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Home My WebLink About200-210ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 1R-03A 50029214060100 2000210 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from jaime.bronga@conocophillips.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: AOGCC Notification: KRU 2L-317 PTD (200-210) Suspected IA Integrity Date:Monday, April 7, 2025 1:46:18 PM Attachments:AnnComm Surveillance TIO for 2L-317A.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Monday, April 7, 2025 1:07 PM To: Automation, AK Wells <akwellsautomation@conocophillips.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: AOGCC Notification: KRU 2L-317 PTD (200-210) Suspected IA Integrity Well Name: 2L-317 Facility: CPF2 PTD: 200-210 Well Type: Injector AA Number (if applicable): N/A Internal Waiver (Yes/No if applicable): N/A Type of Issue: Suspect Integrity Maximum Pressure (if applicable): N/A Date of Occurrence (if applicable): 4/7/2025 Hi Chris, KRU 2L-317 (PTD 200-210) is a WAG injection well currently on produced water injection. The IA pressure is falling off after being charged. CPAI intends to investigate the cause of the IA pressure fall off for possible integrity issues with the well remaining on water injection. At the end of the monitoring period, CPAI will update you with a plan forward. Attached is the TIO plot, schematic, and bleed log. We have added some details to automate email tracking. Please let me know if you have any questions or concerns. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2L-317A 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2L-317 2025-02-21 353 566 213 IA Casing Strings Casing Description CONDUCTOR String O... 16 String ID ... 15.062 Top (ftKB) 35.0 Set Depth (f... 78.0 Set Depth (TVD) ... 78.0 String Wt... 62.58 String ... H-40 String Top Thrd WELDED Casing Description SURFACE String O... 7 5/8 String ID ... 6.875 Top (ftKB) 39.0 Set Depth (f... 3,461.6 Set Depth (TVD) ... 2,316.7 String Wt... 29.70 String ... L-80 String Top Thrd BTC MOD Casing Description PRODUCTION 5.5x3.5 String O... 5 1/2 String ID ... 4.950 Top (ftKB) 31.8 Set Depth (f... 12,646.7 Set Depth (TVD) ... 5,780.1 String Wt... 15.50 String ... L-80 String Top Thrd BTC MOD Tubing Strings Tubing Description TUBING String O... 3 1/2 String ID ... 2.992 Top (ftKB) 29.6 Set Depth (f... 11,936.7 Set Depth (TVD) ... 5,358.9 String Wt... 9.30 String ... L-80 String Top Thrd EUE8RDMOD Completion Details Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Item Description Comment Nomi... ID (in) 29.6 29.6 -0.18 HANGER FMC GEN V 5M TUBING HANGER 3.500 514.8 513.9 7.13 NIPPLE CAMCO DS NIPPLE NO GO 2.875 11,827.7 5,294.8 53.74 SLEEVE BAKER CMU SLIDING SLEEVE 2.812 11,912.7 5,344.8 54.11 NIPPLE CAMCO D NIPPLE NO GO 2.750 11,919.8 5,348.9 54.14 LOCATOR BAKER LOCATOR 2.985 11,921.8 5,350.1 54.15 SEAL BAKER 80-40 CASING SEAL ASSEMBLY 2.985 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (sh...Type Comment 12,182 12,187 5,500.8 5,503.6 S-5, 2L-317 5/6/2001 6.0 IPERF HSD PJ 2506, 60 deg ph 12,187 12,207 5,503.6 5,515.1 S-5, S-3, 2L-317 7/22/2001 6.0 IPERF 2.5" HC/DP, 60 deg ph 12,207 12,227 5,515.1 5,526.7 S-3, T-2, 2L-317 7/22/2001 6.0 IPERF 2.5" HC/DP, 60 deg ph 12,227 12,247 5,526.7 5,538.4 T-2, 2L-317 7/21/2001 6.0 IPERF 2.5" HC/DP, 60 deg ph 12,247 12,267 5,538.4 5,550.1 T-2, 2L-317 7/21/2001 6.0 IPERF 2.5" HC/DP, 60 deg ph Notes: General & Safety End Date Annotation 7/18/2009 NOTE: CT Unable to mill past 12185' CTMD, possible liner damage (see WSR 7/18/09) 12/8/2009 NOTE: TAGGED OBSTRUCTION w/2" @ 12147' 11/8/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLEWell Config: - 2L-317A, 1/6/2012 4:31:27 PM Schematic - Actual TD (2L-317A), 12,655 PRODUCTION 5.5x3.5, 32-12,647 IPERF, 12,247-12,267 IPERF, 12,227-12,247 IPERF, 12,207-12,227 IPERF, 12,187-12,207 IPERF, 12,182-12,187 SEAL, 11,922 LOCATOR, 11,920 NIPPLE, 11,913 GAS LIFT, 11,869 SLEEVE, 11,828 GAS LIFT, 8,491 SURFACE, 39-3,462 NIPPLE, 515 CONDUCTOR, 35-78 HANGER, 30 Annotation Last Tag: CTMD Depth (ftKB) 12,185.0 End Date 7/18/2009 Annotation Rev Reason: FORMAT UPDATE Last Mod ... ninam End Date 1/6/2012 KUP KB-Grd (ft) 43.92 Rig Release Date 5/16/2000 Annotation Last WO: End Date 2L-317A H2S (ppm) Date Mandrel Details Stn Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Make Model OD (in)Serv Valve Type Latch Type Port Size (in)TRO Run (psi)Run Date Com... 1 8,491.0 3,777.1 72.56 CAMCO KBG 2-9 1 GAS LIFT DMY DCK 0.000 0.0 12/22/2000 2 11,868.8 5,319.0 53.92 CAMCO KBG 2-9 1 GAS LIFT DMY DCK 0.000 0.0 7/27/2001 ... TD Act Btm (ftKB) 12,655.0 Well Attributes Wellbore API/UWI 501032033601 Field Name TARN PARTICIPATING AREA Well Status INJ Max Angle & MD Incl (°) 76.76 MD (ftKB) 8,895.24 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2L-317A KUPARUK RIV U TARN 2L-317A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 2L-317A 50-103-20336-01-00 200-210-0 W SPT 5350 2002100 1500 1745 1745 1745 1745 280 300 300 300 4YRTST P Austin McLeod 8/3/2022 MITIA 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 2L-317A Inspection Date: Tubing OA Packer Depth 1070 2470 2405 2400IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220804184932 BBL Pumped:1.5 BBL Returned:1.5 Friday, September 2, 2022 Page 1 of 1 9 9 9 9 9 9 99 9 99 9 James B. Regg Digitally signed by James B. Regg Date: 2022.09.02 13:30:29 -08'00' • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Monday, May 7, 2018 7:42 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 2L-317A(PTD 200-210) Update Attachments: 2L-317A 90 day TIO trend 5-7-18.JPG; MIT KRU 2L-317A diagnostic MITIA 04-08-18.1sx Chris, KRU Tarn WAG injector 2L-317A(PTD 200-210)was reported April 7,2018 for suspect IA pressure decrease. A passinre MITIA, pack off tests,and draw down test were performed the following day. Throughout the subsequent monitor period the well exhibited no annular pressure anomalies and the previous suspect IA pressure decrease is attributed t• localized injection rate and temperature changes. CPAI intends to return the well to normal status at this time. A 90 •ay TIO trend and 10-426 are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. SCANNED ?' 4 Office phone: (907)659-7224 WELLS TEAM 1 S Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Saturday,April 7, 2018 8:51 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 2L-317A(PTD 200-210) Report of suspect annular communication Attachments: 2L-317A.pdf; 2L-317 1 year TIO trend 4-7-18.JPG Chris, KRU Tarn WAG injector 2L-317A(PTD 200-210)was reported for being out of normal operating differential pressure guidelines. After reviewing the TIO trend the well appears to have exhibited suspect IA pressure decrease. The plan is for DHD to perform initial diagnostics including an MITIA and pack off tests. Then the well will be placed on a 30 day monitor period. Correspondence will be made upon completion of the diagnostics and monitor period. A one year TIO trend and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons .Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 Art—LS / SCANNED • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 19, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile / Water Flow Log: 2L -317A Run Date: 9/26/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2L -317A Digital Data in DLIS /LAS format, Digital Log file, Interpretation Report 1 CD Rom 50- 103 - 20336 -01 Water Flow Log 1 Color Log 50 -103- 20336 -01� 1�1 Injection Profile Log 1 Color Log 50 -103- 20336 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907 - 273 -3535 klinton.wooWhburton.com ;1- J' Date: ; Signed: �i, s MEMORANDUM Tai Jim Regg P.I. Supervisor ~~ ~ 6~i3~t" FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 10, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L-317A KUPARUK RIV U TARN 2L-317A Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv ~~ Comm Well Name: KUPARUK RIV U TARN 2L-317A Insp Num: mitRCN100809165036 Rel Insp Num: API Well Number: 50-103-20336-01-00 Permit Number: 200-210-0 Inspector Name: Bob Noble Inspection Date: 8/8/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 2L-317A Type Inj. W ~ TVD 5368 IA 850 1830 ' 1780 1770 P.T.D 2002100' TypeTest SPT 'Test psi 1830 QA 350 375 375 ! 375 Interval 4YRTST P~F, P ~ Tubing 1100 1100 1100 1 ]00 - Notes: uliul, r~y'~#~~~ 1~~i Tuesday, August 10, 2010 Page 1 of 1 . . ~ ConocoPhillips Alaska RECEIVED AUG 2 9 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 20, 2007 d.Ðù~dJD Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AI< 99501 scANNED SE? {\ (; 2001 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the cònrluctor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped between August 12-13, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. ftÅ/~¿ ConocoPhillips Well Integrity Projects Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement DumDed cement date inhibitor sealant date ft bbls ft Qal 2L-305 198-240 SF N/A N/A N/A 1.7 8/13/2007 2L-307 198-256 10" N/A N/A N/A 8 8/13/2007 2L-311 203-155 15" N/A N/A N/A 9 8/13/2007 2L-313 198-219 15" N/A N/A N/A 5.9 8/12/2007 2L-315 198-218 23" N/A N/A N/A 5.9 8/12/2007 2L-317 200-210 SF N/A N/A N/A 4.2 8/12/2007 2L-323 198-251 9" N/A N/A N/A 3.4 8/12/2007 2L-325 198-209 24" N/A N/A N/A 9.3 8/12/2007 2L-327 207-008 20" N/A N/A N/A 6.8 8/12/2007 2L-329 198-225 24" N/A N/A N/A 6.8 8/12/2007 Date 8/13/2007 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor -:/" t! " ,O¡' }~i _ '<..c;cv " ' , \./IQ I "·7~¿ v" v, DATE: Wednesday, August 09, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L-317A KUPARUK RIV U TARN 2L-317A 0- 1-10 ~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv')g)Z- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U TARN 2L-3I7A API Well Number 50-103-20336-01-00 Inspector Name: Chuck Scheve Insp Num: mitCS060808 I 93533 Permit Number: 200-210-0 Inspection Date: 8/8/2006 ReI Insp N urn Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~, ; 2L-317A t I Well ¡Type Inj. I W i TVD 5350 i IA 1050 3010 2990 2990 i i I I I I I ¡--'---~ I -~ P.T. i 2002100 ITypeTest I SPT ! Test psi i 1500 OA I 400 I 450 450 450 1 . ,I .-----.J. t I Interval 4YRTST P/F P ..,/ Tubing I 2000 2000 , 2000 I 2000 I 1 , I Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. SCANNED f\UG 24 Z006 Wednesday, August 09, 2006 Page I of I MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg p P.I. Supervisor 'K er l III el( 05' DATE: Wednesday, November 09, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L-317A KUPARUK RIV U TARN 2L-317A é).po ~ t}.{O FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv Sße- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U TARN 2L-317A API Well Number 50-103-20336-01-00 Insp Num: mitCS051l08062907 Permit Number: 200-210-0 ReI Insp Num Inspector Name: Chuck Scheve Inspection Date: 1116/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -Well 2L-31'7A ¡Type Inj. [Ñ- I TVD I -5-35õ~ -1 250 J 2150 ----:iÕ50 I 205Ö--- I 1------ :~~~a:002:~~:pe:re;;s~p~Î-1-13J70~~~g~::- ~-~:-I :{----~: - F --~ ~~ ----- --- ____ _ _ __ ____ ___------'--L--___ _ __L__ ...L____ _ _____ ___ __----L...________ Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. SCANNE[\ NOV 1 ð 2005 Wednesday, November 09, 2005 Page I of I PHILLIPS PHILLIPS Alaska, Inc. ~~~~ A Subsidinry of PHILLIPS PE7ROLEUM COMPANY Post Office Box 100360 Mchorage, Alaska 99510-0360 J. Putnam +~ ~y Phone (907) 265-6~'p-~~~~~~ .i~~ ~. ~! L~U~ ~zc•;;~ December 13, 2001 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7"' Avenue Suite 100 Anchorage, Alaska 99501 hand delivered Subject: 2L-317A Injection Well Status (API # 50-103-20336-01) Dear Mr. Maunder: ~ ~`c~-iC~ n~ „ €~ ~`_ ~. , . ~ [J i~~ ~ ~ry t~ . ,°t ; .~Pe~ ,A.d~ ~. ~~ ~~ ~~~ ~,F -..~~c.,r , ~_ ~ ~ ~ .~, . ~ ~~ ~ ~~,:.~~ . ~- g ~ ~~ ~ ~~~~~ ~~~ This letter is concerning injector 2L-317A which was completed in December 2000. The cement bond log showed poor cement bonding in and immediately above the Bermuda interval. Phillips proposed that a Water Flow Log (WFL) be run to demonstrate zonal isolation. A meeting was held on April 19, 2001 to review with the AOGCC. The attached letter (originally sent via email) details the agreement that was made. The following list summarizes the work that has been completed to date: 12/13/00: Spud 2L-317A 12/24f00: Rig released 03/04/01: SCMT run to show cement quality, log shows poor bond 04/19/01: Phillip's representatives meet with AOGCC to discuss plan OS/06/01: Limited perforations shot prior to WFL OS/06/01: Initial WFL ran, zonal isolation confirmed 07/22/01: Final perforations shot to complete the well as a water injector 07/28/OL• Well put on water injection (injecting ~ 1500 BWPD) 11/28/01: Second WFL ran, zonal isolation confirmed after 4 months of continuous injection With the results of the final WFL (attached) confirming zonal isolation, Phillips requests that 2L-317A be put on normal MWAG operations. The final sundry form has already been completed and submitted to the AOGCC prior to this letter. If you have any questions regarding this matter, I can be reached at 265-6970. Sincerely, ~ j ~t,.1~~ (S] ~ _ ,. '-~ /~ °-'~aSOII PTILriaIri Tarn Coordinator PAI ~~~ls~~ M ~~ ~~~ ~. ~ ~~~~ ~IasKa Oif ~ Gas ~ons~ t;omm-ssio~~ Anchaaq~ Jason Putnam 07/02/01 01:39 ;,, ;- . ` To: tom maund cc: Subject: Tarn Devel Mr. Maunder, PM er@admin.state.ak.us, bob_crandall@admin.ak.us