 95.72 1675.64 266.61 163.11 -224.05 3.15 2.67 -3.54 51' " 13-SEP-9~ MWD~ 1819.47 31.75 292.53 95.07 1757.54 314.67 183.70 -267.69 3.95 2.56 -5.93 75' " 13-SEP-91~ MWDi 1917.10 37.03 288.22 97.63 1838.09 369.77 202.75 -319.39 5.95 5.41 -4.41 45' " I'3-SEP-9~ MWD 2009.45 40.09 288.67 92.35 1910.30 427.30 220.96 -373.99 3.33 3.31 0.49 45' " 13-SEP-9~ MWDI 2102.41 43.38 289.26 92.96 1979.66 489.15 241.08 -432.50 3.56 3.54 0.63 62' " 13-SEP-9~ MWD 2195~11 48.31 290.57 92.70 2044.21 555.64 263.76 -495.00 5.41 5.32 1.41 62' " r -,, SURVEY CALCULATION AND FIELD WORKSHEET ~ Job No. 0450-00350 Sidetrack No.~ Page 2 of 4 Company ARCO ALASKA, INC. Rig Contractor & No.DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILLSITE 2N/325 Survey Section Name SPERRY SUN BHI Rep.KIRT CHRISTENSEN WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -74.28 Grid Correction 0.000 Depths Measured From:RKB~ MSL~ SS[-] Target Description Target Coord. E/W Slot Coord. E/W -821.40 Magn. Declination 26.830 Calculation Method MINIMUM CURVATU! Target Direction (DD) Build\Walk\DL pelfl0ft[~ 30m[-] 10m~ Vert. Sec. Azim. 290.21 Magn. to Map Corr. 26.830 Map North to:OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction L}~gl[~l TVD Section N(+)/ S(-) E(+0F/T~,V(- DL Build (+) Right (+) Comment Type (FT) (DD) (DD). . (FT) (FT)v--- (Per 100 F'll~rop (-) Left (-) 13-SEP-98 MWD 2288.44 53.01 292.05 93.33 2103.36 627.78 290.01 -562.21 5.18 5.04 1.59 45'" -- 13-SEP-98 MWD 2385.72 55.36 290.29 97.28 2160.29 706.65 318.48 -635.77 2.83 2.42 -1.81 20'" 13-SEP-98 MWD 2481.58 55.46 289.75 95.86 2214.71 785.56 345.49 -709.91 0.48 0.10 -0.56 13-SEP-98 MWD 2575.16 55.31 289.95 93.58 2267.86 862.57 371.65 -782.35 0.24 -0.16 0.21 13-SEP-9~ MWD 2597.97 55.21 290.24 22.81 2280.86 881.32 378.09 -799.96 1.13 -0.44 1.27 15-SEP-9~ MWD 2685.97 55.03 288.50 88.00 2331.19 953.50 402.03 -868.06 1.63 -0.20 -1.98 4 3/4" M1XL SET @ 1.2 AKO 15-SEP-9~ MWD 2780.85 55.20 289.40 94.88 2385.45 1031.31 427.30 -941.67 0.80 0.18 0.95 15-SEP-98 MWD 2873.93 55.18 289.29 93.08 2438.59 1107.72 452.62 -1013.77 0.10 -0.02 -0.12 15-SEP-98 MWD 2969.00 55.15 289.73 95.07 2492.90 1185.75 478.68 -1087.33 0.38 -0.03 0.46 15-SEP-9~ MWD 3063.08 55.11 290.16 94.08 2546.68 1262.94 505.01 -1159.88 0.38 -0.04 0.46 15-SEP-9~ MWD 3159.35 54.75 290.24 96.27 2602.00 1341.73 532.22 -1233.83 0.38 -0.37 0.08 15-SEP-9~ MWD 3251.24 53.79 289.98 91.89 2655.66 1416.32 557.86 -1303.88 1.07 -1.04 -0.28 15-SEP-9~ MWD 3346.93 53.68 290.81 95.69 2712.26 1493.47 584.75 -1376.19 0.71 -0.11 0.87 -- 15-SEP-9~ MWD 3441.04 54.62 290.59 94.11 2767.38 1569.75 611.71 -1447.55 1.02 1.00 -0.23 31' SLIDE 20L TF 15-SEP-9~ MWD 3535.61 56.41 289.15 94.57 2820.92 1647.69 638.20 -1520.86 2.27 1.89 -1.52 15 ..... 15-SEP-9~ MWD 3628.89 56.18 289.75 93.28 2872.68 1725.29 664.03 -1594.03 0.59 -0.25 0.64 15-SEP-9[ MWD 3722.46 55.73 289.77 93.57 2925.07 1802.82 690.25 -1666.99 0.48 -0.48 0.02 15-SEP-98 MWD 3815.36 55.30 289.57 92.90 2977.67 1879.39 716.02 -1739.10 0.50 -0.46 -0.22 / 15-SEP-9~ MWD 3905.80 54.68 288.30 90.44 3029.56 1953.44 740.06 21809.16 1.34 -0.69 -1.40 15-SEP-9[ MWD 4001.01 56.39 289.18 95.21 3083.44 2031.91 765.28 -1883.49 1.95 1.80 0.92 31' SLIDE 10R TF 15-SEP298 MWD 4097.07 57.34 291.51 96.06 3135.95 2112.34 793.26 -1958.90 2.26 0.99 2.43 15-SEP-9~ MWD 4190.91 57.11 291.61 93284 3186.75 2191.22 822.25 -2032.28 0.26 -0.25 0.11 16-SEP-98 MWD 4284.79 56.75 292.09 93.88 3237.97 2269.86 851.53 -2105.30 0.58 -0.38 0.51 .... 16-SEP~9~ MWD 4379.65 56.75 292.87 94.86 3289.99 2349.12 881.86 -2178.61 0.69 0.00 0.82 ~ Sidetrack No. . Page 3 of 4 Company ARCO ALASKA, INC. Rig Contractor & No.DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILLSITE 2N/325 Survey Section Name SPERRY SUN BHI Rep.KIRT CHRISTENSEN WELL DATA -- Target TVD (FT) Target Coord. N/S Slot Coord. N/S -74.28 Grid Correction 0.000 Depths Measured From:RKB~ MSL[~ SS[~ Target Description Target Coord. E/W Slot Coord. E/W -821.40 Magn. Declination 26.830 Calculation Method MINIMUM CURVATU[ Target Direction (DD) Build\Walk\DL pe~00ft[~ 30m~ 10m[-] Vert. Sec. Azim. 290.21 Magn. to Map Corr. 26.830 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction L}~gl~~ TVD Section N(+)/ S(-) E(+0F/T~W(-' DL Build (+) Right (+) Comment Type (FT) (DD) (DD)- , (FT) (FT),____ (Per 100~ F21~rop (-) Left (-) 16-SEP-98 MWD 4473.10 56.57 292.88 93.45 3341.35 2427.11 912.21 -2250.54 0.19 -0.19 0.01 -- 16-SEP-98 MWD 4569.05 56.47 291.25 95.95 3394.28 2507.09 942.27 -2324.70 1.42 -0.10 -1.70 16-SEP-98 MWD 4662.17 56.67 292.37 93.12 3445.58 2584.77 971.14 -2396.85 1.03 0.21 1.20 16-SEP-98 MWD 4756.83 56.50 291.94 94.66 3497.71 2663.74 1000.94 -2470.03 0.42 -0.18 -0.45 16-SEP-98 MWD 4851.79 56.22 292.61 94.96 3550.32 2742.75 1030.91 -2543.19 0.66 -0.29 0.71 16-SEP-98 MWD 4943.00 55.64 290.81 91.21 3601.42 2818.27 1058.86 -2613.37 1.75 -0.64 -1.97 31' SLIDE 125L TF 16-SEP-98 MWD 5037.27 54.24 288.73 94.27 3655.57 2895.42 1084.97 -2685.98 2.34 -1.49 -2.21 16-SEP-9~ MWD 5130.52 54.15 289.60 93.25 3710.12 2971.04 1109.79 -2757.41 0.76 -0.10 0.93 16-SEP-9~ MWD 5223.75 54.03 290.60 93.23 3764.81 3046.55 1135.74 -2828.32 0.88 -0.13 1.07 16-SEP-9~ MWD 5318.15 53.86 290.16 94.40 3820.37 3122.86 1162.32 -2899.86 0.42 -0.18 -0.47 16-SEP-9~ MWD 5412.78 53.47 290.92 94.63 3876.44 3199.09 1189.06 -2971.25 0.77 -0.41 0.80 16-SEP-9~ MWD 5507.91 54.42 286.86 95.13 3932.44 3275.95 1213.94 -3043.99 3.59 1.00 -4.27 31' SLIDE 75L TF 16-SEP-9~ MWD 5601.87 53.95 286.41 93.96 3987.42 3351.99 1235.75 -3116.99 0.63 -0.50 -0.48 -- 16-SEP-9~ MWD 5693.79 53.63 287.81 91.92 4041.73 3426.05 1257.57 -3187.88 1.28 -0.35 1.52 16-SEP-9~ MWD 5788.68 53.69 288.38 94.89 4097.96 3502.43 1281.31 -3260.53 0.49 0.06 0.60 16-SEP-9~ MWD 5884.83 53.51 287.60 96.15 4155.01 3579.76 1305.21 -3334.14 0.68 -0.19 -0.81 16-SEP-9~ MWD 5979.69 53.01 286.92 94.86 4211.76 3655.68 1327.77 -3406.73 0.78 -0.53 -0.72 16-SEP-9~ MWD 6073.86 54.62 287.47 94.17 4267.35 3731.58 1350.24 -3479.33 1.77 1.71 0.58 31' SLIDE 20R TF 16-SEP-9~ MWD 6167.70 55.48 289.07 93.84 4321.11 3808.44 1374.36 -3552.37 1.67 0.92 1.71 16-SEP-9~ MWD 6261.61 55.47 286.79 93.91 4374.34 3885.74 1398.17 -3625.97 2.00 -0.01 -2.43 16-SEP-9~ MWD 6353.26 55.30 288.00 91'.65 4426.41 3961.08 1420.72 -3697.95 1.10 -0.19 1.32 16-SEP-9~ MWD 6449.42 55.94 '288.38 96.16 4480.71 4040.39 1445.49 -3773.34 0.74 0.67 0.40 17-SEP-9~ MWD 6543.61 55.69 287.88 94.19 4533.63 4118.25 1469.74 -3847.39 0.51 -0.27 -0.53 17-SEP-98 MWD 6638.36 55.80 287.42 94.75 4586.96 4196.49 1493.49 -3922.02 0.42 0.12 -0.49 i I r " SURVEY CALCULATION AND FIELD WORKSHEET ~ Job No. 0450-00350 Sidetrack No.__ Page 4 of .. 4 I-'[l~t--]-'l :/e-~! Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILLSITE 2N/325 Survey Section Name SPERRY SUN BHI Rep.KIRT CHRISTENSEN WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -74.28 Grid Correction 0.000 Depths Measured From'RKl~ MSI_~ SS['-] Target Description Target Coord. E/W Slot Coord. E/W -821.40 Magn. Declination 26.830 Calculation Method MINIMUM CURVATU[ Target Direction (DD) Build\Walk\DL peffi0ft[~ 30m[--] 10m~ Vert. Sec. Azim. 290.21 Magn. to Map Corr. 26.830 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate ~,~_gl[~ .~T/)S +0F/T ~0V u~l~r°pBuild (+)(_) Right (-)(+) Comment Date Tool Depth Angle Direction L TVD Section N( (-) E( (-'~ (peDrh 0(] Type (FT) (DD) (DD) (FT) Left 17-SEP-9~ MWD 6733.26 55.93 287.90 94.90 4640.21 4274.96 1517.32 -3996.86 0.44 0.14 0.51 -- 17-SEP-91~ MWD 6826.55 55.98 288.61 93.29 4692.44 4352.22 1541.53 -4070.27 0.63 0.05 0.76 17-SEP-9~ MWD 6921.78 56.04 287.97 95.23 4745.68 4431.13 1566.31 -4145.24 0.56 0.06 -0.67 17-SEP-9[ MWD 7013.93 55.98 287.20 92.15 4797.20 4507.46 1589.39 -4218.08 0.70 -0.07 -0.84 17-SEP-9~ MWD 7109.03 55.70 286.83 95.10 4850.60 4586.02 1612.42 -4293.32 0.44 -0.29 -0.39 17-SEP-9fi MWD 7200.00 55.05 288.75 90.97 4902.29 4660.81 1635.28 -4364.60 1.88 -0.71 2.11 31' SLIDE 130R TF 17-SEP-98 MWD 7293.44 54.46 290.81 93.44 4956.21 4737.11 1661.10 -4436.40 1.91 -0.63 2.20 17-SEP-98 MWD 7387.08 54.59 290.53 93.64 5010.56 4813.37 1688.02 -4507.75 0.28 0.14 -0.30 17-SEP-98 MWD 7478.33 54.56 290.26 91.25 5063.45 4887.72 1713.93 -4577.45 0.24 -0.03 -0.30 17-SEP-98 MWD 7570.75 54.51 290.61 92.42 5117.07 4963.00 1740.21 -4647.98 0.31 -0.05 0.38 17-SEP-98 MWD 7664.78 54.21 289.61 94.03 5171.86 5039.41 1766.49 -4719.74 0.92 -0.32 -1.06 17-SEP-98 MWD 7760.43 55.25 290.90 95.65 5227.10 5117.50 1793.53 -4793.00 1.55 1.09 1.35 17-SEP-98 MWD 7857.59 55.90 288.81 97.16 5282.03 5197.64 1820.74 -4868.37 1.90 0.67 -2.15 17-SEP-98 MWDi 7947.11 56.82 291.67 89.52 5331.63 5272.15 1846.53 -4938.28 2.85 1.03 3.19 17-SEP-98 MWD 8040.73 57.04 290.63 93.62 5382.71 5350.59 1874.83 -5011.45 0.96 0.23 -IA1 17-SEP-98 MWD 8105.33 57.29 290.73 64.60 5417.74 5404.87 1894.00 -5062.23 0.41 0.39 0.15 17-SEP-98 MWD 8182.00 57.29 290.73 76.67 5459.17 5469.38 1916.84 -5122.57 0.00 0.00 0.00 NO SURVEY (EXTRAPOLATE TO BIT) ,. gyroldata ORIGINAL ARCO ALASKA INC. DRILLSITE 2N, WELL NO. 2N-325 TARN POOL, KUPARUK RIVER UNIT, ALASKA Gyro Continuous Muitishot Survey Inside 3.5" TUBING Survey date · 07 - NOVEMBER, 1998 Job number: AK1198GCE507 CONTENTS JOB NUMBER :AK1198GCE507 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION, SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER · AK1198GCE507 Tool 761 was run in WELL# 2N-325 on SCHLUMBERGER 7/32" wireline inside 3.5" TUBING. The survey was completed without any problems. SURVEY CERTIFICATION SHEET JOB NUMBER: AK1198GCE507 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- JACK E. MAY OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: AK1198GCE507 CLIENT: ARCO ALASKA INC. RIG: SCHLUMBERGER LOCATION: DRILLSITE 2N WELL: 2N-325 LATITUDE: 70.25 N LONGITUDE: 149.8 W SURVEY DATE: SURVEY TYPE: 07- NOVEMBER, 1998 GYRO CONTINUOUS MULTISHOT DEPTH REFERENCE: ROTARY TABLE ELEVATION 147.3' MAX. SURVEY DEPTH: 7298' SURVEY TIED ONTO: N/A SURVEY INTERVAL: 0-7298' APl NUMBER: TARGET DIRECTION: 050-103-2026900 290.21 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. OUTRUN SURVEY LISTING A G y r o d a t a D i r e c t i o n a i S u r v e y for ARCO ALASKA INC. WELL: 2N-325, 3.5" Location: DRILLSITE 2N, KRU, TARN POOL Job Number: AKl198GCE507 R. un Date: 7-Nov-98 16:00:00 Surveyor: TOM STODDARD Calculation, Method: MINIMUM CURVATURE Survey Latitude: 70.250000 deg. N Sub-sea Correction from Vertical Reference: 147.3 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 290.210 dog Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gy r o d a t a D i r e c t i o n a i S u r v e y ARCO ALASKA INC. WELL: 2N-325, 3.5" Location: DRILLSITE 2N, Job Number: AKl198GCE507 KRU, TARN POOL Page 1 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 0.0 0.00 0.00 100.0 .80 246.08 200.0 .96 237.00 300.0 .86 235.41 400.0 .94 250.36 .00 0.0 -147.3 0.0 .80 100.0 -47.3 .5 .22 200.0 52.7 1.5 .10 300.0 152.7 2.4 .25 400.0 252.7 3.5 0.0 0.0 .7 246.1 2.2 242.7 3.8 240.0 5.4 240.9 0.0 N 0.0 E .3 S .6 W 1.0 S 2.0 W 1.9 S 3.3 W 2.6 S 4.7 W 500.0 .46 278.38 600.0 .52 12.55 700.0 1..61 333.68 800.0 3.73 316.36 900.0 6.1.2 307.43 .58 500.0 352.7 4.5 .72 600.0 452.7 5.0 .24 699.9 552.6 6.1 .25 799.8 652.5 1.0.0 .50 899.4 752.1 ].8.0 6.5 244.2 6.6 249.3 6.7 264.7 10.0 287.3 18.2 298.1 2.8 S 5.9 W 2.3 S 6.2 W .6 S 6.7 W 3.0 N 9.6 W 8.6 N 16.0 W 1000.0 8.83 306.77 1100.0 12.42 306.82 1.150.0 14.70 307.40 1200.0 16.58 308.33 1250.0 17.66 309.27 2.71 998.6 851.3 30.5 3.60 1096.9 949.6 48.1 4.55 1145.5 998.2 59.3 3.80 1193.6 1.046.3 72.2 2.23 1241.4 1094.1 86.1 31.3. 301.9 49.5 303.7 61.2 304.4 74.7 305.0 89.3 305.6 16.4 N 26.4 W 27.5 N 41.2 W 34.5 N 50.5 W 42.8 N 61.2 W 52.0 N 72.6 W 1300.0 18.68 309.61 1.350.0 20.23 31.0.07 1400.0 21.29 309.88 1_450.0 22.]..9 309.4'7 1.500.0 23.04 308.71.. 1.550.0 24.66 305.08 1600.0 25.79 302.37 ].650.0 27.26 299.91 1.700.0 28.44 298.29 1750.0 30.05 294.92 2.05 1288.9 114]_.6 100.9 3.12 1.336.0 1188.7 11.6.5 2.11 1382.8 1235.5 133.2 1.83 1429.2 1.281.9 150.7 1..80 1475.4 1328.1 168.9 4.37 1.521_.1. 