opment - AOGCC Meeting Notes (06/13) We are ready to move forward on the P to I conversion o# 2L-305 and also the final weli work (perforations) to begin injecting water into 2L-317A. i will drop off the 403 Sundry Forms for both wells along with the additional requested information to your office today. If you have any questions please don't hesitate to call. Thank you, Jason D. Putnam ~ECEI ~~ F Tarn Surveillance Engineer ~ Phillips Alaska Inc. (907) 265-6970 JuL ~ 2,~(-(, ~ - Forvvarded by Jason Putnam/PPCO on 07/02/01 01:43 PM - A~~ka Oil &~ Jeff A Spencer An ~' ~0mmission ~ 06/18/01 05:39 PM t~ To: tom_maunder@admin.state.ak.us, bob crandall@admin.ak.us, Brian D NoeUPPCO~Phillips cc: Jason Putnam/PPCO@Phillips, Satellites Prod Engrs/PPCO@.Phillips, Stephen Bross/PPCO@Phillips ~ Subject: Tarn Development - AOGCC Meeting Notes (06/13) Gentlemen, Please find below a summary of what was discussed at last Wednesday's (06/13) meeting regarding Tam Field development. Attendance: AOGCC Phillips Tom Maunder Jeff Spencer Bob Crandall Brian Noel We112L-317A: (New Injection Well) Because a CBL showed poor cement bonding in and immediately above the Bermuda interval, an alternative method was proposed by Phillips to demonstrate zonal isolation using a Water Flow Log (WFL). After reviewing the CBL, cement job data and other completion related information, the following plan was agreed to during an April 19th meeting. Note: Provide a detailed procedure, wellbore schematic, copy of CBL, details on the initial 2L-317A cement job, and a completed Sundry Form 403 to AOGC~ prior to commencing any field work. 1. Pertorate a 5' interval approximately 70' MD below the top of the Bermuda interval (T3). Projected depths of the initial perFs are expected to be 12182-12187' MD. 2. Establish injection into the weil using water from a pump truckltransport at 1-2 BPM. ~ Note: The expected maximum water injection rate into 2L-317A is <3000 BWPD. 3. Run WFL to determine if there is any behind pipe upward flow out of the Bermuda in~erval. 4. Review WFL with AOGCC. If upward flow is detected above the Bermuda interval, determine an appropriate remedial fix. The WFL did not show any upward flow and was reviewed with AOGCC personnel on June 13th. Once we provide copies of the WFl and a completed Sundry Form 403, we can proceed with Steps #5, 6& 7, as outlined below. Note: Copies of the CBL, wellbore schematic and details of primary cement job were previously provided to AOGCC. 5. If no upward flow is detected, add perforations in the net pay intenrals below the initial perforations and complete well as an MWAG injector. Note: Leave well SI until water is available for injection. 6. Commence water injection at normal operating rates and monitor daily rates & pressures. Note: Injection rates and pressure data are to be reported on a monthly basis similar to other MIT waivered injection wells. 7. After 2-3 months of water injection, run another WFL log to confirm that injection is staying within desired intervaL AOGCC prefers WFL be run after 3 months of water injectior~. 8. If second WFL shows no upward flow or behind pipe channelli~g, commence normal MWAG operations after reviewing log with AOGCC. 2L-305 Conversions: Reviewed CBL on 2L-305 with AOGCC and it showed excellent bonding throughout the zone of interest. Approval to convert to MWAG injector will be forthcoming from AOGCC once we provide copies of the CBL, wellbore schematic, primary cemen# job information and a completed Sundry Form 403. Note: Future P-tal Conversion candidates showing good cement bonding can be submitted for approval directly to the AOGCC (with appropriate supplementary information as shown above). 2N-326 Reviewed CBL on 2N-326 with AOGCC and it showed what appeared to be contaminated cement throughout the zone of interest. The VDL indicated some bonding to the formation but either due to weak compressive strength of the cement and/or incorrect CBL tool settings, the bond to the pipe appeared relatively poor. So although the CBL provides some evidence of cement behind pipe and it was our recollection that the frac job went as planned, the AOGCC requested that we run a WFL to ensure no upward flow above the Tarn producing horizon (Bermuda interval). Therefore, the action plan for 2N-326 is as follows: 1. Establish injection into the well using water from a pump truck/transport at 4- 5 BPM. Note: The expected maximum water injection rate into 2N-326 is --7000 BWPD. f. Ta.'1Development - AOGCC Meeting Notes . . ',d. DO ,- d- \0 Subject: Tarn Development - AOGCC Meeting Notes Date: Thu, 19 Apr 2001 17:53:50 -0800 From: "Jeff A Spencer" <jspencer@ppco.com> To: tom _ maunder@admin.state.ak.us, bob _ crandall@admin.ak.us, steve_davies@admin.state.ak.us, "Brian D Noel" <bnoel@ppco.com> CC: "Jason Putnam" <jputnam@ppco.com>, "Satellites Prod Engrs" <nI177@ppco.com>, "Stephen Bross" <sbross@ppco.com> Gentlemen, Please find below a summary of what was discussed at today's meeting regarding Tarn Field development. Attendance: AOGCC Tom Maunder Bob Crandall Steve Davies Phillips Jeff Spencer Brian Noel scANNED SEP 1 3 2007 Well 2L-317A: (New Injection Well) Because a CBL showed poor cement bonding in and immediately above the Bermuda interval, an alternative method was proposed by Phillips to demonstrate zonal isolation using a Water Flow Log (WFL). After reviewing the CBL, cement job data and other completion related information, the following plan was agreed to. Note: Provide a detailed procedure, wellbore schematic, copy of CBL, details on the initial 2L-317A cement job, and a completed Sundry Form 403 to AOGCC prior to commencing any field work. 1. Perforate a 5' interval approximately 70' MD below the top of the Bermuda interval (T3). Projected depths of the initial perfs are expected to be 12182-12187' MD. 2. Establish injection into the well using water from a pump truck/transport at 1-2 BPM. Note: The expected maximum water injection rate into 2L-317A is <3000 BWPD. 3. Run WFL to determine if there is any behind pipe upward flow out of the Bermuda interval. 4. Review WFL with AOGCC. If upward flow is detected above the Bermuda interval, determine an appropriate remedial fix. 5. If no upward flow is detected, add perforations in the net pay intervals below the initial perforations and complete well as an MWAG injector. Note: Leave well SI until water is available for injection. 6. Commence water injection at normal operating rates and monitor daily rates & pressures. Note: Injection rates and pressure data are to be reported on a monthly basis similar to other MIT waive red injection wells. 7. After 2-3 months of water injection, run another WFL log to confirm that injection is staying within desired interval. 8. If second WFL shows no upward flow or behind pipe channelling, commence normal MWAG operations after reviewing log with AOGCC. Producer-to-Injector Conversions: lof2 4/20/01 1:03 PM ~'am Development - AOGCC Meeting Notes . ~ . . AOGCC prefers a CBL be run on all P-to-I conversion candidates prior to commencing injection. If the cement bond indicates inadequate cement behind pipe, a WFL may be used to demonstrate zonal isolation. Copies of the CBL (and WFL if run), wellbore schematic and cementing information should accompany the Sundry Form 403. Tarn Pool Rules & Area Injection Order Agreed to provide information to the AOGCC for the purpose of updating the Tarn Pool Rules and AIO. Since Tarn is reaching the stage of full development, the AOGCC would consider revising certain regulatory reporting requirements and other miscellaneous changes to more closely match current Kuparuk requirements. Agreed to provide a list of proposed revisions for AOGCC review, along with Tarn updates as noted above. 20f2 4/20/01 1 :03 PM . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . 1, Type of request: APPLICATION FOR SUNDRY APPROVALS Abandon Suspend _ Alter casing _ Repair well _ Change approved program Operational shutdown _ Plugging _ Pull tubing 5, Type of Well: 2, Name of Operator Phillips Alaska, Inc. 3, Address P. O. Box 100360 Anchorage, AK 99510-0360 4, Location of well at surface 192' FNL, 748' FEL, Sec. 22, T10N, R7E, UM (ASP: 460903,5927655) At top of productive interval 51' FSL, 2583' FEL, Sec. 24, T10N, R7E, UM (ASP: 469608, 5922580) At effective depth Development _ Exploratory _ Stratigraphic _ Service X At total depth 49' FNL, 2244' FEL, Sec. 25, T10N, R7E, UM 12. Present well condition summary Total depth: measured true vertical (ASP: 469947, 5922478) 12655 5785 feet Plugs (measured) feet Effective depth: measured 12646 true vertical 5780 Casing Length Size Conductor 105' 16· Surface 3461' 7.625" Production 11942' 5.5" Liner 705' 3.5· feet Junk (measured) feet Cemented 9 cu. Yds High Early 360 sx AS III Lite, 240 sx Class G 90 sx Class G 300 sx Class G Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth 3.5",9.3#, L-80 @ 11937' Packers & SSSV (type & measured depth) Baker Lin pkr @ 11922' , No SSSV 13. Attachments Description summary of proposal_X 14, Estimated date for commencing operation May 1, 2001 16. If proposal was verbally approved Detailed operations program _ 15. Status of well classification as: Oil Name of approver Date approved Service _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Steve Braá/e Title: Wells Team Leader FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrify _ BOP Test Location clearance Mechanicallntegrify Test _ Subsequent fonn required 10- ORIGINAL SIGNED BY D Taylor Seamount Re-enter suspended well _ Time extension Stimulate Variance Perforate _X 6, Datum elevation (DF or KB feet) RKB 35 feet 7, Unit or Property name ;J5}(} Other Kuparuk River Unit 8. Well number 2L-317A 9, Permit number / approval number 200-010 10, API number 50-103-20336-01 11. Field / Pool Kuparuk River Field/Kuparuk Oil Pool Measured Depth 105' 3461' 11942' 11942'-12647' ECEIVED '( (1 -; 2001 ¡ v ¡: Cons. Anchorage BOP sketch Gas Suspended _ True vertical Depth 105' 2317' 5362' 5780' Questions? Call Jason Putnam 265-6970 4/~1 Approval no. ..-"7 t..7/. /2 / Commissioner Date Form 10-403 Rev 06/15/88· L SUBMIT IN TRIPLICATE . . Jeff A Spencer 04/19/01 05:53 PM a To: tom_maunder@admin.state.ak.us, bob_crandall@admin.ak.us, steve_davies@admin.state.ak.us, Brian D Noel/PPCO@ Phillips cc: Jason Putnam/PPCO@Phillips, Satellites Prod Engrs/PPCO@Phillips, Stephen Bross/PPCO@Phillips Subject: Tarn Development - AOGCC Meeting Notes Gentlemen, Please find below a summary of what was discussed at today's meeting regarding Tarn Field development. Attendance: AOGCC Tom Maunder Bob Crandall Steve Davies Phillips Jeff Spencer Brian Noel WeIl2L-317A: (New Injection Well) Because a CBL showed poor cement bonding in and immediately above the Bermuda interval, an alternative method was proposed by Phillips to demonstrate zonal isolation using a Water Flow Log (WFL). After reviewing the CBL, cement job data and other completion related information, the following plan was agreed to. -./' ,/ /' .--- Note: Provide a detailed procedure, wellbore schematic, copy of CBL, details on the initial 2L-317A cement job, and a completed Sundry Form 403 to AOGCC prior to commencing any field work. \./'" 1. Perforate a 5' interval approximately 70' MD below the top of the Bermuda interval (T3). Projected depths of the initial perfs are expected to be 12182-12187' MD. 2. Establish injection into the well using water from a pump truck/transport at 1-2 BPM. Note: The expected maximum water injection rate into 2L-317A is <3000 BWPD. 3. Run WFL to determine if there is any behind pipe upward flow out of the Bermuda interval. 4. Review WFL with AOGCC. If upward flow is detected above the Bermuda interval, determine an appropriate remedial fix. 5. If no upward flow is detected, add perforations in the net pay intervals below the initial perforations and complete well as an MWAG injector. Note: Leave well SI until water is available for injection. 6. Commence water injection at normal operating rates and monitor daily rates & pressures. Note: Injection rates and pressure data are to be reported on a monthly basis similar to other MIT waivered injection wells. 7. After 2-3 months of water injection, run another WFL log to confirm that injection is staying within desired interval. 8. If second WFL shows no upward flow or behind pipe channelling, commence normal MWAG operations after reviewing log with AOGCC. ... . . Producer-to-Injector Conversions: AOGCC prefers a CBL be run on all P-to-I conversion candidates prior to commencing injection. If the cement bond indicates inadequate cement behind pipe, a WFL may be used to demonstrate zonal isolation. Copies of the CBL (and WFL if run), well bore schematic and cementing information should accompany the Sundry Form 403. Tarn Pool Rules & Area Injection Order Agreed to provide information to the AOGCC for the purpose of updating the Tarn Pool Rules and AIO. Since Tarn is reaching the stage of full development, the AOGCC would consider revising certain regulatory reporting requirements and other miscellaneous changes to more closely match current Kuparuk requirements. Agreed to provide a list of proposed revisions for AOGCC review, along with Tarn updates as noted above. . . PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY Date: April 25, 2001 File Code: We1l2L-317A Subject: 2L-317A: Initial Perforation/WFL From/Location: S. B. Andrus/D. E. Hensley