1373.8 1.88.2 3.23 1566.4 141.9.1 209.0 3.67 1611.1 1463.8 230.9 2.79 1655.3 1508.0 254.0 4.62 1698.9 1551.6 278.2 104.9 306.2 121.5 306.7 139.2 307.1 157.7 307.4 1.76.9 307.6 197.2 307.5 21.8.4 307.1 240.6 306.6 263.8 305.9 287.9 305.1 61.9 N 84.7 W 72.6 N 97.5 W~" 84.0 N 111.0 W' 95.8 N 125.3 W 107.9 N 1.40.2 W 1.20.1 N 1.56.4 W 131.9 N 174 . i W 143.4 N 193.2 W 154.8 N 213.6 W 165.7 N 235.5 W A G y r o d a t a D i r e c t i o n a i S u r v e y ARCO AIJASKA liNC. WELL: 2N-325, 3.5" Location: DRILLSITE 2N, Job Number: AKl198GCE507 KRU, TARN POOL Page 2 MEASURED DEPTH feet I N C L AZIMUTH deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 1800.0 1850.0 1900.0 1950.0 2000.0 31.23 293.08 33.44 288.98 36.22 287.44 38.04 287.56 39.67 287.84 3.00 1741.9 1594.6 303.6 313.0 304.2 6.23 1784.2 1636.9 330.4 339.0 303.2 5.84 1825.2 1677.9 358.9 366.7 302.0 3.63 1865.1 1717.8 389.0 396.0 300.9 3.28 ]_904.0 1756.7 420.4 426.6 300.0 176.0 N 258.8 W 185.6 N 283.7 W 194.5 N 310.8 W 203.6 N 339.6 W " 213.1 N 369.5 W 2050.0 2].00.0 2150.0 2200.0 2250.0 4]_.41 288.34 43.39 288.70 46.19 288.95 48.74 289.44 51.06 289.95 3.55 1942.0 1794.7 452.9 458.4 299.1 3.99 ]_978.9 ].831.6 486.6 491.6 298.4 5.61 20].4.4 1867.1 521.8 526.4 297.8 5.14 2048.2 1900.9 558.6 562.8 297.2 4.70 2080.4 1933.1 596.8 600.7 296.7 223.2 N 400.4 W 233.9 N 432.4 W 245.3 N 465.7 W 257.4 N 500.5 W 270.3 N 536.5 W 2300.0 2350.0 2400.0 2450.0 2500.0 53.44 289.89 54.64 289.71 55.59 288.9]. 55.46 288.71 55.69 288.59 4.77 2111.0 1963.7 636.4 640.0 296.3 283.8 N 573.7 W 2.42 2140.4 ].993.1 676.9 680.2 295.9 297.5 N 611.7 W 2.30 2169.0 2021.7 71,7.9 721.0 295.6 3].1.0 N 650.5 W .41 2197.3 2050.0 759.1. 761..9 295.2 324.3 N 689.5 W .50 2225.6 2078.3 800.3 802.9 294.9 337.5 N 728.5 W 2550.0 2600.0 2650.0 2700.0 2750.0 2800.0 2850.0 2900.0 2950.0 3000.0 55.49 288.50 55.35 288.37 55.51 288.46 55.24 288.27 55.59 288.42 55.45 288.60 55.31 288.80 55.53 288.88 55.36 288.95 55.52 289.11 .43 2253.8 2106.5 841.5 843.9 294.5 .35 2282.2 2134.9 882.7 884.9 294.3 .35 231.0.6 2163.3 923.8 925.9 294.0 · 62 2339.0 2191.7 964.9 966.8 293.8 .74 2367.4 2220.1. 1.006.1 1007.8 293.5 .41. 2395.7 2248.4 ]_04'?.3 ].048.9 293.3 · 44 2424.1. 2276.8 1088.4 1089.9 293.2 .45 2452.5 2305.2 ].129.6 1130.9 293.0 · 35 2480.8 2333.5 1170.7 1172.0 292.9 .40 2509.2 2361.9 1211.9 12].3.1 292.7 350.6 N 767.7 W 363.6 N 806.7 W,'" , 376.7 N 845.8 W 389.6 N 884.8 W 402.6 N 923.9 W , 415.7 N 963.0 W 428.8 N 1002.0 W 442.1 N 1040.9 W 455.5 N 1.079.9 W 468.9 N 1118.8 W A G y r o d a t a D i r e c t i o n a i S u r v e y ARCO ALAS~CA INC. WELL: 2N-325, 3.5" Location: DRILLSITE 2N, Job Number: AKl198GCES07 KRU, TARN POOL Page 3 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 3050.0 55.24 289.21 3100.0 55.00 289.28 3].50.0 54.92 289.53 3200.0 54.55 289.58 3250.0 54.27 289.66 .58 2537.6 2390.3 1253 . 0 1254.2 292.6 .49 2566.2 2418.9 1294.1 1295.1 292.5 .45 2594.9 2447.6 1335.0 1336.0 292.4 .74 2623.8 2476.5 1375.8 1376.8 292.3 .57 2652.9 2505.6 1416.5 1417.4 292.3 482.4 N 1157.7 W 495.9 N 1196.4 W 509.5 N 1235.0 W 523.2 N 1273.5 W 536.9 N 131]..8 W 3300.0 53.70 289.77 3350.0 53.44 289.79 3400.0 53.59 289.98 3450.0 54.67 289.62 3500.0 55.61 289.30 1.16 2682.3 2535.0 1456.9 1457.8 292.2 .52 271]..9 2564.6 1497.1 ].498.0 292.1 .43 2741.7 2594.4 1537.3 1538.1 292.1 2.23 2771.0 2623.7 1577.9 1578.6 292.0 1.95 2799.6 2652.3 1618.9 1.619.6 291.9 550.5 N 1349.8 W 564.1_ N 1.387.7 W 577.8 N 1425.5 W 591.5 N 1463.6 W 605.2 N 1502.3 W 3550.0 56.48 288.61 3600.0 56.25 288.69 3650.0 56.26 288.79 3700.0 55.66 288.96 3750.0 55.7'? 289.08 2.08 2827.5 2680.2 1660.3 1661.0 291.9 .47 2855.2 2707.9 1702.0 1702.6 291..8 ._1.7 2883.0 2735.7 1,743.5 ].744. I 29]...7 1.24 2910.9 2763.6 1784. 9 1785.5 291.6 .29 2939 . 1 2791 . 8 1826 . 2 1826 . 8 291.6 618.6 N 1541.5 W 632.0 N 1581.0 W 645.3 N 3,620.3 W 658.7 N 1659.6 W 672.2 N 1698.6 W 3800.0 55.33 289.19 3850.0 55.23 289.44 3900.0 55.05 289.57 3950.0 54.58 289.65 4000.0 56.23 290.07 4050.0 57.45 290.84 4100.0 57.57 290.94 41.50.0 57.31 290.98 4200.0 57.11 291..12 4250.0 57.15 291.36 .90 2967.4 2820.]. 1,867.5 1868.0 291.5 .45 2995.9 2848.6 1908.6 1909.0 291.5 .43 3024.4 2877.1 1949.6 1950.0 291.4 .95 3053.3 2906.0 1.990.4 ].990.9 291.4 3.37 308]_.6 2934.3 2031.6 2032.0 291.4 2.'7'7 3109.0 2961.'7 2073.5 20'73.9 291.4 .29 3135.8 2988.5 2115.6 2116.1 291.3 .52 31.62.8 3015.5 2].57.8 2158.2 29]..3 .46 3189.8 3042.5 2199.8 2200.2 291.3 .40 32].7.0 3069.7 224]_.8 2242.2 291.3 685.7 N 1.737.6 W 699.3 N 1776.4 W( 7].3.0 N 1815.0 W' 726.7 N 1853 .5 W 740.7 N ]_892 .2 W 755.3 N ].931.4 W 770.3 N 1970.8 W 785.4 N 2010.2 W 800.5 N 2049.4 W 815.7 N 2088.6 W A G y r o d a t a D i r e c t i o n a i S u r v e y ARCO ALASKA INC. WELL: 2N-325, 3.5" [~ocati. on: DRILLSITE 2N, Job Number: AKl198GCE507 KRU, TARN POOL Page 4 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 4300.0 56.67 291.45 4350.0 56.93 291.42 4400.0 56.68 291.39 4450.0 56.55 291.52 4500.0 56.69 291..52 .96 3244.3 3097.0 2283.7 2284.1 291.3 .52 3271.6 3124.3 2325.5 2325.9 291.3 .50 3299.0 3151.7 2367.3 2367.8 291.3 .33 3326.5 3179.2 2409.1 2409.5 291.3 .28 3354.0 3206.7 2450.8 2451.3 291.3 831.0 N 2127.6 W 846.3 N 2166.5 W 861.6 N 2205.5 W 876.9 N 2244.3 W , 892.2 N 2283.2 W 4550.0 56.47 291.54 4600.0 56.78 291.62 4650.0 56.47 291.69 4700.0 56.58 291.74 4750.0 56.58 291.73 .44 3381.6 3234.3 2492.5 2493.0 291.3 .64 3409.1 3261.8 2534.3 2534.8 291.4 .64 3436.6 3289.3 2576.0 2576.5 291.4 .24 3464.2 3316.9 2617.7 261.8.2 291.4 .02 3491.7 3344.4 2659.4 2660.0 291.4 907.5 N 2322.0 W 922.8 N 2360.8 W 938.3 N 2399.6 W 953.7 N 2438.4 W 969.1 N 2477.1 W 4800.0 56.28 291.71 4850.0 56.28 291.84 4900.0 55.83 291.97 4950.0 55.86 292.07 5000.0 55.17 291..14 .60 3519.3 3372.0 2701.1 2701.6 291.4 .23 3547.1 3399.8 2742.7 2743.2 291.4 .91 3575.0 3427.7 2784.1 2784.7 291.4 .18 3603.1 3455.8 2825.5 2826.1 291.4 2.06 3631.4 3484.1 2866.7 2867.3 291.4 984.6 N 2515.8 W 1000.0 N 2554.5 W 1015.5 N 2592.9 W ]_031.0 N 2631.3 W ]_046.2 N 2669.6 W 5050.0 54.25 289.71 5100.0 54.40 289.73 5].50.0 54.03 289.71 5200.0 54.21 289.79 5250.0 54.0'7 289.92 5300.0 53.85 290.02 5350.0 53.83 290.32 5400.0 53.35 290.36 5450.0 53.66 290.45 5500.0 54.07 288.81 2.97 3660.3 3513.0 2907.5 2908.1. 291.4 .29 3689.5 3542.2 2948.1 2948.7 291.4 .75 3'718.7 357]..4 2988.7 2989.2 291..3 .40 3748.0 3600.7 3029.2 3029.7 291.3 .35 3777.3 3630.0 3069.7 3070.2 291.3 .48 3806.7 3659.4 311.0.1 3].10.7 291..3 .49 3836.2 3688.9 3150.5 3151.0 291.3 .98 3865.9 3718.6 3190.7 3191.3 291.3 .64 3895.6 3748.3 3230.9 3231..4 291.2 2.78 3925.1. 3777.8 3271.3 3271.8 291.2 ].060.4 N 2707.9 W 1.074.1 N 2746.1 1_087.8 N 2784.3 W" 1.101.5 N 2822.4 W 1_115.2 N 2860.5 W 1.129.]. N 2898.5 W 1.1.43.0 N 2936.4 W 1.1.57.0 N 2974.1 W ]_171.0 N 3011.8 W 1.184.5 N 3049.9 W A Gy r o d a t a D i r e c t i o n a i S u r v e y ARCO ALASKA INC. WELL: 2N-325, 3.5" Location: DRILLSITE 2N, Job Number: AKl198GCE507 KRU, TARN POOL Page 5 MEASURED DEPTH feet I N C L AZIMUTH deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 5550.0 5600.0 5650.0 5700.0 5750.0 54.89 286.40 54.07 286.50 53.80 286.70 53.78 286.99 53.50 287.16 .25 3954.2 3806.9 3311.9 3312.4 291.2 .65 3983.2 3835.9 3352.5 3353.0 291.1 .63 4012.6 3865.3 3392.9 3393.3 291.1 .47 4042.2 3894.9 3433.2 3433.5 291.0 .62 4071.8 3924.5 3473.4 3473.7 291.0 1196.8 N 1208.4 N 1219.9 N 1231.6 N 1243.4 N 3088.6 W 3127.7 W 3166.4 W 3205.0 W 3243.5 W 5800.0 5850.0 5900.0 5950.0 6000.0 53.82 287.27 53.44 287.18 53.39 287.20 53.29 287.11 52.76 287.15 .68 4101.5 3954.2 351_3.6 351.3.9 290.9 .78 4131.1. 3983.8 3553.8 3554.0 290.9 .11 4160.9 4013.6 3593.9 3594.1 290.8 .26 4190.8 4043.5 3633.9 3634.1 290.8 .06 4220.8 4073.5 3673.8 3674.0 290.8 1255 . 3 N 1267.3 N 1279.1 N 1291 . 0 N 1302 . 7 N 3282.0 W 3320.4 W 3358.8 W 3397.1. W 3435.3 W 6050.0 6100.0 6150.0 6200.0 6250 . 0 53.28 287.17 55.39 287.55 55.48 287.46 55.52 287.53 55.55 287.67 .04 4250.9 41_03.6 3713.7 3713.9 290.7 .27 4280.1 4132.8 3754.3 3754.4 290.7 .25 4308.4 4161.1 3795.4 3'795.5 290.7 .14 4336.7 41.89.4 3836.6 3836.7 290.6 .24 4365.0 421.7.7 3877.7 3877.8 290.6 131.4 . 5 N 1326 . 6 N 1339.0 N 1351.4 N 1363 . 9 N 3473 . 4 W 3512 . 2 W 3551 . 5 W 3590 . 8 W 3630 . 1 W 6300.0 6350.0 6400.0 6450.0 6500.0 6550.0 6600.0 6650.0 6700.0 6750.0 55.49 287.41 55.27 287.60 55.56 287.60 55.85 287.50 55.74 287.30 55.80 287.23 55.76 287.4]_ 56.05 287.44 55.71 287.37 56.02 287.42 · 45 4393.4 4246.]_ 3918.9 3919.0 290.6 · 53 4421_.8 4274.5 3960.0 3960.1 290.5 57 4450.1 4302.8 4001.1 4001.2 290.5 .61 4478.3 4331.0 4042.4 4042.4 290.5 · 39 4506.4 4359.1. 4083.7 4083.7 290.4 .17 4534.5 4387.2 4125.0 4].25.0 290.4 .32 4562.7 4415.4 4166.3 4166.3 290.4 .60 4590.7 4443.4 4207.6 4207.6 290.3 · 69 4618.7 4471.4 4249.0 4249.0 290.3 .63 4646.8 4499.5 4290.3 4290.3 290.3 1376.3 N 1388.7 N 1401.1 N 14 ].3.6 N 1425.9 N 1.438.2 N 1.450 . 5 N 1462 . 9 N 1475.3 N 1487 . 7 N 3669.4 W 3708 . 6 W/ 3747 8 W'~ 3787 . 2 W 3826.7 W 3866 . 2 W 3905 . 6 W 3945.1 W 3984 . 6 W 4024 . 1 W ARCO ALASKA INC. WELL: 2N-325, 3.5" Location: DRILLSITE 2N, Job Number: AKl198GCE507 A G y r o d a t a D i r e c t i o n a i S u r v e y KRU, TARN POOL Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 6800.0 55.81 287.42 .43 4674.8 4527.5 4331.7 4331.7 290.3 6850.0 55.79 28'7.36 .10 4702.9 4555.6 4373.0 4373.0 290.2 6900.0 56.23 287.44 .89 4730.9 4583.6 4414.4 4414.4 290.2 6950.0 55.96 287.21 .66 4758.8 4611.5 4455.8 4455.8 290.2 7000.0 56.18 287.34 .50 4786.7 4639.4 4497.3 4497.3 290.2 1500.1 N 4063.6 W 1.512.4 N 4103.1 W 1524.8 N 4142.7 W 1537.2 N 4182.3 W 1549.5 N 4221.9 W 7050.0 55.95 287.25 .48 4814.6 4667.3 4538.7 4538.7 290.1 7100.0 55.68 287.15 .58 4842.7 4695.4 4580.0 4580.0 290.1 '7150.0 55.78 287.15 .21 4870.8 4723.5 4621.3 4621.3 290.1 7200.0 55.07 288.58 2.75 4899.2 4751.9 4662.4 4662.4 290.1 7250.0 54.64 290'.04 2.55 4928.0 4780.7 4703.3 4703.3 290.0 1561.8 N 4261.5 W 1574.1 N 4301.0 W 1586.3 N 4340.5 W 1598.9 N 4379.7 W 1612.4 N 4418.3 W 7298.0 54.51 290.81 1.34 4955.8 4808.5 4742.4 4742.4 290.1 1626.0 N 4454.9 W Final Station Closure: Distance: 4742.40 ft Az: 290.05 deg. A Gy r o d a t a D i r e c t i o n a i S u r v e y for ARCO ALASKA INC. WELL: 2N-325, 3.5" Location: DRILLSITE 2N, KRU, TARN POOL Job Number: AKl198GCE507SS Ru.n Date: 7-Nov--98 16:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.250000 deg. N Sub-sea Correction from Vertical Reference: 147.3 ft. Azi.m~lth Correction: Gyro: Bearings are Relative to True North Propesed Well Directien: 290.210 deg Vertical Sectien Calculated from Well }lead Lecatien Closure Calculated frem Well Head Lecation Horizental Ceerdinates Calculated from Local Horizental Reference A Gy r o d a t a D i r e c t i o n a i S u r v e y ARCO ALASKA INC. WELL,: 2N-325, 3.5" Location: DRILLSITE 2N, KRU, Job Number: AKl198GCE507SS TARN POOL Page SUBSEA I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL VERTICAL CLOSURE SEVERITY DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet -147.3 0.00 0.00 0.0 .88 241.78 100.0 .92 236.25 200.0 .90 242.48 300.0 .71 263.62 0.00 .52 .16 .17 .41 0.0 147.3 247.3 347.3 447.3 0.0 1.0 1.9 2.9 4.0 0.0 0.0 2.2 244.5 3.8 241.4 5.4 240.4 6.5 242.5 0.0 N 0.0 E .6 S 1.3 W 1.4 S 2.6 W 2.2 S 4.0 W 2.7 S 5.3 W 400.0 .49 152.52 500.0 ]..04 354.15 600.0 2.61 325.47 700.0 4.87 312.10 800.0 7.43 307.11 .65 .97 1.72 2.37 2.60 547.3 647.3 747.3 847.3 947.3 4.7 5.5 7.9 13.8 24.0 6.6 246.6 6.7 256.6 10.0 275.4 18.2 292.5 31.1 299.9 2.6 S 6.0 W 1.5 S 6.4 W 1.7 N 8.0 W 5.7 N 12.6 W ]_2.4 N 21.0 W 900.0 10.61 306.79 1000.0 14.77 307.43 1100.0 17.79 309.31 1200.0 20.49 310.02 1300.0 22.52 309.17 3.15 4.52 2 .21 2 .88 1.82 1047.3 1147.3 1247.3 1_347.3 1447 .3 39.2 59.8 88.0 120.6 157.8 49.5 302.8 74 .7 304 .4 104 .9 305.7 139.2 306.8 176.9 307.5 21.9 N 33.7 W 34.8 N 50.9 W 53.3 N 74.1 W '75.4 N 100.7 W 100.6 N 131.1 W 1400.0 25.32 303.51 1500.0 28.22 298.58 1600.0 31.51 292.56 1,700.0 37.23 287.50 1.800.0 411.70 288.39 1900.0 48.67 289.43 2000.0 54.87 289.52 2100.0 55.53 288.52 2200.0 55.34 288.31 2300.0 55.49 288.87 3 . 71 2.95 3 .4]. 4 .62 3 .61 5.16 2 .39 .44 .66 .45 ].547.3 ]_647.3 1747.3 1847.3 1947.3 2047.3 2147 .3 2247 .3 2347.3 2447.3 200.2 249.8 307.0 375.6 457.7 557.6 686.7 832.0 977.0 1122.1 2].8.4 307.3 263.8 306.0 339.0 304.1 396.0 301.4 491.6 299.0 562.8 297.2 721.0 295.8 843.9 294.6 1007.8 293.7 1130.9 293.0 126.9 N 166.6 W 152.7 N 209.9 W 177.2 N 261.9 W 1_99.5 N 326.8 W 224.7 N 405.0 W 257.1 N 499.5 W 300.7 N 621.1 W 347.6 N 758.6 W 393.4 N 896.3 W 439.7 N 1033.8 W A Gy r o d a t a D i r e c t i o n a i S u r v e y ARCO ALASKA INC. WELL: 2N-325, 3.5" Location: DRILLSITE 2N, KRU, Job Number: AKl198GCE507SS TARN POOL Page SUBSEA I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL VERTICAL CLOSURE SEVERITY DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 2400.0 55.16 289.23 2500.0' 54.33 289.64 2600.0 53.80 289.91 2700.0 56.32 288.67 2800.0 55.65 289.11 .55 .60 .77 .93 .47 2547.3 2647.3 2747.3 2847.3 2947.3 1267.0 1408 .7 1545.1 1690.1 1838.2 1295.1 292.6 1417.4 292.3 1578.6 292.1 1702.6 291.8 1868.0 291.6 487.0 N 1170.8 W 534.2 N 1304.5 W 580.4 N 1432.8 W 628.2 N 1569.7 W 676.1 N 1709.9 W 2900.0 54.67 289.63 3000.0 57.46 290.96 3]_00.0 56.70 291.45 3200.0 56.66 291.52 3300.0 56.51 291.71 .85 .39 .91 .29 .48 3047.3 3147.3 3247.3 3347.3 3447.3 1982.0 2133.6 2288.3 2440.6 2592.2 1990.9 291_.4 2158.2 291.3 2325.9 291..3 2451.3 291.3 2618.2 291.4 723.9 N 1845.6 W 776.8 N 1987.6 W 832.7 N 2131.9 W 888.4 N 2273.7 W 944.3 N 2414.7 W 3400.0 56.28 291.85 3500.0 54.66 290.36 3600.0 54.21 289.79 3700.0 53.65 290.33 3800.0 54.69 286.97 .23 2.56 .41 .67 3.90 3547.3 3647.3 3747.3 3847.3 3947.3 2742.9 2889.1 3028.2 3165.5 3302.3 2784.7 291.4 2908.1 291.4 3029.7 291.3 319]..3 291..3 3312.4 291.2 1000.1 N 2554.7 W 1054.0 N 2690.7 W 1101.2 N 2821.5 W 1].48.2 N 2950.5 W 1193.9 N 3079.5 W 3900.0 53.73 287.02 4000.0 53.42 287.1.9 41.00.0 53.21. 287.17 4200.0 55.53 287.59 4300.0 55.53 28'7.60 4400.0 55.78 287.31 4500.0 56.02 287.42 4600.0 56.07 287.30 4700.0 55.69 287.15 4800.0 54.55 290.57 .49 .41 1..05 .1.8 .56 .24 .62 .76 .52 1..71 4047.3 4147.3 4247.3 4347.3 4447.3 4547.3 4647 . 3 4747. 3 4847.3 4947.3 3440.1 3575.6 3708.9 3851..9 3997.0 4143.7 4291.1_ 4438.8 4586.8 4730.4 3473.7 291.0 3594.1 290.9 3713.9 290.7 3877.8 290.6 4001.2 290.5 4166.3 290.4 4331.7 290.3 4455.8 290.2 4621.3 290.]_ 4742.4 290.1_ 1.233.6 N 3211.6 W 1273.7 N 3341.3 W 1313.1 N 3468.9 W 1356.1 N 3605.4 W 1399.9 N 3743.9 W 1.443.8 N 3884.1 W 1487.9 N 4024.8 W 1532.1 N 4166.0 W 1.576.1 N 4307.5 W 1621.9 N 4443.7 W A G y r o d a t a D i r e c t i o n a 1 S u r v e y ARCO ALASKA INC. WELL: 2N-325, 3.5" Location: DRILLSITE 2N, KRU, Job Number: AKl198GCE507SS TARN POOL Page SUBSEA I N C L AZIMUTH DOGLEG VERTICAL VERTICAL CLOSURE DEPTH SEVERITY DEPTH SECTION DIST. AZIMUTH feet deg. deg. deg./ feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 4808.5 54.51 290.81 1.34 4955.8 4742 . 4 4742 . 4 290 . 1 1626.0 N 4454.9 W 4742.40 ft Az- 290.05 deg. Final Station Closure: Distance: 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: AK1198GCE507 TOOL NUMBER: 761 MAXIMUM GYRO TEMPERATURE: 74.84 C MAXIMUM AMBIENT TEMPERATURE: 53.28 C MAXIMUM INCLINATION: 57.57 AVERAGE AZIMUTH: 290.05 WIRELINE REZERO VALUE: O! REZERO ERROR/K: N/A CALIBRATION USED FOR FIELD SURVEY: 2714 CALIBRATION USED FOR FINAL SURVEY: 2765 PRE JOB MASS BALANCE OFFSET CHECK: -.75 POST JOB MASS BALANCE OFFSET CHECK': -1.28 USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS: OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING MWD 6921 56.04 287.97 4745 1566 - 4145 FINAL SURVEY 6950 55.96 287.21 4758 1537 -4182 FUNCTION TEST JOB NUMBER: AK1198GCE507 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 1100 12.42 12.42 12.42 12.42 12.42 AZIMUTH M.D. ft 1 2 3 4 5 1100 306.82 306.77 306.65 306.92 306.84 5. EQUIPMENT AND CHRONOLOGICAL REPORT I I EQUIPMENT REPORT JOB NUMBER: AKl198GCE507 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 761 GYRO SECTION DATA SECTION POWER SECTION BACKUP TOOL No. 789 GYRO SECTION DATA SECTION POWER SECTION A0149 C0111 C0083 A0057 C0089 C0086 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0433 A0085 A0079 A0143 A0467 A0107 A0029 A0055 WIRELINE COMPANY: SCHLUMBERGER CABLE SIZE: 7/32" RUNNING GEAR 2.25" HOUSING w/ ECCENTRIC BAR TOTAL LENGTH OF TOOL: 26' MAXIMUM O.D.: 2.25" INCHES TOTAL WEIGHT OF TOOL: 210 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: AK1198GCE507 SATURDAY, 11/07/98 15:00 16:45 17:15 19:30 21:45 22:30 24:00 FINISH 2N-321A RU SCHLUMBERGER, WARM UP TOOL PICK UP GYRO RIH SURVEY 1N TO 7298' SURVEY OUT LD TOOL. RETURN ATLAS SUNDAY, 11/08/98 12:00 CHECK TOOL, PROCESS SURVEY. m"ml~ I LLI NIi SEI:I~/I C E S To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs December 23, 1998 2N-325, AK-MM-80377 1 LDWG formatted Disc with verification listing. API#: 50-103-20269-00 PLEASE ACKNOWLEDGE RECEHrF BY SIGNING AND RETURNING THE A~VFACHED COPY OF THE TRANSMH'FAL LEq_~rER TO THE A~FF_,NTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date:D[C 7_3 1998 ~laska Oil & .Sas Cons. Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend _ Alter casing __ Repair well _ Change approved program __ Operation Shutdown __ Re-enter suspended well _ Plugging __ Time extension _ Stimulate _ Pulltubing__ Variance_ Perforate_ Other X Annular Injection 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development X_ Exploratory __ Stratigraphic ~ Service -- 6. Datum elevation (DF or KB) 28' RKB 7. Unit or Property name Kuparuk River Field/Tarn Oil Pool 8. Well number 74' FNL, 821' FEL, Sec. 3, T9N, R7E, UM At top of productive interval 1623' FSL, 148' FEL, Sec. 33, T10N, R7E, UM At effective depth At total depth 1814'FSL, 670'FEL, Sec. 33, T10N, R7E, UM 2N-325 9. Permit number 98-163 10. APl number 50-103-20269 - 11. Field/Pool Kuparuk River Field/Tarn Oil Pool 12. Present well condition summary Total Depth: measured 8182' feet (approx) true vertical 5459' feet Effective depth: measured 8000' feet (approx) true vertical 5360' feet Casing Length Size Structural Conductor 80' 16" Surface 2634' 7.625" Intermediate Production 7369' 5.5" x Liner 765' 3.5" Plugs (measured) Junk (measured) None Cemented 10 Cu Yds High Early 313 sx ASIII LW & 240 sx Class G 245 sx Class G Measured depth True vertical depth 108' 108' 2662' 2317' 7397' 5016' 8162' 5448' Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 7413' Packers and SSSV (type and measured depth) Baker CSR @ 7397', No SSSV ORIGINAL 13. Attachments Description summary of proposal __ Detailed operation program __ BOP sketch __ Contact Paul Mazzolini at 265-4603 with any questions. LOT test, surface cement details and casing detail sheets X 14. Estimated date for commencing operation November 1998 Oil X 16. If proposal was verbally approved Name of approver Date approved Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed' /.~~~~ Title Tarn Drilling Team Leader 15. Status of well classification as: Gas __ Suspended __ Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance require 10- l//1 ~¢...-~:¥~ Subsequent form Mechanical Integrity Test _ J Approved by the order of the Commission Origirlal Sigr~ed By ,¢~O Form 10-403 Rev 06/15/88 ]'Appr°val Commissioner Date // .. ~,,~"'"'~ ~'~ SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Casing Detail 7-5/8" Surface Casing WELL: TARN 2N-325 DATE: 9/14/98 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Doyon 141 RT to LR=29.10 29.10 7 5/8" Landing Joint 34' OA. 29.10 FMC GEN V- Prudhoe 7 5/8" Csg Hgr 2.65 29.10 31-62 7 5/8", 29.7#, L-80 BTC-MOD 1358.98 31.75 Jt #30 7 5/8", 29.7#, L-80 BTC-MC)D (Thread Locked Collar) 36.89 1390.73 Gemeco 7 5/8" Stage Collar (BAKERLOK) 2.78 1427.62 Jt. #29 7 5/8", 29.7#, L-80 BTC-MC)D (Thread Locked Collar) 40.38 1430.40 jts. 3-28 7 5/8",29.7#, L-80 BTC-MOD (shutoff baffle on top of jr #3, BAKEI 1107.86 1470.78 Gemeco Float Collar 1.28 2578.64 jts 1-2 7 5/8", 29.7#, L-80 BTC-MOD 80.31 2579.92 Gemeco Float Shoe 1.50 2660.23 Bottom of shoe 2661.73 Insert baffle @ 2537.93 TD @ 2675.00 2675.00 31 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1,2, over stop collars every collar thru Jt, # 15=every 3rd collar to surface. 1 above & 1 below stage collar. Remarks: String Weights with Blocks: 80K# Up, 70K# Dn, 12k# Blocks. Ran 62 Joints of casing. Drifted casing with 6.750 plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor: M. C, HElM ARCO Alaska, Inc. Cementing Details Well Name: 2N 325 Report Date: 09/14/98 Report Number: 3 Ri~l Name: DOYON 141 AFC No.: AK9485 Field: tarn Centralizers State type used, inten/als covered and spacing Comments: as per program Mud Weight: PV(prior cond): PV(after cond): [ YP(prior cond): YP(after cond): Comments: 10.2 41 21I 34 15 Full returns Gels before: Gels after: Total Volume Circulated: 11/14 4/9 200 bbl. Wash 0 Type: Volume: Weight: Comments: 0 0 Spacer 0 Type: Volume: Weight: Comments: ARCO 90 bbl 10.5 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: AS III LW 75 313I 10.5 4.42 Additives: as per program Tail Cement 0 Type: Mix wtr temp: I No. of Sacks: Weight: Yield: Comments: G 75I 240 15.8 1.17 Additives: as per program. Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 6 bpm i6 bpm 75k Reciprocation length: Reciprocation speed: Str. Wt. Down: 15' 90 fph 65k Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 117 bbl 117 bbl 70k Calculated top of cement: CP: Bumped plug: Floats held: surface Date:09/14/98 yes yes Time:12:30 Remarks:Full circ. thru out job=recovered 28 bbl cement fl 1st stage. Cement Company: Rig Contractor: Approved By: DS DOYON M.C. HE M CASING TEST and FORMATION INTEGRITY TEST Well Name: Supervisor: 2N-325 D.P. BURLEY 7 518", 29.7 ppf, L-80, BTC Date: 9115198 Casing Size and Description: Casing Setting Depth: Mud Weight: Hole Depth: LOT = 2661 TMD 9.1 ppg 2,336' TVD 850 psi (0.052 x 2,336') Fluid Pumped = 1.1 bbl 2,317' TVD EMW = Leak-off Press. + MW 0.052 x TVD + 9.1 ppg EMW = 16.1 ppg Pump output = 0.1000 bps TIME LINE 2,300 psi ,900 psi ' ,. ' .:, ..',,.' ~' ,~ J ....... ,800 psi ..... ,400 [ 9oo psi ............. ~ .................................................... ~LEAK-OFF TEST ............ ; CASING TEST SHUT IN TIME 700 psi ..... eooos~ / ~ TIME LINE 200 psi 0 psli , ............................................................................... 0 2 4 6 8 10 12 ~4 16 18 20 22 24 26 28 30 32 ~ 36 38 40 42 44 46 48 50 S2 ~ 56 58 60 82 ~ 66 68 70 72 74 76 78 80 82 ~ 86 STROKES LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE ! ~. L J J ................... [ .... .?.~.tL~. .... 1 ...... .o_..p~! ...... = 2 stks i 70 psi ................... i .... 'a"~' .... i .... :f¥O"~/~ .... ................... [ .... A~.t?. .... ~ .... ~.~_?_.P.~[ .... ,. [ 8 stks i 560 psi .................. ~ .... f6'~'~-~'"'! .... ................... ~ .................. i .................. L l i ................... ~. .................. ~ .................. ................... [ .................. i ................... ................... i .................. ! .................. ................... [ .................. ~ ...... , ........... ................... ~ .................. ~ .................. ................... ~ .................. 4 .................. ................... [ .................. .,' .................. ; ................ 'h" ................ ~ .................. ~ L J .J .... , ....... . ..... ! .... .._... .......... ! .................. SHUT IN TIME! SHUT IN PRESSURE OOmin ~ : 850nsi ...... ; ............ !'-~ ......... 1.0 min : . : 840 ps~ : · '-~:~'~-"'f ...... ! .... ~'~'~a'"! ~'-~;~'~F'"[ ....... ~ .... ~'~'~F"i .... ',1:5'~i~""-i ; .... ii¥O'~i"'i .................. ~ i .... ii:'~ ......... 5.0 rain i = I psi 7.0 min [ : 790 psi 80min ~ t 780ps~ 9.0mm : : 770 psi CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE I 0 stks 0 psi j 4 stks 410 psi , : 7 stks 980 psi .................. ] ..... ~-- J~ ....... J. L1..3..0.. --P-- --sj__--. : lOstks ~. 