NSK-14 Telephone: x7687, pgr 921, radio 243 To/Location: Central Wells Group NSK 69 (3 copies) WELL: PROPERTY CODE/ACTIVITY CODE: CAPITAL or EXPENSE BUDGET CATEGORY JOB SCOPE PRIMARY OBJECTIVE: ESTIMATED COST: 2L-317A/lnjector 35TN2L 1 LG/AK0070 Capital Perforate/Stimulate Perf/Perf Support Perforate/WFL $15,000 E-line Å Perforate Å Run WFL Objective: A CBL was conducted on Well 2L-317A which showed poor cement bond in and immediately above the Bermuda interval. Therefore, an alternative method to demonstrate zonal isolation using a Water Flow Log (WFL) has been agreed upon with the AOGCC. The primary objective of the WFL is to determine if there is any behind pipe UPWARD flow out of the Bermuda interval. Wellbore Condition: Well 2L-317A was recently completed as a 3-1/2" Monobore injector. The maximum hole angle is 77° at 4349' MD-RKB with an average tangent angle of 73°. The well was tagged at 12,529' MD-RKB on 02/04/01, dummy gun drifted to 12,497' MD-RKB on 02/06/01, and SCMT logged on 03/04/01. Therefore, no pre- PERF/WFL work is necessary. To assist in the tubing drift and cement bond logging run, the dummy valve was pulled from the GLM at 11869' MD-RKB and piping was installed to take returns up the inner annulus. This allowed slickline and electric line tools to be pumped down the well. The GLM was left open to allow tools to be pumped down the well if necessary. Job Scope: çQntact the Tarn DSO to have the radio repeater turned off prior t(u~ed',ºrating. . RU EL. Perforate Well 2L-317A per the recommended perforation procedure listed below. See attached log with perforation picks identified. . 10' Marker located @ 12,101' MD-RKB -2278749.doc Page 1 of 2 . . Perforation Specifications: Reference Log: Interval: Guns: Charges: SPF: Phasing: Orientation: Wellbore Fluid: Service: Estimated Reservoir Pressure: Sperry Sun MWD DGR/EWR log dated 12/19/00 12,182' - 12,187' MD-RKB (5') 2-1/2" HC/DP Deep Penetrating 6JSPF 60° None Diesel WAG Injection 2300 psi The well should be shot sli~htlv overbalanced w/200 psi WHP · After completing perforations, RIH with RST WFL to obtain a baseline temperature and static pressure pass prior to fluid injection. Log baseline pass from 12,187' MD-RKB to 12,000' MD-RKB. · Inject 300 BBLS of produced water at 1.5-2.0 BPM to establish injection into formation. · Continue injection of produced water at 1.5-2.0 BPM while RIH with RST WFL. Set up WFL tool to detect flow UPWARD behind pipe. Take WFL stops at 12,175' MD-RKB, 12,125' MD-RKB, 12,085' MD- RKB, and 12,055' MD-RKB. Top of Bermuda interval is at 12,112' MD-RKB. · If behind pipe UPWARD flow is detected between readings or any WFL stop appears to be anomalous, repeat the WFL at the requested stop locations. · If behind pipe UPWARD flow is detected between readings during repeat pass, WFL stops should be taken every 10' to determine the extent of the upward flow of water. · RD EL and freeze protect well with diesel. Cc: W. Dobson/G. Jones CPF-2 DS Lead Tech / Tarn DSO S. Bradley J. Spencer J. Putnam NSK-14 NSK-14 E-mail E-mail E-mail -2278749.doc Page 2 of 2 · WPHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY NIPPLE (514-515, OD:3,500) TUBING (0-11936, OD:3,500, ID:2,992) Gas Lift Mandrel/Dummy Valve 1 (8491-8492, OD:4.725) Gas Lift Mandrel/Dummy Valve 2 (11869-11870, OD:4,725) NIPPLE (11912-11913, OD:3,500) PROD CASING (0-11942, OD:5,500, Wt:15,50) SEAL (11921-11922, OD:4,000) LINER (11942-12646, OD:3.500, Wt:9,30) KRU· 2L-317A 2L-317 A API: 1501032033601 Well Tvpe: SVC Anole @. TS: Idea @. 1 SSSV Tvoe: I 1 Oria Comoltn: Anole @. TD:ldea @.S"z~p 12,'(. Annular Fluid:1 I Last W/O: Rev Reason:1 New Schematic; I JWP I Reference Ref Log Date: i Last Update: 1/8/01 I Loa: I I Last Tao: 1"Z.-,5Z.<¡ TD: 12665 ftKB I Last Tag Date: 7../'-1 lei Max Hole ~d~9 @ fìIN¡S Anole: Casing Strings - All Description Size I Top Bottom TVD Wt Grade Thread CONDUCTOR 16,000 1 0 78 78 62,58 H-40 WELDED SURF CASING 7.625 1 0 3461 3461 29,70 L-80 BTC MOD PROD CASING 5,500 1 0 11942 11942 15.50 L-80 BTC MOD LINER 3,500 i 119421 12646 12646 9.30 L-80 8RD EUE TubinQ StrinQs - All DescriDtion Size i TaD ¡Bottom TVD Wt Grade I Thread TUBING 3.500 I 01 11936 11936 9.30 L-80 18RD EUE Gas Lift MandrelsNalves St MD TVD Man I Man VMfr V Type VOD Latch Port TRO Date Vlv Mfr TVDe Run Cmnt 1 8491 8491 CAMCO KBG 2-9 Cameo DMY 1.0 DCK 0.000 0 12/22/00 I 2 11869 1869 CAMCO KBG 2-9 Cameo DMY 1.0 DCK 0,000 0 12/22/00 Other (pluQs, eQuip., etc.) - JEWELRY DeDth I TVD 1 TVDe DescriDtion ID 514 ! 514 1 NIPPLE Cameo 'DS' Nioole wINo-Go Profile 2.875 119121119121 NIPPLE Cameo 'D' Nioole wINo-Go Profile 2.750 i 119211119211 SEAL Baker 80-40 Casino Seal Assemblv 2.985 I I I ~S" II I I 1 ...... ~ . . TUBING Single Completion Assembly WELL: 2L-317 A DATE: 12/21/00 1 OF 1 PAGES PHILLIPS Alaska, Inc. # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS . , Nabor's 19E RT to LDS = 29.5B 29.58 FMC Gen V 5M 3.5" Hanaerw/3.5· 9.3# 8 rd Mod EUE DUD 2.85 29.58 Pup Spaee Out PuPs - 3.5· 9.3#8 rd EUE Mod 2 - 8' & 1 - 10' (26.25') 9.00 32.43 Jts363 -377 3.5·, 9.3#, 8rd EVE Mod tubino (15 jts) 473.37 41.43 Nipple Cameo 2.875" liDS' nipple No-go profile 1.57 514.80 Jts 109 -362 3.5", 9.3#, 8rd EVE Mod tubing ( 254 jts) 7969.08 516.37 XO 3.5· BTC Pin X 9.3#,8rd EUE Mod Box Pup 5.51 8485.45 GLM # 2 Camco 3.5" X l",KBG 2-9, w/Ðummy (BXB 8rd) w/ÐCK latch 6.63 8490.96 XO 3.5" BTC Pin X 9.3#, 8rd EVE Mod Pin Pup 5.71 8497.59 Jts 3 - 1 08 3.5",9.3#, 8rdEVE Mod tubing ( 106 jts) 3324.43 8503.30 SS Baker CMV Sliding Sleeve, 8rd EVE Mod w/2.812" Cameo profile 3.92 11827.73 Jt# 2 3.5",9.3#, 8rdEVE Mod tubino ( 1 jt) 31.61 11831.65 XO 3.5" BTC Pin X 9.3#, 8rd EUE Mod Box Pup 5.51 11863.26 GLM # 1 Cameo 3.5· X 1·, KBG 2-9, w/Ðummv (BXB 8rd) w/ÐCK latch 6.64 11868.77 XO 3.5· BTC Pin X 9.3#, 8rd EVE Mod Pin Pup 5.70 11875.41 Jt # 1 3.5",9.3#, 8rdEVE Mod tubino ( 1 jt) 31.63 11881.11 Nipple Cameo 2.75" liD" nipple No-go profile .96 11912.74 pup 6' Handling Pup Joint 3.5", 9.3#, 8rd EVE Mod BŒc 6.07 11913.70 Baker 4.5" OD x 2.985" ID Locator 2.00 11919.77 Baker 80-40 Csg Seal Assy, 4.00" od x 2.985" ID Locator (2.00') 14.95 11921.77 15' effective seal stroke w/3.5" 9.3#, 8rd EVE Mod Box 11936.72 TUBING TAIL @»»» 11936.72 Note: Tag top of CSR spaced out with locator sub 2' above CSR Ran total 377 jts 3-1/2",9.3#, 8rd EUE tubing. Up weight 87K. Down weight 37K, Blk weight 12K NABORS Rig # 7 9E Drilling SupeNisor: Rick Overstreet " Casing Detail s-øx 3-1/2" Production Casing . WELL: 2L-317 A DATE: 12/19/00 1 OF 1 PAGES Phillips Alaska, Inc. # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Nabor's 19E RKB to LDS = 31.85' TOPS 31.85 Hanger 5-1/2" GEN V CASING HANGER W / 5.5" 17# PUP 2.89 31.85 Jts. 1-283 5-1/2", 15.5#, L-80, BTC MOD (283 joints) 11877.10 34.74 Pup 5-1/2", 17#, L-80, BTC MOD 9.93 11911.84 Baker Csg Seal Receptacle (CSR), SIZE 80-40, 5-1 a' x 4" 20.59 11921. 