1,460psi , , : 12 stks 1,820 psi ::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::: : : : : 00rain : ; 2030 ;"-~'.~'~',~ .... : ........ ;"~;o'~iJ-~i'"! 3.0 min [ 2,010 psi i.._4....o.~j,,. .... ] ............. .2.,_ .o.o..o...p_ .~j_ _. , 5.0 mln : 1,990 psi 6.0min : 1,980 i 7.0min ~ 1,980 psi · 80min ! 1,980psi ~ ..... 9.0; ........... min 41 ........... +: ...... 1,§'~J/.... pSl'""'l: "q'b;'8';~'~F"i ......... 15.0min i ~ 1,960 Psi ! [ 20.0min : , 1,950ps~ : : 25.0min = ! 1,940 psi "'-~'/6%Tn-"] ............. ..r--¥;§~-i~i---[ NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: Supervisor: 2N-325 D.P.BURLEY 7 518", 29.7 ppf, L-80, BTC Date: 9/16198 Casing Size and Description: Casing Setting Depth: Mud Weight: Hole Depth: LOT = 2661 TMD 9.1 ppg 4,051' TVD 470 psi + 9.1 ppg (0.052 x 4,051 ') Fluid Pumped = 5.0 bbl 2,317' TVD EMW = Leak-off Press. + MW 0.052 x 'I'VD EMW = 11.3 ppg Pump output = 0.:1000 bps TIME LINE 2,300 psi . ; -~- ~Ol~t= IVII~U I t::: . 1,900 psi 1,700 psi 1,600 psi .... ~ ............................. 1,500 psl ' ...... , .... ,,,. ; r~ , : ,: ~ : : 'T I 1,400 psi ~.~oo.., 1,200 psi ~ .... ~ ~ : , ..; tooo psi ...... ~] ......, ......................................... ~ LEAK-OFF TEST 900 psi ~ ~CASING TEST eoo psi ................ . .....LOT SHUT IN TIME 700 psi J --,-- CASING TEST SHUT IN TIME soo psi .... ~ .......... ~ ............ ~ . TIME LINE 5OO psi . ........................................... ~ ........................ o 2 4 ~ 8 ~0 12 14 ~6 ~8 2o 22 24 26 28 3o 32 ~ 36 38 4o 42 44 46 48 5o 52 ~ 56 58 6o 62 ~ 66 68 7o 72 74 76 78 80 82 STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE · 0 stks { 0 psi ........................ -~-~- .... i .... ¥~'~"~a'"! ........................ -,~-~i~- .... ~ .... ~-~--~a---~ ........................ -~--~i~.~- .... ~ .... ~-~--~[---I 8stks ! 420 psi : ; ....................... ~-%~i[~-'"i .... i 14 stks : 400 psi ........................ ~-~-~[i,-~- ........ ~-~'-~['"i ........................ ~-~-~[~'~---'~ .... ~'~'i~a"'~ i.. .................................... .I .................. 20 stks 330 psi · 25 stks 310 psi : ........................ ~'~-~ii,'~''''~ .... ~i¥~'~["'~ ........................ :T~'i;ii('~' ........ ~b~'~['"i ................... ~ .................. ~ .................. : 40stks : 300 psi : " ...................... -,,ij-~;i~-~----" .... [~'~'i:;a"'i L ...................................... ~ .................. ~. .................................... L -~ .................. J ! i SHUT IN TIME SHUT IN PRESSURE 0.0 min = 290 p. si : · ---. ..................... ---~---~ --~,~ '..-~ .... r---'{ 1.0 min : z.~:.u__.P..S.L_.j .... ';~'.~'~i~ .... i 220 psi j "'-~:~%i~- .................. i .... ""',i:5%i;{ .................. i .... ~f~'~i'"~ ................... t ~ .............. .----4 5.0min : ~ 210psi "-f16%i~-'"r ........... ! .... ...... ; ............ ~ ............. ~ .................. 8.0 rain : : 200 psi j .... '6:6%i~; .... f ................. i .... L..~..~....~..~ ..... ~.,,,,,.~...~ ....................... CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE .......................................................... ! , t .................. J .................. ~ .................. 0 stks 0 psi ......................... Y-_~-f~ ......... ~i~--~,-a ..... ......................... >--~-t-~; ......... -~a--~,-a .... 3 stks 270 ps~ ......................... ~-~ ........ ~-a--~i .... ......................... ~--~ ........ ~-~--~i .... ......................... ~--~i~ ......... ~--~i .... 7 stks 980 psi ~ .................. ~ .................. ~ .................. , 8 stks 1,130 psi ......................... ~-~ .... T"~':~'~i"'i .................................... ~ .............. %---I 10 stks 1,460 psi : ........................ ¥~'~i~' ...... ¥:~'~a"'~ ........................ ¥~'~i~' ...... ¥;~'~a"i ........................ ¥~'~i~'"'~"~;6~'~a"'j ...................................................... .................. ~ .................. ~ .................. SHUT I~ TIME SHUT IN PRESSURE ~.o m,~ .__~__X,~.~.~.__~ 2.0 rain j 2,020 psi ~ ............................. 3.o m~ T"~;6~'~a .... r .... ~T6'~'B ..... ~"~;6~'~a'" }............... ...................... L. 5.0 min 6.0 rain ~ 1,980 psi ~ .... X*~'~T~ ................. T"¥;~*~a .... · . ..... ~ .................. : 9Omen : 1,970ps~ : 10.0min ~ 1,970 psi , 15.0min ~ 1,960psi ~ '"~'~'~%~ .... T'Y,'~*~'~T-'~ 25.0min ~ ~ 1,940 psi NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY SENT BY: 11-23--58 · 4:31P~I · ARCO ALASKA~ 907 276 7542 Dail~y O'rilling Report ARCO Alaska, Inc. AFC No. l'Dale Rpl No ] Rig AcCept-'~i'S Days S n¢~ Acc~-'~l/F..sI: 2.5 / 3,75 AK9485 Ji:~N14190 3 J 09/12~8 121o0100 Rig Relase - hr~: Well' 2N.325 Dnpth (MD/IVU) 25751Z.300 P,uv De-pill MD: ~;sT~ Pmgruss: o ~mractuL DOYON ~ily Co~t $177~5a' ~ Co~ S 4128~ ' E~'t C~st T~ Dale Ri~ Na~e ~YON 141 " Leal ~g: T SIS" ~61',"' ~Ne~t ese, 6.~ x, 3.~, ~"8040',, ,. o~mtlon At 0~o Teal 7 S/S~ csg. ~ 2~1'. (24 bm- h~line pe~r} lJ~midg ~ratiom~: Drill cut cement-I~,ddg. ~ 8u~eys, "' MUD D~TA ORILLING DATA Bl~ ~ATA ' ' EH&S ' ' ~ILL~P ~TA MOO IYPE DEPIH ' BIT N~' BIT HO,"" INOIO~hK ~'{'BOP~RT i'A~T ~OPIDR~L LSND ~ N TST ~IGHT " ROT ~ SIZE S~E EMPLOYE~' LAS'~ ~2S DRILL L~T FiRE DRILL 9~!ppg ~ 6 314 ........ 0~30~8 09/~9 ~COSI~ ..... PU ~ M~KE M~KE SPILL LAST CON~!~ED ~ST 5PI~DRILL s~ HTC N SPACE 0NI~8 PV~H 80~ '~YP~ ~YPF ~YPE ' FUEL &WA~R " 1~ I ~ 6TR~64 GELS ' AVG D~AG SERIAl NO 5ER~L N0 VOLUMff FU~["USFD " 21~ 51 G / 0322673 APl ~ '~ M~ DRAG '" DEPTH OUI *' DEPTH O~1' L~T SAFEIY*~TG DRILL WA ~ER USED, 9.0 Q~1~6 BBLS HTHP ~ TRO BTM DEPTH IN DEPTH IN ' POTABLE WA~ ' ' 1091 mU30 mln 2675 INJEC~QN U~ED - BULS ~OI iR~ ~RQ OF F ~OOTAGE FOOTAGE ~ECTION ~LL ..... W~ER & &a% a 2N 337 ~RSO~NEL DATA 'HOLE'VOLUMF PUMP PR~S AU ~I~ST AD ffAST SOURCE ~LL ' I EMP ~F 23 . Dh 'LINN~'SZ Rr'M i' RPM ~ PREDS~JRF {p~) ~NU DIREC~ON 120' LGS 'r ~PM I ,TFA TFA "' iNJECTiON FLUIU~" CI IILL FACTOR "F 19.~8 ~lef B~;e Mud~ 14~5 PiT VOL '~' GPM ~ .... J~ ~' d~ Fresh ~ler '~ ARCO PERSORNEL .... 6D ~ILY MUD RPS ~ ~IT COST "IT tORT " CO~ACTOR $es2e III o o ,,, TOTAL MUO Spp1 " DULL ~' DULL TOTAL VOL (bbl) MISC PE"SONNFI. COMPA'hY ~ ~ ~t~ ~0~ ' TOT F~ ~LL {bbl) ~E~WC~ TOTAL ' -TIMC I END i, ~dRS J - 'OPS CODE J F ~I;F R~Cf J PHAGE'0PS "J ' 'QPERATIONS FROM 0~0 - '12=~0 AM 03:~ AM 3,00 T~I~LOUT '~RF Othe~ "' PJSM~oh-lay d~ bha ~I. (Hole ~ g~d 03:00 AM e~:a0 AM 5,00 RUN_CSG ~RF Casing and PJSM=C~ floef,~g ~ & m~ 62 its. 7 618" 2g.7~ Ca.riling mod c~g.~a~ up landing JL & ~ent ~eed, aa:a0 AM Ol~3O ~M 1.60 CIRC SURF Ca~ing and Cifc.-condJtlen hole f/ce~ntlng ~ 8 bpm. Ce~nting 09:30 AM 10130 AM t.00 CM~CSG SURF C~Ing and Cemen~ 1~t 8~g~ as par preg~fll elm, thru out Job Cementln~ 10130 ~M t 1:20 AM 1,00 CIRC SURF C~ing and Open stago tool wi ~0~lm, cond hO~ t4:3G AM 01 :OD PM 1.50 CU~CSG SURF Casing ~d Cement ~ st~. as ~r program~,fl Cementing comet ~¢~BU~p pl~g~ut s~ I~1 w/t3~. 01100 PM 03;30 PM 2,50 NU_ND SURF Other Rig d~ do~ll=~y ~ la.lng ji.=n/d dive.er ;~m, 03:30 PM 07100 PM 3.50 NU_ND SURF O~ N/U ~pee~ head & ~=00 PM 10:30 PM 3,~0 NU_NB ~RF Otb~ ~ · ~{ 81i bo~Sa-35~ine~ wear dna, 10130 PM 12100 AM 1,SO BHA SURF Oth~ Pick up bhu ~ ...... Supervisor:. M,<:. HBIM Daily Drilling Report: 2N-325 0g114/98 Page 1 "SENT BY: 11-23-,58 · 4:30PM ; ARCO '.ALASKA-,- UO7 27~d '/-b~.'~ 7/ V ~I1.1~ ARCO Alaska, Inc. Cementing Details -' WaLl Name. 2N 325 R~port Date: 05/14/~1~ ~;~l~ort Nurhber 3 Rig Name DOYEN 141 AFC rio.: AKa415 t-ield: tam Cen~'alizem ~;tate lype used, intcrvol.~ rx:~re~l Comments: ............... as p~ program Mud ~lgt~t: PV(prier tend}: ~(~/tnr ~mm~ts: 10.2 41 .... Full ~rns G~ be~re; ..... ~els ~r; T~al Voi~e 1111~ ~ 20~ bbl. --- ~... i ...... ~Wash 0 Ty~: Vol~.~e: Wnighl: Comments: ~ ~ac~ 0 T~=: Vol~na: We ~mnmente: ARCO '~ bbl 16.E .... I ......... 1 ..... ~ad Cem,I 0 Typo' Mix wit letup:No. of g~: Wol~ht; ~eld: Commenla: AS Ill LW 75 313 10,~ 4.42 ~.. . .... Add,ives: as ~ ~ogram TallCement 0C om m,n,;: TY~:G IM~ ~r t'"0.7' N°'°fSack" I '" Waigh'~ '-1240 1 ,. 8 Yi;,d:l. t, ..... , ~ per program. _.~.. Diap~cement 0 Hete(~lOm tail at sh~): E~e(~il ~r~ ~a). Gtr. Cammenis: 6 ~m Is ~m 7ilk Reclpro~lion length' Eec~megt~q ~pnnd: 15' ~ f~ Theoretl~l Dlsp~cemen~ .... Aclual Dlapla~men~ Sir. ~ in mud: 117 bbl ~117 bbt calculated top ~ cemem' CP: ~ Burned pl~: ~nn~s ~ld: su~ace Dntn:Ogll~8 i yes yes Time:12:$O I Remark: Full tim, thru out job-m~vered 38 bbl cement fl t ~ ,.,,, ,. ~,~ ~.' ~ ,..... '" Cement Company: DS IDOYON IM.C. HElM SENT BY: i 1-23-.58 ' 4:31P~ ' ARCO ALASKA~. ~07 276 7-542' # 8/ B -- ARCO Alaska, Inc. Cementing Details Well Name: 2N :I2B Repor~D~e. 0~1~ ~p~Nu~r: 4 H~g Nnmm: DOYON t4~ AFC No.: AKg~6 Fiuid: TARN Ce$irlO~iz~ 7,516" H<31~ DiaPnaler: 9 -716:. '. Anglethm~U: I Sh°e~pth: ~ LC~ePth' ~% wsah°~: ,~. ~~. ~ .... 2S37 : Cenl~allt~e StYe ty~ ~d, tnte~als co~ and ' Co~t~: .... "' ~a ~r ~ogram U.d " ~[0~ ;"' PV(pH~r ~na). P~[afle; ¢ond): [ ~ Comments. ~ 0.2 41 21 Gale beforn' Cels ;h~ Total VM~. Ci~lat~: 11/14 ~ 240 ,. ...... . .... Wash 0 Type Vo~me: Weigh[' Comrde~ta; Spacer ' "0 Type: " VOItl~: .... Weight:"' Comment~: ARCO 30 bbls I 0. S L,~ C.m;;t'-~ T'ype: " MIx ~r tamp: No. ~ S~s; ~igh[ Yiel~ C~m~r,l,. AS III LW 7a 2~ 10.5 ~42 ~ .. , i .. .-. , Second n~ge Addilive=: as per pro~ Tell Cement 0 Type: ~ ~r lamp. Ne. ef S~ks: ~Ighl: Yield: Comment¢: ASll 70 50 1~,7 leeand ~tnge~. ......... A~lt~v~: a~ per p~Qr~ ~m~ts: 8 ~ nra 0 0 ~/a 6&~ b~s ~ bbl~ CalcUlated top ~ c~m e,,t. ""1 CP:~ ~np~ ~'l~: I FIu=tu'Ir,~I~: ~fl~elhnl stage collar ~ 1426', Oa~-9.14.ga yea Th~e;lZ~ h~ ,.... , _ Ruma~:See~d slagD: Full mturnn while careening, 70 DDI~ O[ 10,~ ppg c~nt ~u~ tO Cement Company'. IRig Contractor: JApproved By: DS IDOYON [D,P.BURLEY TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION September 2, 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Paul Mazzolini? Drlg Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2N-325 ARCO Alaska, Inc. Permit No: 98-163 Sur Loc: 74'FNL. 821'FEL, Sec. 3, T9N, R7E, UM Btmholc Loc. 1735'FSL, 472'FEL, Sec. 33, T10N, R7E, UM Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above referenced xvell. Thc permit to drill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Approval of annular disposal of drilling wastes is contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and anv CQLs must be submittcd to the Commission on form 10-403 to ensure the requirements of 20 AAC 25.080 are met prior to initiating disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a permitted existing well on Drill Site 2N must comply with thc 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 for a period longer than one year. Blowout prevention equipment (BOPE) must bc tested in accordancc with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witncss a test of BOPE installed prior to drilling new hole. Notice may be given ~cum field inspector on thc North Slope pager at 659-3607. Dav~r-d-W. Jolmston Chairman " BY ORDER OF THE COMMISSION dlffEnclosures cc; Department et' Fish & Game, ! Iabitat Section W/o encl. Department of Environmental Conservation w/o encl. SENT BY: 9- 1-88 ' 3:4~P~ ' ARCO ALASKA+ 907 276 7542:# 1/ 1 ARCO Alaska, Inc. Post Dfflce Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 1, 1998 Mr. David I. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-325 Permit to Drill Dear Mr. Commissioner: Please accelerate the processing of the Permit to Drill on 2N-325. The sidetrack of 2N-321A to another bottomhole location has caused us to revise our drilling schedule. Doyon 141 will be moving to 2N-325 early next week. We would appreciate it if you could have the permit ready by Friday September 4, 1998. If them are any questions, please call 263-4603. Sincerely, P. Mazzolini Tam Drilling Team Leader PM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMIV~SSION PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill X Redrill [~ lb Type of Well Exploratory [~ StratigraphicTest [~ Development Oil Re-Entry F' Deepen [-' Service X Development Gas [~ Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 121' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380054, ALK 4602 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 74' FNL, 821' FEL, Sec. 3, T9N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1635' FSL, 184' FEL, Sec. 33, T10N, R7E, UM 2N-325 #U-630610 At total depth 9. Approximate spud date Amount 1735' FSL, 472' FEL, Sec. 33, T10N, R7E, UM 9/11/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2N-323 8040' MD 1635' @ Target feet 25.9' @ 500' feet 2560 5509' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum hole angle 55.06° Maximum surface 1357 psig At total depth (TVD) 2300 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' +_230 AS I 9.875" 7.625" 29.7# L-80 BTC MOE 2621' 28' 28' 2649' 2300' 1.40 sx ASlIIL & 240 sx Cl. G 2. 240 Sx ASIIIL & 60 sx ASl 6.75" 5.5" x 15.5# / L-80 LTC M 7277' 28' 28' 7305' 4989' 230 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 735' 7305' 4989' 8040' 5509' (included above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summaryORiGiNAL 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 Structural Conductor ~.( EC''~ ~ Sudace Intermediate Production 'i, '~lQ ~ ;~ Liner A U 9 Perforation depth: measured true vertical ¢daska 0ii & Gas Cons, Commission 20. Attachments Filing fee X Property plat [~ BOP Sketch X Div~;~8~e'rtL-v~ X Ddlling program X Drilling fluid program X Time vs depth plot [--" Refraction analysis F~: Seabed report [~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~ ~/?~~~ , Title Drilling Team Leader Date 8/11/~ t ~ / Commission Use Only Permit Number I AP,.u~ber I Approval date ~,,~.. ,~ ... See cover letter for ~'~2 ...//~" S 50- /~1 ~.-- ~ O .2.. ~:~ ¢ F~) other requirements Conditions of approval Samples required [~ Yes ~' No Mud log required r~ Yes 'l~ No Hydrogen sulfidemeasures ~__ Yes I~ No Directional surveyrequired .l~ Yes I-~ No Required working pressure for BOPE F.~ 2M ~ 3M [~ 5M [~ 10M E~ 15M Other: di'lgtrlal 61glleO ~y David W. Johnston byorderof Approved by Commissioner the commission Date ¢ Form 10-401 Rev. 7-24-89 Submit in triplicate STATE OF ALASKA ALASI~ OIL AND GAS CONSERVATION COMM'I~SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Reddll r-] lb Type of Well Exploratory J--'] Stratigraphic Test r-J Development Oil J~ Re-Entry r-J Deepen E] Service X Development Gas ~ Single Zone X Multiple Zone ["-j 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 121' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380054, ALK 4602 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 74' FNL, 821' FEL, Sec. 3, TDN, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1635' FSL, 184' FEL, Sec. 33, T10N, R7E, UM 2N-325 #U-630610 At total depth 9. Approximate spud date Amount 1735' FSL, 472' FEL, Sec. 33, T10N, R7E, UM 9/11/98 $200,000 , . ~ 2. Distance to nearest 13. Distance to nearest well 14, Number of acres in property 15. Proposed depth (MD and TVD) property line 2N-323 8040' MD 1635' @ Target feet 25.9' @ 500' feet 2560 5509' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum hole angle 55.06° Maximum surfa~ 1357 psig At total depth (TVD) 2300 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casi.ng Weight Grade Coupling Length MD ]-VD MD 'I-VD (include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' +_230 AS I 9.875" 7.625" 29.7# L-80 BTC MOB 2621' 28' 28' 2649' 2300' 1.40 sx ASIIIL & 240 sx Cl. G 2. 240 Sx ASIIIL & 60 sx ASI 6.75" 5.5" x 15.5# / L-80 LTC M 7277' 28' 28' 7305' 4989' 230 sx Class G 6.75" 3.5" 9.3# L-80 8rd DUE 735' 7305' 4989' 8040' 5509' (included above) 19. To be completed for Reddll, 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 Surface ~'%.~._ Intermediate Production Liner DUPLICATE ..... Perforation depth: measured 20. Attachments Filing fee X Property plat E] BOP Sketch X Diverter Sketch X D"rfllt~l'~¢6"g~,m X Ddlling fluid program X Time vs depth plot E~ Refraction analysis E~ Seabed report F~ 20 AAC 25.050 requirements X 21. I hereby certify'that the foregoing is true and correct to the best of my knowledge Signed ~ )/'~t~¢'4~~ , Title Drilling Team Leader Date t. ~' t Commission Use Only P°rmit~b~'2~'~'-~ I~ APIso.r~O,,.~number '~..~'"' ~) ~. ~.. ~ I ^pprova, date ~ ~.,. ~ I See cover let~er,Orother requirements Conditions of approval Samples required [~ Yes ~ No Mud log required [2 Yes ~.~ No Required workingpressureforBOPE BI 2M ~ 3M [-] 5M r-] 1OM j'-j 15M Other: di'igmal ~lg~]~,a ~y ~)a~/id W. J0~nst0~ byorderof ¢...~.... ~'~ Approved by Commissioner the commission Date :orm 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Diverter Schematic Doyon 141 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet I Flowline ~ 21 ¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS L I I r- I I 3" 5,000 psi WP OCT MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE wi hydraulic actuator / J / DSA 13-5/8" 5.000 psi WP.--~L x 11" 3.000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom L ] 3" 5,000 psi WP Shaffer GATE VALVE rj ~_~~raulic actuator 13-5/8" 5.000 psi WP DRILLING SPOOL L]'~.~ w/two 3" 5M psi WP outlets I J SINGLE 13-5/8" 5,000 psi WP, I HYDRIL MPL BOP w/pipe rams ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N 325 1. Move in and rig up Doyon 141. 2. Install divertersystem. 3. Drill 9-7/8" hole to 7-5/8" surface casing point according to directional plan. . Run and cement 7-5/8" casing, using stage collar placed approximately 200' MD below the base of the permafrost. Use lightweight lead cement in the first stage. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. . 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). 7. Drill 6-3/4" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). . Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. 12. Secure well. Rig down and move out. ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 325 Drillin_cl Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casin~t point 9.0-10.2 ppg 15-35 25-50 70-120' Drill out to TD 8.5- 10.0 ppg 12-24 15-30 45-60 10-25 15-40 5-7 9.5-10 _+10% 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillinq Fluid System- ITriple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser Pit 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 surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,660 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70- 0.11) -- 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be --2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. ARCO Alaska, Inc. Well Proximity Risks: The nearest well to 2N 325 is 2N 323. The wells are 25.9' from each other at a depth of 500'. Drillinq Area Risks: The primary risk in the 2N 325 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 9-5/8" 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. 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 325 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. We request that 2N 325 be permitted 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 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 ARCO Alaska, Inc. 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 3Y2" 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi8,636 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). ARCO Alaska, Inc. Structure : Torn Drill Site 2N Well : 325 Field : Torn Development Field Location : North Slope, Alaska _~~ <- West (feet) 5200 ~800 4400 4000 5800 5200 2800 2400 2000 1600 1200 800 400 0 ~-00 TARGET LOCATION: I TO LOCATION: I 1635' FSL, 184' FEL 2000 1755' FSL, ¢72' FELI ~TD - Casing Pt SEC. 33, T1ON, RTE SEC. 33, T10N, R7E ~"----'"--,~TARGET - Mid Bermuda TARGET %_.,~-~End Angle Drop TVD=5205 TMD=7610 ~ 6O0 0EP=4948 NORTH 1709 WEST ¢645 1200 C40~ ~~"~,9. g 800 ~oo 7 5/8 Casing P[-"~.~ ... :-' _ . Base West Sok Sands'"'7-~ 0 RKB ELEVATION 1¢9' Begin_Turn to Target_'"~..~70 - - ro~? .S~ So~.d~ 290.21 AZIMUTH ~o,~ of Permafrostl~) 0 400 4948' (TO TARGET) 7¢' FNL, 821' FEL ¢00 K0P TVD=700 TMD=700 DEP=0 ***Plane of Proposal*** SEC 3, T9N, R7E 800 4.00 8.00 OLS: 4.00 deg per 100 ft · 12.00 ~ENO INITIAL BUILO TV0=1071 TMD=1075 DEP=46 ~,B/ PERMAFROST TYD=I 199 TMD=1208 DEP=78 ~200 ~r / w SAK SNDS TVD=1245 TM0=1253 DEP=89 ~18.678EGIN TURN / CONTINUE BUILD TVD=1288 TMD=1300 OEP=lO1 h22.¢5 · --'--, ~. 26.29 OLS: 4.00 deg per 100 ft -+-- 1600 ~,~ .30.18 (D(D k34.08 41 94 "+- '%.-~" B / W SAK SNDS TVD=1997 TMD=2138 0EP=523 2000 '%. 49.84 (- '"'.. EOC TVD=2118 TMD=2332 DEP=674- Cl._ ~7 5/8" CSG PT 'rvo=2300 TM0=2649 DER=g35 f-~ 2400 =11 99 2800 · 5200 ~ MAXIMUM ANGLE I"-- 3600 ~ 55.06 D E G '-~o YV0=3762 TMD:5202 0EP:3027 5¢.15 DLS 3.00 Oeg Per 100 fi 4800 4-8.15 5200 TAR GET AN GLE c~ TV0=5368 TM0=7840 OEP=SI 10 TO -- CASING PT TVO=5509 TMD=8040 0EP=5252~ ~oo 45 DEG I , ~ I I I i I I I I II I I I I I I I I I I I I 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 Vertical Section (feet)-> Azimuth 290.21 with reference 0.00 N, 0.00 E from slot //525 creote,~ ~,~ ri~e For: BRASSFIELD Date plotted : 4-Auq-gB Plot Reference ;s 525 Vc~ion ~4. Coordinates are in feet reference slat ~25. True Ve~ical Depth~c RKB {Doyon I ~ 120 O 90 IARCO Alaska, Inc. ............. rn I Location : North Slope, Alaska West (feet) 51(] 480 450 420 390 360 330 300 270 240 210 180 150 120 90 60 ..tO 0 50 60 90 120 150 ~° ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' '~.. ~.. ~.' ' '~i.. ... ,, ,~,,,,,,, ,, ,¢,, ,, ,~,, ,, "., 1300 ',, ',. ,, ",~ 1600 3,30 ", 330 ,~o~......,,..,,,,,,,, "'",,,, "",,>~T "",,,, 4~°° 1 ¢00 ",,,, ',,,, ",,,, ',% 17e~,, '"~ 1200 '"" 1500~ 300 ,300 270 1 50'0% '"',, 1300 "% 1200 %,, '%,2500 ',,, "', 270 2000 1300 '"'.. '"', %,, '",. 16~b., '", '", ",, ",, ", ',, '-, ", 11 O0 ',,, 240 '"', '"', '% "", "", 220(~" 11 O0 \ ,,, 2,~0 ",. ',, ',, ',, ",. ", ~. ', 1400 1900 1400 '-, ",, '"' 11 O0 '", '" '" ~ '" "", ", \, "; 1 50[~", "', ", 1200 ',, ",~ 1200 ,,, .,, ,,, ,, ~ ,, 21o 2~o ~6oo "'... '",, "',, "',, '% ~i'~o \ 1~o0 '". "', '" "' " '" lOOO ,ooo 1300'",. ",, "'" "'" 140~)"' ""' 180 1500 1100 ", ", ",, 1000 "~ ",, ',, 1700 '",,",. 11 O0 "%, "',, %,, ~)000 ~ 7oo '"":::t ",,,, "',, '",,'",, ~ 50 1400 1200 '2.,,_ ' ,, "',,1300 ",,,",,, 1600 1000 .",',',,~ ',,, gOO ',,, 1906', '", 1500 120 1400 '~, 11 O0 1500 1000% '",, '",. 12001 '"" 1200 900 %,,, . ",,,, 800 ",, 'L'-, 1000 "11 O0 ", 90 1400 1 500 1 400 '""... 900'.;., '", x ". 1100 ", 1~oo ..,,,, ,,.,,!~oo'-,,~oo "",::,,, ~oo ',.,,700 '",.lOOO '",~ 1500 1200 ....... . ",. 1000 '"',,. 1200~ 800 'N:',,. ',,, ',, 1600 ,. 60 .o ....... --. ..... . ~oo .... .-~.,:~.~ 1200 1100 ......... 1100 '"",., §00 '"',,. 1100~ '"'"" 600 "' '" 800 '~ 1 , oo }...o.o... ., 30 .0. .................. !_1_?.0. ........ ~0 ................... L' ........... ~oo '~ ~'~'- ;~;~, "~ -8. o 0 900 .... ;,;,-~.-...' ....... '"< ..... "-. "~ 1300 1200 1100 1000 ouu "~0~ ....... 700 -- 900 _~_ u ..... "- :~ boo ~ ~ . ~ ,~oo ................................................ /uu .... "' .......................................... - ............... ~o ~ ......... - ....... -a~_~o ~ (~ 500 . ~ ~.~j~oo i~o~OO I I I i I I ] I I 510 480 4-50 4-20 3gO 360 330 .300 270 240 210 180 150 120 90 60 .:30 0 ,30 60 90 120 150 <- West (feet) A I Z creo~.d by r~xse For: BRASSFIELD Oat~ plaU. od : %--Au9--O8 Plot Re, ...... ;s 325 Vet,ion ,4. Coordino[es ~re in feet reference slot IStructure : Torn Drill Site 2N Well : 525 Field : Tarn Development Field Location : North Slope, Alaska A2CO Alaska, Inc. <- Wesi (feet) ""-., 1900 "' '"'.?b.,,25 C 0 ' " ", ' 2300 960 " " ', " 960 ", 1700 ", '- '" ',, 1 700 ', 880 8O0 720 I 6~o -ii- W-- 560 -I-- ~ 4.80 0 400 320 240 16O 8O ~ ...., ,,.. ,,,,,',,,, ,, ,, ,,, "'" '"' ' '~?~, ", ',, 1900 ... ,, 33ob~ .... soo '-,,-",, 2100 ",;q,,, ", %, ,,....... .,,,,.,,,:~<oo ,,,,,, ,,,~oo ~ ~ ~oo -...,..' ~,~ ~, ~;~.. ,,,, ,, ~o -~ -....,., .,~ ~q,, , ,,, ',, .......,,.. ,q,. ',,, ~oo '~, · . .. ~ ~ 6{0 ',,,.,, ........ ;;;; .......... "~%", '""::(~%oo '"'", "~ ..... -- ... ---..2500 ~ "' '" ~".' '" ..... ' '?" - ".,'".. >~. ",, ~ ~o -- 2300 "'"'- '""- ' " ' ' .......... -... ~o~' ....... ::::::::::::: ......... ~~oo '?,,, ',,,k~yo ",,?% .................... - ........ :::::::; ......... ~ ~,,,,,,,,,, ,,~,~,~ ?0% ~~ ~~--,_.~.~oo ~ ',,.,',,,, ',,,,',,;,,~o~,,~ ~o ............ ~oo ..... ~oo ~7o6 ...... ' ...... ~ ""?', ,,,, ,,,,~ ...................................... ,~o ~~'" '"" .... ' ..... " ~ "L", ............................ ~_~y ................. ~ ................ . ..... ... ..... ¥~,:,, ,,,, ...................... '~ 1700 1 . ' ~6o .................... ].~o ~s~;' ........................... 1700 ~o ......................................................................................... -LS~O_ ........ ~ 3oc A I Z O 560 '~' 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 <- West (feet) Created by rixee For: BRASSFIELD Oote plotted : 4-Au9-98 Plot Roi ...... is .325 Vcrs;on ~4. Coordinates ore tn feet reference slot ~f525, t~ I 1360 1280 1200 1120 1040 960 I 880 --I-- ,+_ 800 k_ 720 o Z 640 560 A CO Alaska, Inc. Structure : Tarn Drill Site 2N Well : 325 Field : Tarn Development Field Location : North Slope, Alaska <- West (feet) 480 I I I I I I I I I t I I I I I I I I I t I I I I I I I I I I I I I I I I i I I I I I '1~60 %, "'""-.. 1280 - '""'x 2100 """-.,.., 1200 3900 120 ~--._27oo ............ ---...2500 "~ .............. ' ...... -.~Z~° ~ lO4O ~l ..... ..2900 .......... 2700 " ....... ' ....... ............. ' .......... ' ........ ~ 2900 ................ ' ............. ~ ...... ~o ............. 2500 ............ "'~08._~ .......... ' ........ '~' 560 4~0 ~ 2700 400 ~ 2500 320 ~ ............................ Z!'"""-'-'"'"" O0 240 I [ I [ I I [ i I i I i i [ i [ i i i i 2500 I I I I I I I I I I I I I I I 960 880 Z o 800 720 400 ,320 240 <- West (feet) ARCO Alaska, Inc. Cr.~,.~ ~, ri.,. For: BRASSFIELD J / $Sr%¢lur'--~e'~ ~ar--~Orill Sit-~-2-~-- .... ~;ll: ~25 --- Plot ~d~ ..... i~ ~25 wr~m t4. I [Field : Torn Development Field Location : North Slope, Alask~ Coordin~[es ere in feet relcrcnce si0[ ~5. [ <- West (feet) i~ / 5800 5600 6400 5200 5000 4800 4600 4400 4200 4000 5800 5600 5400 3200 3000 2800 2600 2400 2200 2000 1800 1600 I I I I I t ~ 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 t I I I i I I , 1 2800 '-. ,,, ". ", ,,., ~ "-.,.,. "%? O0 ',,,, 41~0, 3100 ",, ~- ""-.. 31 O0 '"' '"' '" 250~" ~ '"',.... "",., "',,,3¢~, '"',,,...3900 "-,.. ",,., ',,., ',%2900 ~ '"...2900 '",, 290(5",,, "',, "'"-. '"-, ".~ 3)0o '"",,.. "',,, "",,, '"'%2700 .....3500 ',....2700 '"'.. %. ~'sqo ~ooo ~ ..... ~ ~ -.....,., ,,,,,,. ~,,.,,.,,,, .... -_ "'--..,~300 " " ", ", ...... "-. "-, ', '].g,.~O0 "",. 2500 ",. [~[,'",,~,,V-,X oo '"',. "'-, '"'~',"'"'r-~, ............ .~;..o.o.. :;~- .... ::-.-.-.-...-......~.o.o.. ...................... - ........ :::;;:;;; .... ~.~2o ' ........ ~?.oo ........ 2.'.' ....... ~oo .......... 2500 ...... :: ....... .......... 2700 ....... ' .... ,. 31 O0 ............. ' ....."-' ~ .',' ...... 2900 .......... 2'3oo::~-'~, ......... ?.? 2600 2400 2200 1800 1600 1400 1200 1000 800 600 ._..~.100 ~~~_~00 3700 :~ 3500 .................... 2700 ________ 3300 3100 ...................................... 2500 2900 2300 ~ 4OO 3500 3300 ~ ...................................... 3100 . 200 ............................................ 2900 ~ 5800 5600 5400 5200 5000 4800' 4600 4400 4200 4000 3800 3600 3400 3200 <- Wesf (feet) 2700 .......... '~ 2500 2~oU'--------~ ~ ....................................... ~oo' ~ I i i I I i i 1 I i ! i 5000 2800 2600 2400 2200 2000 1800 1600 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 ARCO Alaska lnc Structure : Torn Drill Site 2N Well : 525 Field : Tarn 0evelopmenf Field Location : North Slope, Alaska WELL PROFILE DATA o.oo a. ooo.~ o.oo 7~.~ o.oo 31o.~ 7oo.~ o.~ o.~ o.~ o.~ lO~.~ I~oo 310.~ ,070.73~1~7 7840.2645,~ 289.20 ~8.~ ~40 26 45.0028g~ ~g.4~ 1~.~1 32O 340 5O TRUE NORTH 0 10 2O 1100 310 1300 300 29O 280 27O .~500-'1- ~00 c,,.~.a by ~.,, For: BRASSFIELD Oot~ p~ottea : 5-~9--98 ~ot Relerence (s ~25 Vernon ~4. C~d~not~s ~e in fe~ r~er~e alot ~325. J / / /4O *' 1900 ! 50 ,j ~oo / ! I I ~ / ~1o070 ,~, 700 ~os°° 80 9O 26O · 25O lO0 110 240 120 2JO , 220 ',,, 200 190 180 130 140 150 160 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths ARCO Alaska, Inc. Tarn Dri11 Site 2N 325 clot #325 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Bake~ Hughes INTEQ Your ref : 325 Version Our ref : prop2850 License : Date printed : 5-Aug-98 Date created : 27-Feb-98 Last revised : 31-Jul-98 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 nT0 10 13.224,w150 18 56.568 Slot Grid coordinates are N 5911933.219, E 460771.631 Slot local coordinates are 74.28 S 821.40 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-9631'>,,343,Tarn Drill Site 2N PMSS <O-9690'>,,329,Tarn Drill Site 2N PMSS <0-12339'>,,341,Tarn Drill Site 2N PMSS <O-8239'>,,339,Tarn Drill Site 2N PMSS <O-10655'>,,337,Tarn Drill Site 2N PMSS <7090-10245'>,,337A,TarnDri11 Site 2N PMSS <0-7431'>,,345,Tarn Drill Site 2N PMSS <O-9553'>,,323,Tarn Drill Site 2N PMSS <0-9134'>,,313,Tarn Drill Site 2N PMSS <0-???>,,317,Tarn Drill Site 2N Tarn #1 (Straight Hole),,1,TARN #1 PMSS < 0 - 6150'>,,TARN#4,TARN #4 PMSS < 2250 - 7162'),,3A,TARN ~3 PMSS < 0 - 7650>,,Tarn#2,TARN #2 Closest approach with 3-D Last revised Distance 28-May-98 269.3 28-May-98 59.1 15-Jul-98 240.4 1-Ju~-98 207.8 18-Jun-98 179.4 29-Jul-98 179.4 21-Jul-98 300.0 23oJul-98 25.9 4-Aug-98 163.9 4-Aug-98 119.4 12-Aug-97 10996.3 12-Aug-97 6678.2 13-Jul-98 3593.0 14-Aug-97. 12856.8 Minimum Distance method M.D. Diverging from M.D. 300.0 300.0 400.0 400.0 100.0 100.0 300.0 300.0 300.0 300.0 300.0 300.0 100.0 100.0 500.0 500.0 725.0 725.0 600.0 600.0 8040.3 8040.3 725.0 725.0 3980.0 3980.0 1750.0 1825.0 ARCO Alaska, Inc. Tarn Drill Site 2N 325 slot ~325 Tarn Development Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 325 Version #4 Our ref : prop2850 License : Date printed : 3-Aug-98 Date created : 27oFeb-98 Last revised : 31-Jul-98 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 nT0 10 13.224,w150 18 56.568 Slot Grid coordinates are N 5911933.219, E 460771.631 Slot local coordinates are 74.28 S 821.40 W Projection ty~e: 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 a~ asterisk, e.g. 487.4* Object wellpath PMSS ¢ 0 - 7650>,,Tarn~2,TARN #2 PMSS < 2250 - 7162'>,,3A, TARN #3 PMSS < 0 - 6150'>,,TARN~4,TARN #4 Tarn #1 (Straight Hole),,1,TARN #1 319 Version #2,,319,Tarn Drill Site 2N 333 Version #2,,333,Tarn 347 Version #1,,347,Tarn PMSS <0-9631'>,,343,Tarn 330 Version #4,,330,Tarn PMSS <0-9690'>,,329,Tarn PMSS <O-12339'>,,341,Tarn 350 Version #1,,350,Tarn 335 Version #1,,335,Tarn 305 Version #2,,305,Tarn 303 Version #2,,303,Tarn 314 Version #1,,314,Tarn 311 Version #1,,311,Tarn 315 Version #1,,315,Tarn 301 Version #1,,301,Tarn 302 Version #l,,302,Tarn Drill Site 2N Drill Site 2N Drill Site 2N Drill Site 2N Drill Site 2N Drill Site 2N Drill Site 2N Drill Site 2N Drill Site 2N Drill Site 2N Drill Site 2N Drill Site 2N Drill Site 2N Drill Site 2N Drill Site 2N Closest approach with 3-D Minim=m Distance method Last revised Distance M.D. Diverging from M.D. 14-Aug-97 12856.8 1750.0 1825.0 13-Jul-98 )3432.3( 4340.0 7400.0 12-Aug-97 6678.2 725.0 725.0 12-Aug-97 10996.3 8040.3 8040.3 8-May-98 )82.6( 600.0 600.0 20-Jul-98 120.1 200.0 200.0 8-Mar-98 330.1 300.0 300.0 28-May-98 )267.7( 300.0 300.0 20-Jul-98 )73.8( 300.0 300.0 28-May-98 )57.0( 400.0 400.0 15-Jul-98 )239.9( 100.0 6893.9 11-Ju~-98 375.1 300.0 5480.0 8-Mar-98 150.1 300.0 300.0 8-Mar-98 300.0 600.0 600.0 8-Mar-98 330.0 400.0 400.0 21-Apr-98 151.9 725.0 725.0 21-Apr-98 208.6 750.0 750.0 8-Mar-98 150.0 700.0 700.0 8-Mar-98 360.0 300.0 300.0 8-Mar-98 345.0 400.0 400.0 304 Version #1,,304,Tarn Drably'Site 2N 306 Version #1,,306,TarnDri11 Site 2N 307 Version #1,,307,Tarn Drill Site 2N 308 Version #1,,308,Tarn Drill Site 2N 309 Version #1,,309,Tarn Drill Site 2N 310 Version #1,,310,Tarn Drill Site 2N 320 Version #1,,320,TarnDri11 Site 2N 334 Version #1,,334,TarnDrill Site 2N 327 Version #2,,327,Tarn Drill Site 2N 317 Version #3,,317,Tarn Drill Site 2N PMSS ¢0-8239'>,,339,Tarn Drill Site 2N PMSS <0-10655'>,,337,Tarn Drill Site 2N PMSS <7090-10245'>,,337A,Tarn Drill Site 2N 331 Version #7,,331,Tarn Drill Site 2N PMSS <O-7431'>,,345,Tarn Drill Site 2N PMSS <0-9553'>,,323,Tar~Drill Site 2N 321 Version #5,,321,TarnDrill Site 2N 326 Version #2,,326,TarnDri11 Site 2N 313 Version #5,,313,Tarn Drill Site 2N PMSS <0-9134'>,,313,Tarn Drill Site 2N 8-Mar-98 8-Mar-98 8-Mar-98 8-Mar-98 8-Mar-98 8-Mar-98 8-Mar-98 8-Mar-98 27-Mar-98 16-Jul-98 1-Jun-98 18-Ju~-98 29-Jul-98 28-Jul-98 21-Jul-98 23-Jul-98 23-Jul-98 31-Jul-98 13-Jul-98 3-Aug-98 315.0 285.0 270.0 255.0 240.0 224.8 58.5 135.1 30.4 )114.9( )206.0( )177.8 ( )177.8( )88.4( )298.6( )23.0( )48.3( )14.2( )168.3( )158.9( SO0.O~=' 600.0 700.0 700.0 300.0 600.0 775.0 300.0 400.0 775.0 400.0 300.0 300.0 300.0 400.0 500.0 700.0 400.0 700.0 725.0 500.0 600.0 700.0 700.0 300.0 600.0 775.0 300.0 2380.0 775.0 400.0 300.0 300.0 300.0 4400.0 500.0 700.0 2400.0 700.0 7760.0 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 August 10, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-325 Surface Location: 74' FNL 821' FEL Sec 3 T9N R7E, UM Target Location: 1635' FSL, 184' FEL Sec. 33, T10N, R7E, UM Bottom Hole Location: 1735' FSL, 472' FEL Sec. 33, T10N, R7E, UM Dear Commissioner Johnston, ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-325, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: & Gas Cons. com~.~issio,q A~s148 Oit Anchorage David W. Johns't~n Application for Permit to Drill Page 2 KRU 2N-325 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2N-325 Well File ARCO Alaska, Inc. Diverter Schematic Doyon 141 Flowline 21 ¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS I I 3" 5,000 psi WP OCT MANUAL GATE KILL LINE L 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / J / BSA 13-5/8" 5,000 psi WP.~L x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE ~~T~r~raulic actuator 13-5/8" 5,000 psi WP DRILLING SPOOL L-~~ w/two 3" 5M Dsi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams .... ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N 325 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9-7/8" hole to 7-5/8" surface casing point according to directional plan. , Run and cement 7-5/8" casing, using stage collar placed approximately 200' MD below the base of the permafrost. Use lightweight lead cement in the first stage. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. , 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). 7. Drill 6-3/4" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(0). o Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. 12. Secure well. Rig down and move out. ARCO Alaska, Inc. '~'~ DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 325 Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casin~l point 9.0-10.2 ppg 15-35 25-5O 70-120' 10-25 15-40 5-7 9.5-10 +10% Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillinq Fluid System- Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser Pit 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 surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 1,660 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. ARCO Alaska, Inc. Well Proximity Risks: The nearest well to 2N 325 is 2N 323. The wells are 25.9' from each other at a depth of 500'. Drillinq Area Risks: The primary risk in the 2N 325 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 9-5/8" 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. 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 325 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. We request that 2N 325 be permitted 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 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 ARCO Alaska, Inc. 