77 XO 5-1/2" EUE Box x 3-1/2" 9.3# L-80 8rd EUE .58 11942.36 3 Pups 3-1/2" EUE Pups 9.3#L-80 8rd, 1-10.08', 1-10.59', & 1-11.00' 31.67 11942.94 jts 18-21 3-1/2" 9.3# L-80 8rd EUE (5 joints) 126.70 11974.61 MARKER 3- 1 /2" 9.3# L -80 8rd EUE 10.11 12101.31 Jts5-17 3-1/2" 9.3# L-80 8rd EUE (13 joints) 408.12 12111.42 Jt4 31/2" 9.3#L-80 EUE8rd(1 jt)-(Plug Catcher Top of this jt @ 12519') 31.46 12519.54 Weatherford Gemoco Float Collar 1.25 12551.00 Jts.1-3 3-1/2" 9.3# L-80 8rd EUE (3 joints) 93.27 12552.25 Weatherford Gemoco Float Shoe 1.18 12645.52 . Shoe @ 12646.70 TD 6 3/4" Hole @ 12655' (Rathole 8.21 ' Plua ( r in the top of joint #4 @ 12519 Joints #1 & 4 have stright blade centralizer installed Run 3.9x 6.5 straight blade centralizers on jts# 3,6,8,10 thru 21 = Total 17 Run 5.5" x 6.75" bow spring centralizers on jts# 3,6,9,12,15,18 21,24,27,30,33,36,39,42,45 & 48 = Totol16 Run 5.5" x 6.5" centering guides on Jts# 202,203,204,205,206, 272,275,278,281 = Totol9 **FiII on the fly and Top off every 5 joints **Baker Lok all connections from the Top of the FC down ** Break Circu at the shoe and every 2500' to TD Bring pumps up slowly, but do not exceed 4 BPM ## Torque first 10 and average torque to Run-Watch Diamonds Nabor's 79E Drilling SupeNisor: Dearl W. Gladden REMARKS: String Weights with Blocks: 180K Up, 40K Dn,25K Blocks. Ran 283 Joints 5-112" and 21 joints of 3 112" casing. Drifted 5.5" (4.825") & 3.5" (2.867") casing with plastic rabbit. Used Artie grade API modified No Lead thread compound on all connections. Casing is non-coated. Well Field Country Time 12121/00 22:47:51 22:48:00 22:55:12 23:02:24 23:09:38 23:18:48 23:24:00 23:31:12 23:38:24 2L-317 A Tam USA ... "- " " Cementing Job Report Client SIRNa. Job Date Phillips 20193714 12/2112000 10:47:51 PM støøe Volume T oIFIcIwnIIt '. .......,f I \ I \ --- -.. , , , , , I "- ..... "- " " " ..... I , I , I I , , I / ..-..- -_:;~.. ===~=.====...-- ---.._--~-----.. AOOO . 8 23:45:38 i ~ ~ 23:52:48 (iii ~ 8 I hh:mm:ss 0 - bill 310 0 ppg 0 --- bill 70 12121/00 23:55:52 . Mark 01 Schlumbergw r:.. .- --- 'START ACQUISITION .Sefoty MeetIng 'Stort CW 100 'Pressure TeslU.... ·R........ CWloo "SIart W""', Spacer , "lSlaae VoIume]=20,12 bÞ R_VoIume 'ISIaae VoIume]=10,09 bÞ Rese1VoIume SIIrt Mudpush '1SIaae Vclumel=24,o4Ø bÞ Rese1 Volume ' Stort Leed SIully .SI8rt Ten SIuny þ~~~I=32.82 bÞ 'Pump 2bbI H2O -RlglOOIspIece PRISM· V2.23 1.4_ , . tlementing Service Report , ~f...... /> ..... ···1';:/ Well I ........- .- ............ M"'" 2L 317 Prudhoe Bay, AK 12121/00 Field Formation NamelType Deviation I BIt SIze WeIIMD Well TVD TARN 0 . 6.75 in 12,646 ft Oft County StateIProvinc:e ~ AK Opsi ... O°F . O°F· 0 psiIft Rig Name DrIlled For I Service Via Oil Land Depth, ft Size, in Weight, IbIft Grade Thread Offshore z- Well c.... I Well Type 11942 5.5.·. 15.5 L80 Butt New Development 12652 3.5 9.3 L80 8rd DrlHing Fluid Type I Max. Density II Plastic Viscosity '":~:::::;::::~::::~:''''''' . ',v :';;;i';T~~~"~s;E;@@;¡1;;@!iii:,;~ii:;ili!¡;i :;:;:{:>}::~~:(I~~t:~~jI:~JJ;::f:: .;, Spud Mud o Iblgal 0 cp Depth, Size, in Weight, JbItt Grade Thread Service Line Job Type 0 0 0 Cementing ---- Cement Uner 0 0 0 . Max. Allowed Tubing Press... Mu. Allowed Ann. Press....1 WeIIHeed Connection 3500 psi o psi Double cement hea Top, ft Bottom, ft spt No. or Shots ToIIiIIlnIierYaI Service Ins1ruc:tions 0 0 0 0 0 ft AHoœtion = $56,575.00 0 0 0 0 DiMIeœr Materials + 2% = 45,392.72 0 0 0 0 0 in Total = $101,967.72 Tr_tDown Displacement Packer Type Packer Depth TN #-13789 Casing 289.2 bbl 0 ft Tubing Vol. Casing Vol. AnnuI8r Vol. 0penH0Ie Vol 0 bbl 290.3 bbl 0 bbl o bbl CasingITublng Secured ~ 1 Hole Volume Circulated prior to CementingO Casing Tools Squeeze Job Uti Pressure: psi Shoe Type: Float Squeeze Type PIpe Rotated 0 Pipe Reciproc:atl!d~ Shoe o.pth: 12646ft Tool Type: No. Cen1ra1lzers: 0 Top f'tugs: 1 Bottom Plugs: 1 Stage Tool Type: Tool Depth: Oft Cement Heed Type: Double Stage Tool Depth: Oft Tall Pipe SIze: Oin 12121100 19,00 '212'100 19,," 12122/00 .,," -_ '2519' ..,y...- .... 22:47 0 0 0 0 0 0 0 START ACOUlsmON . 22:48 O. 8.38 0.335 73.26 O. O. 0 Smety Meeting 22:52 O. 8.37 4.17 4.58 O. O. 0 Start ON 1 00 . 22:58 4.85 8.35 10.84 3526 4.85 O. 0 Pressure Test Unes· 23:00 4.87 8.39 12.51 233.5 4.87 0.723 0 Resume 0N1 00 23:05 19.61 11.-16 17.52 645.6 19.61 3.03 0 StartWe.ter Spacer 23:05 20.12 . 11.-16 17.69 641. 20.12 3.03 0 [Stage Volume]-20.12 bbl 23:05 20.12 11.46 17.69 641. . 20.12 3.03 0 Reset Volume 23:08 .30.21 11.2 21.03 682.2 10.04 3.03 0 [Stage Volume]-1 0.09 bbl . 23:08 30.21 11.2 21.03 682.2 10.04 3.03 0 Reset Volume 23:09 31. 11.21 21.36 595.2 0.686 2.89 0 Start Mudpush 23:17 54.89 11.74 29.2 677.7 0.05 3. 0 Reset Volume 23:17 54.89 11.74 29.2 677.7 0.05 3. 0 [Stage Volume]-24.48 bbl 23:17 55.9 12.-12 29.53 696. 1.05 3. 0 Start Lead Slurry 23:27 87.66· 15.-19 39.88 27.-17 32.82 O. 0 Start Tail Slurry 23:28 87.82 15.79 40.21 1 00.7 0.162 0.93 0 ResetVolume 23:28 87.82 15.79 40.21 1 00.7 0.162 0.93 0 [Stage Volume]-32.82 bbl 23:47 147. 16.07 59.73 430.4 59.39 2.93 0 Pump 2bbl H2O 23:55 151.8 8.93 67.23 O. 64.19 O. 0 Rig to Displace 23:55 152.8 8.44 67.73 315.9 65.1 0 0 Shutdown 23:55 152.8 8.014 67.73 315.9 65.1 0 0 End Job Dee 22,2000 WRS3 V3.o.sR Page .1 of 2 SIuny ~mum RMe Volume of Fluid Injected, bbI Mud S,** N2 3 4 o Breakdown Fluid 50 o Maximum Final Type DensIty L Obbl L I 00· c-t CIrculated III Surface? Volume of Washed Thru Pwrs . To 0 ft VoI_ 700 Mix WaW Temp Olblgal o bbI . 80 Rick Overstre Steve Doughten· 0 CIrcuJatlonl.ost ~ Job Completed '--., Dee 22;2000 WRS3 v3.o.sR Page 20f 2 e) . Ph11" AI k D 11" c r D 1 I IpS as a n mg . ernen mg etal S Well Name: 2L-317A Report Date: 12/2212000 Report Number: 30 Rio Name: Nabors 19E AFC No.: AKOO70 FI8Id: TARN Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout. 5-1/2 X 3-1/2 63/4 3461 12646 Central"'" . State type used, intervals coveflld and spacing Comments: 17 3.9 X 6.5 straight blade,16 5.5 X 6.75 bow spring. 9 5.S X 6.5 centering guides thru surface casing. MUd Weight: PV(prlor conel): PV(after cond): YP(prior cond): YP(after cond): Comments: ..' 9.6 15 15 13 12 LSND Gels before: Gels after: Total Volume Circulated: 4-6 5-7 480 Wash 0 Type: Volume: Weight Cotnn"lents: ARCO Wash 20 SA SpactIr 0 Type: Volume: Weight: Cotnmenls: MUDPUSHXL 30 11.0 .. .. . µ¡edc.ment 0 Type: Mix wtr temp: No. of Sacks: Weight: YIeld: Comments: G 75 90 13.0 1.99 Add~ives: .65%D800, .2%D046, 0.1%D065,8.O%D02O. 0.6%D167 "aI'Cell'lllnt 0 Type: Mix wtr temp: No. of Sacks: Weight Yield: Comments: G 75 300 15.8 1.2 Add~ives: . ... .... DS3, D6OO. D135, D800, D047,D065, Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: Comment$: 3.5 3 180K Reciprocation length: Reciprocation speed: Str. WI. Down: 40K Theoretical Displacement: Actual Displacement SIr. WI. In mud: ...... 