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 31/2" 9.3 L-80 2 8rd EUE Mod 10,530 psi8,951 psi 10,160 psi8,636 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). 5200 A[ CO Alas , [nc Structure : Tarn Drill Site 2N Well : 325 Field : Tarn Development Field Location : North Slope, Alaska <- West (feet) /800 4400 4000 3800 3200 2800 2400 2000 1600 1200 800 400 0 r I I I ! I I f ' ~ ! { I I [ I I I ! I I I I ! r I I V 400 400 80O 1200 1600 200C 2400 2800 3200 3600 4000 4400 4800 5200 5600 TO LOCATION: 1755' FSL, 472' FEL SEC. 33, TION, R7E RKB ELEVATION 149' TARGET LOCATION: I 16.35' FSL, 184' FEL I SEC. 55, T10N, R7E Casing Pt GET - Mid Bermuda TARGET Angle Droo TVB=5205 gin An(~le Drop TMO=7610 DEP=4948 NORTH 1709 WEST 4645 7 5/8 Casing Pt ~ CC Begin Turn to Target '"'~Z0 Base of PermaFrost 290.21 AZIMUTH KOP TVD=700 TMD=700 DEP=O 4.00 8.00 OLS: 4.00 dea per 100 ft ~ i 2.00 ~END INITIAL BUILD TVD=~071 TMD=1075 DEP=46 ~,B/ PERMAFROST iR/D=~ 199 TM0=1208 DEP=78 ~T / W SAK SNDS ]-VD= 1245 TMD=1253 DEP=89 ~18.67BEGIN TURN / CONTINUE BUILD TVD=1288 TMD=1500 DEP=101 %22.45 ~, 26.29 OLS: 4.00 deg per t00 ft \~o.!8 k3~-.08 ~x'x.~'l'94 B / W SAK SNDS TVD=1997 TMD=2158 BEP=523 %. 4.9.84 "% EOC TVD=2118 TMD=2332 DEP=67¢ ~'"~ 7 5/8" CSG PT TVD=2500 TMD=2649 OEP=935 =1i99 MAXIMUM ANGLE 5 5.0 6 D E G '-~0 =0:~,62 ,,~0=~02 OE?:~02, 54.15 4-8.15 TARGET ANGLE c~ ,-vo:~ - TO - CASING PT TVD=5509 TMD=8040 DEN=5252v 45 DEG I ; i i i i i i t I i i 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4-400 4800 ,5200 4948' (TO TARGET) S~R~AC~LOCAT,ON: 74' FNL, 821' FEL ***Plane of: Proposal*** SEC 3, TgN, R7E Vertical Section (feet) -> zOO L 2000 ~ ! 6co ;- ! 200 L h 800 :L f400 i° L 400 DLS 3.00 Oeg Per i00 ft i 5600 Azimuth 290.21 with reference 0.00 N, 0.00 E from slot j/325 A I Z Ic~eot~e W ~i~ For: BRASSFIELD ['lore plottad : 4-Aug-§l] ,ueC~,~t~p~e in feet ret ....... ,or ,325. J Alaska, }S}ructure : lam Drill SHe 2N Well : 525 Field : Tarn Development Fle]d LocaHon : Nor}h <- West (feet) 510 480 450 420 590 360 530 300 270 240 210 180 1:50 120 90 60 5Q 0 3(] 60 §0 120 150 3.30 J ,~ ~ "., ",, '., 1300 ",, '", ", X " " - ' ' ", ', ' ", 1600 ~ ~ -~ 1400 ' 60;'",., '"",., "'"', '"", '"". 2400 '"', ~120~ "', ~.~ -330 ~oo-I "-... "',.... "'.... "',,,. '",....'".... ",,,,\' ~ ",,, ~ - ~°1~., ~. ~o'~,., ",,,,~oo ",,, ~oo ",,,, -,.,.,~oo "',,,, \ ',,. ,~oo ' I ......... ~ooo ~L~°° '", ", "' '". '", ",,,. \ '", -~° ....... '"', ""' '"', '"', ~;~ '"', \ '", t ....... - ........ "~. "'"'"'. '"' '"'.'"'..~o~;',, ~°° \ '"' I'~4° ' ....... ' ..... -.. 1 goo ~ 14.0~"-, '",, '", ",, ",,. ",, ~ ',,. 1400 2~o-~ ........ ' ....... ~ .... ",, ',, ", ,1oo '.. ",. ",. \ ', ~ "'-..1600 ....... --.~u "-,'",,1200 '" 'q'\! 50 0'"",. 'k k I, 1210 ,~o ] ........ ' ......... ~oo '~. "-,. ",,, ',,,",,, ",,,_~;'~,o \ (~ l. L'"~,. ......... 1500 .......... xx'x- 130(J"'-,"',, ',,,, ",,, ',',, ',,,..~O00k,,'O00 ' 1400 'ld(~ .... " ....... .... '"-.. '"'""~1100 "".]", "", 1000 "'% 1400"',,, "',,, ~ 150.I ....... .1..770 ........... "'.,..1.7..0.0 ~ "":"'. 1100 '"". "'"'. k'":')Q'00 ~ t' '- ' ..... ...,to.o. ...... ,~~ '"::'"'"'- ""' '"'"". ~oox ~oo 120~: 1200 '"'""' ,~ 11 O0 ,o ......... _.,,.o.o.. oo ............... ,?oo .... "'""--<. '''':<- 1:..,,,,ooo ".,,?oo -',,,,,,,, :?:,,,,,% -I ..... '~ '"'-.. "-..~ ..... "-,. ~.~ uuu',;... '- ',, '~,1100 ",. ",. ~ F 90 [ .......... ~ ...... ~,.1.1Q0 ""-. 1300'~x. 800 "":" ", ", ~700",, %,?00 ...................... ?_0.0 1200 ......... 1..2. .-....~.~.o..o. ..... -. '= ".~ e' ~oo o - ~ ~'~t~ ........... ' ........ "-"---. 8o~':'- '. ". ~"~ ~ ......... ' ..... 900 --.... _:?... 800 '.,. 600 '-,..,S0Q -~- F __ ' .............................................................................. 900 b'o ..... ::: ..... soo '~ ~ '8 / ,~o - ~D ........................................ 700 5~6-:~--~ ' ' ............. ~o 'e . ~.~ (_4 ;" ~' u~. L~ , ,.._, ,,_ _,, 510 480 4-50 420 590 360 5]0 ").~ .... i~ ' ,~.. ~ ~ ~ I "-] ~r--"-'-r'-'~l'----i T--'--T----'r ..... -'i .... ~ -~ ~' I -T- ~ ---r -'m"----~" 300 270 -.- ..... ~au 150 120 90 60 30 0 50 60 90 120 <- West {feel) A I Z Created by rixse For: BRASSFIELD Dote plotted : 4-Aug-98 J Plot Reference ;s 325 Version ~4. Coordinotes ore in feet reference slot ~325. ARCO nc. Structure : Tarn Drill Site 2N Well : 525 Field : Tarn Development Field Location : North Slope, Alaska <- West (feet) 1120 I I I I I I I I I I I I I I I I I I 1040 '.. 3700-. "¥. 1900 '"'. '~:,,2500'. 960 "-...... -. 2100 880 ". 800 720 640 560 480 -.... .. . -,...:;: :....:... . ,,,, ,, , "'- '", ,. 1 (300 " " 1040 " ' 2300 , ' 960 "'"'x 1700 1700 ', -.......... 3500'. ''~ , , '"' ', , 880 '"'",, ~3~;b("."~,,,, " ' 1goo',, ,~oo ,. ',. 2100"'::~q~,!700 ' 2100 ~-~ "::':':~",,,::.,'",,,, , ~ 1900 '"-. 1"~'6'~1.. 510,~.~;:... ,,,,, ' " 5oo ' I '"'~'", " 640 ............. '"":", 2&'~,,, , ' '"'-'"', '"'-C',, ", , Z " ........ ' ...... ,. 2700 ",h~ ,, , '" O ............ ~ ........... 1700 ""%~:, 1900 ":::):,%,21 O0 1900'~ 560 ........... ::: ........... '~ "%... ",:~-',,,,~oo "¢ .. ' .......... : .... .~?o "C."... Z~(i~. ~o '"-. "-.,. "'-.. ' ', '% '% ~"~.~. ......... ' ........ ',,,,",., 1~oo ,,,, % 2300 '"--. ' .... , ', "- ',. %. 2100 ...... ' .... -... ',,, ,. - ~uu ',, ' --" '- ,:. "- ' ' '"'-'% ], ~oo .......... :::::: .......... ~ooo 1~o~,,,~",,,,, ' ~,~;~,, ',,1 21oo .......... ~ ........... '"...'".. ~"~oo '",,, "':::..~7&,~ 1900.__._._ 2100... ' ..... "'""'1700190~' ........ ....... -.' ......... 1900 "'2100170C;~L[~'""'"-... ......... . ....... 1500 """1500""'"'× ","' ", "::'",300 "', 2',~{~'b',,, '"'x"l'i'' ~X'~ 240 1700 ' 1 3~'0'::,, '"', 17oo 1~'~'o ....... ' ..... .... 1~o 1~oo 1~o',~ .... '--U 1700 "" 1300 """--... 13~0'"'-.11 80 ..__l.~_Q_O_ ........ ~ ....... 400 320 240 160 8O 0 i i' '|-- i i i i i i -- i i i i i ' f ---I i i -- t i '- t i - i i---T'-T' i i --F-"--I i i i i i i i <- West (feet) Cr~oU~d b~ r~¢ For: BRASSFIELD J Bate plotted : 4-Aug-g8 J PIoi Reference Ja ~25 Version ~4. J Coordinates ore in feet reference slot ~325. J True Vc~icoJ Oepth~e RKB (Doyon 1~1).J 1360 1280 1200 1120 1040 960 880 800 720 640 56O 48O 400 320 240 a ka, JStructure : Tarn Drill Site 2N Well : 325 [Field : Tarn Development Field Location : North Slope, a <- West (feet) 1360 ~--.~ 2700 '"'"""---. 3700 ..... " ' .... . 3500 ~ ..... 2900 '"" ............................ . ......' ....... -.. 3300 '" .... --..2500 '--.. ~..~_~ 2700 '"'x 2100 500 '"""-,, 2300 ........................... ' .... ' ...... '""-- '"""--, 3100 .......... 2700 ......... ............. ' ......... .,. 2900 ............................................ ' ............ ..... ........ _ 2500 ............ '-'~'700._ A 2500 ~ ................ - ........... al aa 23O0 _210o I I I I I ~---- I I I I -1 I I I I I I--[--"-'--I T I I I I I I I -i I i I I i I i i i i I I I I 1280 1200 1120 1040 960 A 880 I Z 0 800 '-~ ,,,-...,, 72O 640 560 480 400 320 240 <- West (feet') A C O Al a,.,," k a, ii n c. Created by rixse For: BRASSFIELD I Structure : Torn Drill Site 2N Well : 525 Date plotted : 4-Aug-§8 motR~fer~ncels~25V*r~b~4. J Field : Tarn Development Field Location : North Slope, Alaska Coordinates are in fcct reference slot ~325. <- West (feet) I/~l'i~;I / 5800 5600 5400 5200 5000 4800 4600 4400 4200 4000 5800 3600 5400 .5200 3000 2800 2600 2400 2200 2000 1800 1600 t 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 4300 '--. '.. .. '.. ', "'- "x .3100". 41~'0 '" ".... ,... ".,.. %3100 ',,, ~ "-.,3100 "' "'- "' 2500", 2600 2600 '-...-. '.... . .... '..... ~ "'"-.... ",...., '",,,,~;~, 2400 ""-.~.3900 "-.... '.... "... '.,..2900 2400 ~ '-....2..900 "'... 290C~"... '""~0,0 "'""~ 3700 '"-.. '", '"x 3 2200 2200 "'... "'., "". "%.. 2700 '""'.~ 500 -,..2..700 '".. '".,. 3'5Q0 ~ooo q~ ~ "'--.. '"'... ,,;~i'..,'"'.. ~ooo '" ......... ~ .'530(3 '"" '"' "" "' .... 0'" ' .... --.. .... ",,, [~_~,,,, ,~,~8 u I ~aoo ".. - .. .. ~oo I-~a°° A -. -. . ,~auu ' ' OD "-.. '-,, ",, ', 'm,.I I ~......_'_'3..9.0..0_ 3300 ................... :ii:' .......5.!.0..0..._-1900 ~ "'""- '"q'~??O'x:~--~l Z 1600 .................... ' .........3 -'""-'"1'(~:::f':'-'' ...... .4. L?.O. ~~ ~0'.~. W.~[-16000 ................~5.7..0...05700 ............. .... ' ............4700....~ _ 2900 '-............ 25. '~¥0"'~ O0 '""-. '"5'9'> ~ 400 A 1400 ........ _ .{5.5. _0.?. .... .............. ':~::~: .-4.~.0..0. ~ '"'-.... '-~ 500 21 -~- 15o-...C~' 1200~ 1200 ............. ......3.1..0.0.. 2~D' ..... .'.:'.:'.-.-.:. ~5.7..0..0_ 1000 . 10130 ............ 2~oo ......... -'2 ......... ~oo ............ 25~}5 .... :::5: ....... 800 ........... 2700 ....... ' .... .. 3100 800 ~/-~...._4100 ............ - ......:::7 ...... 2900 .......... ~ 3900 3700 ,3500 .......... ?..5.00 600 ~ .............. 2700 ~00 ~ 600 3100 2500 2900 ........ 2500 27OO 2500 400 ~.oo 2 ~ oo------------ :5500 , 3300 '~1 nn ...................................... " .......... ~ ......1900 200 ........................ 29_0._O_ .........(_,~%__-] ..... : ...... q,~p~ 200 I I I I I I I I r I I I I .... 1---'---'-1 I I -----i'--'----'t--'--T--'---I ..... T-'----I T'--'3 I ---i--- Ii I I [ -'--'1-'-----1 .... I I I I 1 T 1 5800 5600 5400 5200 5000 4800' 4,600 44.00 4.200 4000 5800 3600 5400 3200 5000 2800 2600 2400 2200 2000 1800 1600 <- West (feet) ARCO A[aska [nc. Structure : Tarn Drill Site 2N Well : 325 Field : Tarn Development Field Location : North Slope, Alaska WELL PROFILE DATA r~ ~n o.oo o.oo o.~ o.~ o.~ o.~ o.~ o.oo ~ 7~.00 oco 310.c0 7c0,c0o,co o.co 0.~ 0.~0 End of 8uRd 107~.C015.C0310.~1070.73 31.57-37.~9 45.~5 ¢.00 ~'n Tur~ m T~ 15~.00 13,00510C01288.C~ 5~.81-82.00 IC0.72 O. CO ~d ~ Build/rum2551.a655.c62~a.20 21 I~.T2 ~5.~7-eoe.~ 67~,25 ~.~0 E~a ~f He~ 6S69.8255.06289.20 ~774.~7 1~4.19 -4197.0~ d~75.~ 0.~0 End cf Cr~urn 7205.0945.C0289.20 ~gB9.58 1~8.58 -4~39.~8 4732.12 3.00 [Tcrget 2N-325 ~d St- 7E09.74 ~5.C0289.20 5203.~t7Cg,41 -4~4~,~49~7.51 O.CO ~ of ~c~ 7840.2645.~0289.20 5558.00 17~5.Ol -47~6.7~ 5110.49 Z O. ~ E~d o~ Hda ~40 26 4500 28g 20 550g 42 1 ~g.51 -4g~0.52 5251 Bg 320 350 TRUE NORTH 0 340 I0 2O '~ ~1oo 310 1500 300 290 280 270 26 0 <3f~-~ · 25O · 1 oD 910 I [C~,oted ~ ,a,. For: BRASSFIELD Dote p~otted : 5-~§-98 Plot Reference ~s Cc~dinote9 are in feet re/er¢ce slot ~325. True VeAical Depths are reference , zo / / /4© ,/~9oo 50 /1100 / / / , / / ~" 70 ', ~" 100 700 ~?oo 80 0 1"8.,'3 2 9O i00 1!0 240 2{0 ,, , 22O ~ Normal Plane Trove 200 190 180 lng Cylinder- Feet 170 120 t50 160 t50 140 All depths shown ore Measured depths ARCO Alaska, Inc. Tarn Drill Site 2N 325 slot #325 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Bake~ Hughes INTEQ Your ref : 325 Version #4 Our ref : prop2850 License : Date printed : 5-Aug-98 Date created : 27-Feb-98 Last revised : 31-Jul-98 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 nT0 10 13.224,w150 18 56.568 Slot Grid coordinates are N 5911933.219, E 460771.631 Slot local coordinates are 74.28 S 821.40 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-9631'>,,343,Tarn Drill Site 2N PMSS <O-9690'>,,329,Tarn Drill Site 2N PMSS <0-12339'>,,341,Tarn Drill Site 2N PMSS <0-8239'>,,339,Tarn Drill Site 2N PMSS <0-10655'>,,337,Tarn Drill Site 2N PMSS <7090-10245'>,,337A,Tarn Drill Site 2N PMSS <0-7431'>,,345,Tarn Drill Site 2N PMSS <0-9553'>,,323,Tarn Drill Site 2N PMSS <0-9134'>,,313,Tarn Drill Site 2N PMSS <0-???