284.2 284.2 Calculated top of cement: CP: Bumped plug: Floats held: O8te:12/22/00 yes yes Time:01:25 Remarks: Cement Company: Rig Contractor: Approved By: Dowell NABORS Rick Overstreet .} .! 2L-317 Tarn Development Well CemCADE Summary 5 1/2" 15.5# x 3 1/2" 9.3# Production Casing in6 3/4" Open Hole TD @ 12652' MD, 100% Excess in Open Hole. Crossover @ 11912' MD, Top Of Cement @ 10391' MD. 1021' of Lead Cement (500' above top of the Iceberg Formation @ 10891' MD) 1240' of Tail Cement (500' above the top of the crossover) REVISED 12/19/00 by KVT Pumpin2 SeQuence: 20 bbls CWl00 Wash, 10 bbls FW, 30 bbls MudPUSH XL @ 11.0 ppg, 32 bbls of 13 ppg Lead, Drop plug, 64 bbls of 15.8 ppg GasBLOK, Orop Plug, Oisplace (approx. 289 bbls.) Lead Slurry: Cement from 11412' to 10391' Volume: 2.00 x (11412'-10391') x (0.0835 ft3/ft) = Yield = 1.99 ft3/sk Total sacks = 170.5 ft311.99 ft3/sk = 86 sacks. Round up to 90 sacks 170.5 ft3 Composition: 13.0 ppg Class G wI 0.65%0800,0.2%0046,0.1 %0065,8.0%0020 & 0.6%0167 per lab testing @ 160 BHST, 130 BHCf - 3.5 to 4.5 hour thickening time Tail Slurry: Cement from 12652' to 11412' +80' shoe volume Volume: 5112" x OH: 2.00 x (11912'-11412') x (0.0835 ft3/ft) = 83.5 ft3 31/2" X OH: 2.00 x (12652'-11912') x(0.1817 ft3/ft) + (80') x (0.0488 ft3/ft) =272.8 ft3 Yield = 1.2 ft3/sk Total sacks = (83.5 + 272.8) ft3/1.2 ft3/sk = 297 sacks. Round up to 300 sacks Comoosition: 15.8 ppg GasBLOK wI Class G + 053, 0600, 0135, 0800, 0047, 0065, per lab testing @ 160 BHST, 130 BHCT - 3.5 to 4.5 hour thickening time CemCADE Summary: Pumoing sequence: Outlined above Circulation: Simulated mud circulation over 6 bpm risks formation breakdown. Verify with company man on location. Cementing and displacing: Rates @.4 bpm or under are within the safe operating limits. Recommend dropping the displacement rate 20 bbls prior to bumping the plug @ 1300 psi. No U-tubing is expected. Centralizers: Recommend 2/1 across the zone of interest. Mud: Recommend Pv = 15 to 20 and YP = 15 to 20 @ 10.0 or underfor effective mud removal Kevin Tanner can be reached regarding this program at the following numbers: 265-6205( office), 230-6628( cell) . . ~.. "." ARCa Alaska, Inc. Cementing Details Well Name: 2L-317 Report Date: 0511512000 Report Number: 6 RiQ Name: Nabors 19E AFC No,: AK 0070 Field: TARN Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: I lC Depth: % washout: 7-518" 9-7/8" 3461 3370 Centralizers State type used, intervals covered and spacing CommentS: 34 TOTAL, CENTER JTS 2,53,54 OVER STOP CLRS. 31 OVER CLRS JTS 1,3-12,15,18,21.24.27,30,33,36,39,42,45,48,51 ,fiT ,60,63,66,69.72 Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: Gels before: Gels after: Total Volume Circulated: 2.5 CSG VOLUMES Wash 0 Type: Volume: Weight: Comments: ARCO B47 20 BBL 8.3 Spacer 0 Type: Volume: Weight: Comments: ARCO B45 40 BBL 10.2 PPG LeadCel1lsnt 0 Type: Mix wtr temp: No, of Sacks: I Weight: Yield: Comments: AS III Ute 65 360 10.7 4.44 Additives: G W/.50%D124,9.0%D44,0.4%D46,30%D53, 1.5%S1, 1.5%D79 Tall Cement 0 Type: Mix wtr temp: No, of Sacks: I Weight: Yield: Comments: G 65 240 15.8 1.17 Additives: G W/1%S1,0.2%D46,0.3%D65, Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: CommentS: 6.65 6.5 90 LEFT 10 BBL CEMENT ON Reciprocation length: Reciprocation speed: Str. WI. Down: TOP OF PLUG, OVERDISPLACEDBY 4 BBl, 20' STKlMIN 70 DID NOT BUMP PLUG. Theoretical Displacement: Actual Displacement: Str. WI. in mud: 154.7 158.7 Calculated top of cement: CPo Bumped plug: I Floats held: CMT TO SURFACE Date:5I15100 NO YES Time:1045 Remarks:DISPLACED W/DIESEl(57 BBL) FOLLOWED BY SEAWATER. RECCOMEND NOT USING DIESEL IN FUTURE DUE TO COMPLEXITY OF SWITCHING TRUCKS DURING DISPLACEMENT, AIRING UP PUMPS AND CONSEQUENT LOSS OF STROKES AND NOT BUMPING PLUGS. DIESEL TRUCK UNABLE TO SUPPLY DISPLACEMENT DIESEL AT RATE NEEDED. FULL RETURNS THROUGHOUT JOB. Cement Company: Rig Contractor: I Approved By: DS NABORS RW. SPRINGER TARN PARTICIPATING AREA - 2L-317 2L-317 Rpt Date Start End Hole Tvpe Op Operations Section 10-May-00 00:00 00:00 SURF MIRU PJSM, P/U KELLY, M/U LOWER KELLY VALVE & SAVER SUB, R/U & TEST & RECORD PRESSURE, TEST STANDPIPE & KELLY, BLOW DOWN LINES, INSTALL NEW INSULATION, HEAT TAPE AND FLASHING ON FLOW LINE, LOAD BHA IN PIPE SHED.SERVICE RIG, DRAW WORKS, KELLY & BLOCKS, TAKE ON MUD IN PITS, BLOW DOWN H20 & STEAM IN PITS & RIG. SHUT DOWN ALL POWER TO RIG & WIRE IN HIGHLlNE POWERT. SEAL SEAMS ON RIG FLOOR & PITS. CONTINUE SEALING RIG FLOOR & PITS W/CAULKING, INSTALL DUCTING FROM AIR HEATER . TO CELLAR, HELD PRESPUD MEETING W/CREW. INSTALL WELL SIGN. CONTINUE PARKER BALL MILL INSTALLATION. 11-May-00 00:00 02:00 SURF BHA M/U BIT TO MOTOR, CHANGE MOTOR TO 1.4deg, TAG ICE @38' 11-May-00 02:00 02:30 SURF BHA P/U KELLY, FILL HOLE, CHECK FOR LEAKS. 11-May-00 02:30 03:00 SURF DRIL DRLD ICE F/38'-105'. 11-May-00 03:00 03:30 SURF BHA SET KELLY BACK, P/U MWD, ORIENT, ART 1.25 HR. 11-May-00 03:30 14:00 SURF DRIL P/U KELLY DRLD F/105-591', ART 2.5, AST 2.25 HR., RUNNING PEA GRAVEL, SAND @ -550-590' . 11-May-00 14:00 19:30 SURF PMP_SERV BALL MILL GALlGHER PUMP IN OUTSIDE TANK PLUGGED UP W/GRAVEL, CIRC AND WORK DP WHILE PUMPING SWEEPS & CLEANING OUTSIDE CUTTINGS TANK & PUMP. 11-May-00 19:30 00:00 SURF DRIL DRLD F/591-808', ART .5, AST 2.0 HR. ACCEPTED RIG @ 2400 HR 5/7/00 WHEN ALL RIG MODIFICATIONS EXCEPT BALL MILL COMPLETE. 12-May-00 00:00 11 :30 SURF DRIL DRLD F/808-1465', ART 2.25, AST 3.25 HR, END BEARING OF CUTTINGS AUGER BROKEN, SET KELLY BACK. 12-May-00 11 :30 12:00 SURF PRB_RA POH 5 STDS TO 979' (ABOVE HYDRATE ZONE). 12-May-00 12:00 16:00 SURF PRB_RA REPAIR AUGER BEARING, WORK DRILLPIPE, CIRC ACROSS TOP OF HOLE & MONITOR WELL. . 12-May-00 16:00 16:30 SURF PRB_RA RIH, P/U KELLY. 12-May-00 16:30 00:00 SURF DRIL DRLD F/1465-1960', ART 2.5, AST 2.0 HR, MAXIMUM GAS UNITS -2100 UNITS @ 1600' 13-May-00 00:00 06:00 SURF DRIL DRLD F/1960-2276' ART 2.0, AST 1.75 HR 500-600 UNITS GAS. 13-May-00 06:00 07:00 SURF CIRC HOLE PACKING OFF, SET BACK CONNECTION, PUMP SWEEP & CIRC. 13-May-00 07:00 00:00 SURF DRIL DRLD F/2276-3129' ART 6.5, AST 4.0 HR, 400-500 UNITS GAS. 14-May-00 00:00 05:30 SURF DRIL DRLD F/3129-3471, ART 2.75, AST .5 HR. 14-May-00 05:30 06:00 SURF CIRC CIRCULATE BOTTOMS UP. 14-May-00 06:00 07:00 SURF CIRC PUMP SWEEPS & CLEAN HOLE, MONITOR HOLE, PUMP DRY JOB. 14-May-00 07:00 11 :30 SURF WIPERTRP POH, TIGHT SPOTS @ 2501, 1687, 1587, 1570, & 1134', CONTINUE POH TO JARS, MONITOR WELL. 14-May-00 11 :30 14:00 SURF WIPERTRP RIH TIGHT @ 1128' WORK THROUGH. 