>,,317,Tarn Drill Site 2N Tarn #1 (Straight Hole),,1,TARN #1 PMSS < 0 - 6150'>,,TARN#4,TARN #4 PMSS < 2250 - 7162'>,,3A,TARN #3 PMSS < 0 - 7650>,,Tarn#2,TARN #2 Closest approach with 3-D Minimum Distance method Last revised Distance 28-May-98 28-May-98 15-Jul-98 1-Jun-98 18-Jun-98 29-Jul-98 21-Jul-98 23-Jul-98 4-Aug-98 4-Aug-98 12-Aug-97 12-Aug-97 13-Jul-98 14-Aug-97 269 3 59 1 240 4 207 8 179 4 179 4 300 0 25 9 163 9 119 4 10996.3 6678.2 3593.0 12856.8 M.D. Diverging from M.D. 300.0 300.0 400.0 400.0 100.0 100.0 300.0 300.0 300.0 300.0 300.0 300.0 100.0 100.0 500.0 500.0 725.0 725.0 600.0 600.O 8040.3 8040.3 725.0 725.0 3980.0 3980.0 1750.0 1825.0 ARCO Alaska, Inc. Tarn Drill Site 2N 325 slot #325 Tarn Development Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ REPORT Your ref : 325 Version #4 Our ref : prop2850 License : Date printed : 3-Aug-98 Date created : 27-Feb-98 Last revised : 31-Jul-98 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is n70 10 13.224,w150 18 56.568 Slot Grid coordinates are N 5911933.219, E 460771.631 Slot local coordinates are 74.28 S 821.40 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 - 7650>,,Tarn#2,TARN #2 PMSS < 2250 - 7162'>,,3A,TARN #3 PMSS < 0 - 6150'>,,TARN#4,TARN #4 Tarn #1 (Straight Hole),,1,TARN #1 319 Version #2,,319 333 Version #2,,333 347 Version #1,,347 PMSS <0-9631'>,,343 330 Version #4,,330 PMSS <0-9690'>,,329 PMSS <0-12339'>,,341 350 Version #1,,350 335 Version #1,,335 305 Version #2,,305 303 Version #2,,303 314 Version #1,,314 311 Version #1,,311 315 Version #1,,315 301 Version #1,,301 302 Version #1,,302 .Tarn Drill Site 2N .Tarn Drill Site 2N ~Tarn Drill Site 2N .Tarn Drill Site 2N .Tarn Drill Site 2N .Tarn Drill Site 2N Tarn Drill Site 2N .Tarn Drill Site 2N .Tarn Drill Site 2N Tarn Drill Site 2N Tarn Drill Site 2N Tarn Drill Site 2N .Tarn Drill Site 2N Tarn Drill Site 2N Tarn Drill Site 2N Tarn Drill Site 2N Closest approach with 3-D Minimum Distance method Last revised Distance Diverging from M.D. 14-Aug-97 12856.8 1825.0 13-Ju1- 12-Aug- 12-Aug- S-May- 20-Jul- S-Mar- 28-May- 20-Jul- 28-May- IS-Jul- il-Jun- S-Mar- 8-Mar- S-Mar- 21-Apr- 21-Apr- S-Mar- 8-Mar- S-Mar- 58 )3432.3( 97 6678.2 97 10996.3 9s ) s2.6 ( 98 120.1 98 330.1 98 )267.7( 98 )73.8( 98 )57.0( 98 )239.9( 98 375.1 98 150 1 98 300 0 98 330 0 98 151 9 98 208 6 98 150 0 98 360 0 98 345.0 1750.0 4340.0 725.0 8040.3 600.0 200.0 300.0 300.0 300.0 400.0 100.0 300 0 300 0 600 0 400 0 725 0 750 0 700 0 300 0 400 0 7400.0 725.0 8040.3 600.0 200.0 300.0 300.0 300.0 400,0 6893.9 5480.0 300.0 600.0 400.0 725.0 750.0 700.0 300.0 400.0 304 Version #1,,304,Tarn Dr~ ,Site 2N 306 Version #1,,306,Tarn Drill Site 2N 307 Version #1,,307,Tarn Drill Site 2N 308 Version #1,,308,Tarn Drill Site 2N 309 Version #1,,309,Tarn Drill Site 2N 310 Version #1,,310,Tarn Drill Site 2N 320 Version #1,,320,Tarn Drill Site 2N 334 Version #1,,334,Tarn Drill Site 2N 327 Version #2,,327,Tarn Drill Site 2N 317 Version #3,,317,Tarn Drill Site 2N PMSS <O-8239'>,,339,Tarn Drill Site 2N PMSS <0-10655'>, PMSS <7090-10245'> ,337,Tarn Drill Site 2N ,,337A,Tarn Drill Site 2N 331 Version #7,,331,Tarn Drill Site 2N PMSS <0-7431'>,,345,Tarn Drill Site 2N PMSS <0-9553'>,,323,Tarn Drill Site 2N 321 Version #5,,321,Tarn Drill Site 2N 326 Version #2,,326,Tarn Drill Site 2N 313 Version #5,,313,Tarn Drill Site 2N PMSS <0-9134'>,,313,Tarn Drill Site 2N 8-Mar-98 8-Mar-98 8-Mar-98 8-Mar-98 8-Mar-98 8-Mar-98 8-Mar-98 8-Mar-98 27-Mar-98 16-Jul-98 1-Jun-98 18-Jun-98 29-Jul-98 28-Jul-98 21-Jul-98 23-Jul-98 23-Jul-98 31-Jul-98 13-Jul-98 3-Aug-98 315.0 285.0 270.0 255 0 9.40 0 224 8 58 5 135 1 30 4 ) 114.9 ( )206.0( ) 177.8 ( ) 177.8 ( )88.4( )298.6( )23.0( )48.3( )14.2( )168.3( )158.9( 500.0 600.0 700.0 700.0 300.0 600 0 775 0 300 0 400 0 775 0 400 0 300 0 300 0 300.0 400.0 500.0 700.0 400.0 700.0 725.0 500.0 600.0 700.0 700.0 300.0 600.0 775.0 300.0 2380.0 775.0 400.0 300.0 300.0 300.0 4400.0 500.0 700.0 2400.0 700.0 7760.0 ARCO Alaska, Inc. .- Post Office Box 100360 Anchorage, Alaska 99510-0360 August 10, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-325 Surface Location: 74' FNL 821' FEL Sec 3 TgN R7E, tiM Target Location: 1635' FSL, 184' FEL Sec. 33, T10N, R7E, MM Bottom Hole Location: 1735' FSL, 472' FEL Sec. 33, T10N, R7E, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-325, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: R[C[ VED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AUG "/2 ~998 Alaska 0ii & Gas Cons. Commission Anchorage David W. Johns~'on Application for Permit to Drill Page 2 KRU 2N-325 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2N-325 Well File RECEIVED AJaska 0ii & G-as 00ns. O0~r~issi0~ Anchorage · WELL PERMIT CHECKLIST COMPANY FIELD & POOL INIT CLASS ~)~_...,' //- O,~ ~ ADMINISTRATION WELL NAME,,,~_~ ~ ',~ 2~- .~ PROGRAM: exp [] dev~ redrll [] serv [] wellbore seg II ann. disposal para req ,,,. GEOL AREA ~4::,;/___.~ UNIT# ///~"~3, ON/OFF SHORE ENGINEERING APPR DATE 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 ........... N 14. Conductor string provided ................... ~ N 15. Surface casing protects all known USDWs ........... (~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... N 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... ¢.~ N 19. Casing designs adequate for C, T, B & permafrost ....... fLY~ N 20. Adequate tankage or reserve pit ................. ~ N 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. (~ N 23. If diverter required, does it meet regulations .......... ~Y) N 24. Drilling fluid program schematic & equip list adequate ..... (~ N 25. BOPEs, do they meet regulation ................ (~ N 26. BOPE press rating appropriate; test to "~oOC3 psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ (~ N 28. Work will occur without operation shutdown ........... 09 N 29. Is presence of H2S gas probable ................. Y N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y ~ 31. Data presented on potential overpressure zones ....... ~.v./"N.. . .-~ 32. Seismic analysis of shallow gas zones ............. ~Y N 33. Seabed condition survey (if off-shore) ............. J Y N 34. Con. tact.nam, e/phone for weekly progress repods ....... / Y N lexploratory only] s.. ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; r~ N (D) will not damage producing formation or impair recovery from a ~ N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. (~ N APPR DATE pEO.~¥: ENGINEERING: UlC/Annular COMMISSION' BEW WM SJSl JDH / ¢ RNC ' ";', ~ co Os M:chel~list rev 05~29~98 dlf: C: \msof fic¢:\wordian\diana\cl mcM i,~;t ,, ......... Plmsc note that ans' disposal of fluids gcncratcd from this drilling operation which a~r~pumped down the surface/production casing annulus of a pcrmirtcd existing well on Drill Sitc'k~ mus~ comply xvith thc rcqu~rcmcnts and limitations of 20 AAC 25.080. Approval of this pcrrn~t to drill docs not authorize disposal of drilling xxastc in a xolume greater than 35.000 barrels through thc annular space of a single wcll or for a period longer than one year. Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilli~ Services LIS Scan Ut ty Tue Dec 22 16:20:33 1998 Reel Header Service name ............. LISTPE Date ..................... 98/12/22 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/12/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical 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: OPER3tTOR 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 2 AK-MM- 80377 G. GRIFFIN HEIM/BURLEY 1ST STRING 2N-325 501032026900 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 3 09N 07E 74 821 148.80 147.30 120.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2NDJSTRING 3RD.STRING PRODUCTION STRING REI~KS: 16.000 108.0 9.875 7.625 2661.0 6.750 8182.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. 2. ALL DEPTHS ARE MEASURED (MD) DEPTHS UNLESS OTHERWISE NOTED. 3. DEPTH SHIFTING/CORRECTION IS WAIVED AS PER THE E-MAIL FROM DEDE SCHWARTZ FOR DOUG HASTINGS ON 10/22/98. MWD IS PDC. 4. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 5. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA R3~Y (DGR), PHASE-4 ELECTROMAGNETIC WAVE RESISTIVITY (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). 6. SECTION 7640'MD, 5157'TVD TO 8025'MD, 5374'TVD IS CONTROL-DRILLED AT 100 FT/HR FOR NUCLEAR LOG QUALITY. 7. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8182'MD, 5,459'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (RESISTIVITY). TNPS = SMOOTHED COMPENSATED NEUTRON POROSITY. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT. CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT. SBD2 = SMOOTHED BULK DENSITY (BEST BIN). SC02 = SMOOTHED STANDOFF CORRECTION (BEST BIN). SNP2 = SMOOTHED NEAR ONLY PHOTOELECTRIC ABSORPTION FACTOR (BEST BIN). COMPENSATED THERMAL NEUTRON POROSITY PROCESSING PARAMETERS: FIXED HOLE SIZE: 6.75" MUD WEIGHT: 9.1 TO 10.0 PPG MUD SALINITY: 500-750 PPM CHLORIDES FORMATION WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEDNDER FILE NUMBER: EDITED~MERGED MWD Depth shifted and clipped cuz Js; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE ROP GR FCNT NCNT NPHI DRHO RHOB PEF FET RPD RPM RPS RPX $ STUART DEPTH 2550 0 2580 5 2653 5 2653 5 2653 5 2655 0 2655 0 2655 0 2660 5 2660 5 2660 5 2660 5 2660 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: STOP DEPTH 8182 0 8089 5 8060 5 8060 5 8060 5 8076 5 8076 5 8076 5 8096 5 8096 5 8096 5 8096 5 8096 5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 2675.0 8182.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD OHMM 4 1 68 28 8 CTFA MWD CNTS 4 1 68 32 9 CTNA MWD CNTS 4 1 68 36 10 RHOB MWD G/C3 4 1 68 40 11 DRHO MWD G/C3 4 1 68 44 12 PEF MWD BARN 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 Name DEPT ROP GR RPX RPS RPM RPD FET CTFA CTNA RHOB DRHO PEF NPHI Min 2550 2253 55 37 27 1 61 0 25 11 77 33 92 0.1 150.21 15420.6 1.08 -1.31 0.08 11.77 Max 8182.5 5459.44 234.39 2000 1522.92 50.93 53.34 2 1086.3 43817 3.06 0.67 11.57 50.93 Mean Nsam 5366.25 11266 3857.36 11266 120.87 11019 5.94752 10873 257.548 11265 37.4198 10815 41.6785 202 1.05 21 245.421 10815 25574.1 10815 2.34303 10844 0.0982728 10844 2.24929 10853 37.4198 10815 First Reading 2550 2550 2580.5 2660.5 2550 2653.5 2956 2651 2653.5 2653.5 2655 2655 2650.5 2653.5 Last Reading 8182.5 8182.5 8089.5 8096.5 8182 8060.5 4450.5 2661 8060.5 8060.5 8076.5 8076.5 8076.5 8060.5 First Reading For Entire File .......... 2550 Last Reading For Entire File ........... 8182.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEA/DER FILE NUMBER: 2 R3kW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 2580.5 FCNT 2653.5 NCNT 2653.5 NPHI 2653.5 DRHO 2655.0 STOP DEPTH 8089.5 8060.5 8060.5 8060.5 8076.5 RHOB 2655 0 PEF 2655 0 · FET 2660 5 RPD 2660 5 RPM 2660 5 RPS 2660 5 RPX 2660 5 ROP 2675 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 CNP SLD $ 8076 5 8076 5 8096 5 8096 5 8096 5 8096 5 8096.5 8182.0 ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN 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 STA/XrDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 17-SEP-98 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD 10.87 MEMORY 8182.0 2675.0 8182.0 53.5 57.3 TOOL NUMBER P1087GRM4 P1087GRM4 P1087GRM4 P1087GRM4 6.750 6.8 LSND 9.80 45.0 8.5 450 6.4 2.600 1.700 3.200 4.100 46.1 .5 Data Specification Block Typ~ ...0 Logging Direction ............ ,...Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 NPHI MWD 2 PU-S 4 1 68 32 9 CTFA MWD 2 PU-S 4 1 68 36 10 CTNA MWD 2 PU-S 4 1 68 40 11 RHOB MWD 2 PU-S 4 1 68 44 12 DRHO MWD 2 PU-S 4 1 68 48 13 PEF MWD 2 PU-S 4 1 68 52 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI CTFA CTNA RHOB DRHO PEF Min 2550 0.02 37 27 1 52 1 54 1 53 1 61 0 31 11 77 150 21 15420.6 1.08 -1.31 0.08 First Max Mean Nsam Reading 8182 5366 11265 2550 1522.92 254.264 11265 2550 234.39 120.87 11019 2580.5 1889.79 5.21624 10873 2660.5 2000 5.80734 10873 2660.5 2000 6.0706 10873 2660.5 2000 5.94752 10873 2660.5 11.01 0.867072 10873 2660.5 50.93 37.4198 10815 2653.5 1086.3 245.421 10815 2653.5 43817 25574.1 10815 2653.5 3.06 2.34303 10844 2655 0.67 0.0982728 10844 2655 11.36 2.2421 10844 2655 Last Reading 8182 8182 8089 5 8096 5 8096 5 8096 5 8096 5 8096 5 8060 5 8060 5 8060.5 8076.5 8076.5 8076.5 First Reading For Entire File .......... 2550 Last Reading For Entire File ........... 8182 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LIsTpE pate ..................... 98/12/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/12/22 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Services Technical Services Physical EOF Physical EOF End Of LIS File