14-May-00 14:00 14:30 SURF CIRC CIRC BTMS UP. 14-May-00 14:30 16:30 SURF CIRC PUMP SWEEPS, SPOT PILL, MONITOR WELL, PUMP DRY JOB, SET KELLY BACK. 14-May-00 16:30 18:30 SURF TRIP _IN POH, SLM NO CORRECTIONS. Monday, April 30, 2001 - 1 TARN PARTICIPATING AREA - 2L-317 14-May-00 18:30 21:00 SURF BHA LA V DOWN BHA. 14-May-00 21:00 21:30 SURF CASG CLEAN RIG FLOOR. 14-May-00 21:30 23:00 SURF CASG PJSMRIG UP CASING EQUIPMENT. 14-May-00 23:00 00:00 SURF CASG RUN 7-5/8" CASING. 15-May-00 00:00 06:00 SURF CASG RUN 7-5/8" CASING TO 3461'. 15-May-00 06:00 06:30 SURF CASG MIU LANDING JT & CEMENTING HEAD, LAND CASING. 15-May-00 06:30 08:30 SURF CIRC BREAK CIRC SLOWL V, WORKING UP TO 7 BPM @ 600 PSI, CIRC AND RECIPROCATE CASING. ~ 15-May-00 08:30 11 :00 SURF CEMENT PJSM, PUMP 5 BBL PRE FLUSH, TEST LINES, 15 BBL PREFLUSH, DROP PLUG, 40 BBL SPACER, 284 BBL LEAD CEMENT, 40 BBL TAIL CEMENT, DROP PLUG, FOLLOWED BV 10 BBL CEMENT & 20 BBL WATER. DISPLACE WIRIG 57 BBL DIESEL FOLLOWED BV 68 BBL SEAWATER, CIP @1045 HR. DID NOT BUMP PLUGS, . FLOATS HELD, FULL RETURNS THROUGHOUT JOB. CMT TO SURFACE. 15-May-00 11 :00 13:00 SURF CASG FLUSH OUT FLOWLlNG W/RETARDER & WATER, BLOW DOWN MUD LINES, UD CEMENTING HEAD, BACKOUT LANDING JT & LAV DOWN, UD CASING EQUIPMENT. 15-May-00 13:00 18:00 SURF NU_ND NIPPLE DOWN DIVERTER LINE & 20" HVDRILL. INJECTION LINE TO BALL MILL REMOVED TO LAV DOWN DIVERTER, DIVERTER LINE & WELLHEAD. 15-May-00 18:00 00:00 SURF NU_ND NIPPLE UP WELLHEAD & TBG SPOOL, INSTALL TUBING HANGER WIONE JT OF 2-7/8" TBG BELOW HANGER. TEST HANGER TO 5000 PSI, INSTALL MASTER VALVE & TEST TO 5000 PSI. 16-May-00 00:00 01:30 SURF TEST_CSG TEST 7-5/8" CSG TO 2000 PSI F/30 MIN, OK, RIG DOWN HIGH PRESSURE HOSE, INSTALL 2 WAY CHECK. 16-May-00 01:30 06:00 SURF OTHER PJSM, LA V DOWN DP FROM DERRICK. 16-May-00 06:00 07:00 SURF OTHER FINISH UNLOAD TOP SHED OF DP TO LOWER SHED, SECURE PIPE. RELEASE RIG @ 0700 HR. 16-May-00 07:00 12:30 MOVE RDMO RID SKATE, BLOW DOWN H20 & STEAM, PIU CELLAR- BOL TS- TOOLS- SECURE BOP STACK, BREAK DOWN BERMS, UNHOOK TIOGA HEATER & MOVE, MOVE FUEL STORAGE TANK, MOVE OUT PIT COMPLEX & LINE OUT TO GO W/SUB. INSTALL JEEP ON SUB, PIU HERCULlTE & MATTS, PJSM WIPEAK & CREW. . 16-May-00 12:30 17:00 MOVE RDMO MOVE SUB OFF WELL & FOLLOW PIT COMPLEX TO 2N PAD, 3+ MILES. 16-May-00 17:00 00:00 MOVE RDMO UNHOOK JEEP FROM SUB, SPOT SUB OVER HOLE, SET MUD PITS IN PLACE. 18-Nov-00 17:30 00:00 COMP RDMO RID Modules - Split Modules @ disconnects- Move Ball Mill & Pit Module Out - Move Pit Module & Ball Mill to 2L pad and stage at east end. 19-Nov-00 00:00 13:00 MOVE MIRU Move Rig from 2N pad to 2L pad wI derrick standing (3 mile move) No major problems - Move Rig in over we1l2L-317 cellar bermed using hand-V-berm- Mate Pipe shed to Derrick Module. Set pit Module and berm using hand-V-berm. Set "New" cuttings tank and berm using hand-V-berm. Set & Mate up Ball Mill (Old Parker 245 unit) 19-Nov-00 13:00 14:00 PROD MIRU Rig Accept @ 1 :OOPM - Complete Berms 19-Nov-00 14:00 15:00 PROD NU_ND NID Master Valve & Tbg adapter 19-Nov-00 15:00 19:30 PROD NU_ND NIU BOPs & Surface flow lines 19-Nov-00 19:30 21:00 PROD NU_ND MIU Landing jt to Tbg Hanger(3 1/2 EUE 8rd) - BOLDS - Pull hanger to rig floor 19-Nov-00 21:00 22:00 PROD NU_ND UD landing jt, XO, & 1 jt 2 7/8" Tbg 19-Nov-00 22:00 23:00 PROD BOPE Set Test Plug - RIU Test Equip - Fill Stack w/Water Monday, April 30, 2001 - 2 TARN PARTICIPATING AREA - 2L-317 19-Nov-00 23:00 00:00 PROD BOPE Test BOPs - Test BOPs & Choke Manif 250psi/3500 psi, Annulur tested to 250psi/2500psi - AOGCC Rep : Jeff Jones present for test 20-Nov-00 00:00 03:30 PROD BOPE Test BOPs & Choke Manif 250psi/3500psi , ANN test 250psi/2500psi - Lower kellt valve failed -C/O & retest "OK" 20-Nov-00 03:30 04:00 PROD BOPE Blow On lines - Blow Down & SIB Kelly - Install wear bushing 20-Nov-00 04:00 06:00 PROD BHA P/U BHA #2 - Orient Tools 20-Nov-00 06:00 06:30 PROD BHA Sperry Sun Program Tools 20-Nov-00 06:30 09:00 PROD BHA P/U HWDP & Jars out of shed 20-Nov-00 09:00 11 :30 PROD TRIP _IN P/U DP out of shed - Ice Plugs @ 1125', 1158' & 1208' 20-Nov-00 11 :30 12:00 PROD TRIP _IN Con't TIH P/U DP from shed 20-Nov-00 12:00 14:00 PROD TRIP _IN Con't TIH P/U DP from shed t! 2770' - Tag Stringers -Will take wt. 20-Nov-00 14:00 00:00 PROD CLN_OUT P/U Kelly - C/O CMT Stringers 2770' to 3150' - Firm CMT @ 3150' ( Note: FC @ 3370' = . 220' CMT above FC) 21-Nov-00 00:00 04:30 PROD CLN_OUT C/O cement from 3,150' - 3231. Test csg to 2000 psi. 21-Nov-00 04:30 06:00 PROD CLN_OUT C/O cement from 3231' - 3326'. 21-Nov-00 06:00 06:30 PROD CIRC Circ hole clean for csg test. 21-Nov-00 06:30 08:00 PROD TEST_CSG Test 7 5/8" csg to 2,000 psi for 30 min - held. 21-Nov-00 08:00 12:00 PROD CLN_OUT C/O cement, float collar, good cement, float shoe, and drilled 30' new formation to 3501'. 21-Nov-00 12:00 14:00 PROD CIRC Circ hole clean and conditon mud to 9.4 ppg for L.O.T. 21-Nov-00 14:00 14:30 PROD OTHER R.U. AND PERFORM L.O.T. - 13.1 PPG EMW @ SHOE. 21-Nov-00 14:30 00:00 PROD DRIL DRILL FROM 3501' - 3893'. 22-Nov-00 00:00 14:00 PROD DRIL DRILL FROM 3893' - 4,462'. 22-Nov-00 14:00 14:30 PROD CIRC PUMP SWEEP AROUND AND CIRC CLEAN FOR WIPER TRIP. 22-Nov-00 14:30 15:30 PROD WIPERTRP POOH TO SHOE - NO PROBLEMS. KICK DRILL. 22-Nov-00 15:30 17:30 PROD RIGS PJSM. CUT DRILLING LINE. INSPECT BRAKES. 22-Nov-00 17:30 18:30 PROD WIPERTRP RIH - NO PROBLEMS. 22-Nov-00 18:30 00:00 PROD DRIL DRILL FROM 4462' - 4715'. 23-Nov-00 00:00 00:00 PROD DRIL DRILL FROM 4715' - 5865'. BOP DRILL. NO PROBLEMS. 24-Nov-00 00:00 15:00 PROD DRIL DRILL FROM 5865' - 6,422'. 24-Nov-00 15:00 16:00 PROD CIRC CIRC HOLE CLEAN FOR WIPER TRIP. . 24-Nov-00 16:00 18:30 PROD WIPERTRP MADE WIPER TRIP TO 4359'. HOLE IN GOOD SHAPE. WASHED 40' TO BOTTOM. 24-Nov-00 18:30 00:00 PROD DRIL DRILL FROM 6422' - 6571'. SPILL DRILL - DISPLACE WELL WITH NEW 9.5 PPG LSND MUD AT 6500' WHILE DRILLING. 25-Nov-00 00:00 00:00 PROD DRIL DRILL FROM 6571'- 7430'. NO PROBLEMS. 26-Nov-00 00:00 00:00 PROD DRIL DRILL FROM 7430' - 8284'. NO PROBLEM 27-Nov-00 00:00 04:00 PROD DRIL DRILL FROM 8284' - 8487'. 27-Nov-00 04:00 06:30 PROD CIRC PUMP SWEEPS AROUND AND CIRC HOLE CLEAN. OBSERVE WELL - SLUG D.P. 27 -Nov-OO 06:30 12:00 PROD TRIP _OUT POOH TO 3900' - OBSERVE WELL - POOH TO 3400' - OBSERVE WELL - CIRC BTMS UP - OK. FINISH POOH WITH D.P. 27-Nov-00 12:00 14:00 PROD TRIP _OUT LD BHA 7 1/2" DOSRWD HAD CHIPPED AND WORN CUTTERS. Monday, April 30, 2001 - 3 TARN PARTICIPATING AREA - 2L-317 27 -Nov-OO 14:00 20:00 PROD BOPE PULLED WEAR BUSHING AND SET TEST PLUG. TEST BOP'S TO 250 PSI LOW AND 3,500 PSI HIGH. ONE LEAK - TUBING HEAD I BOP FLANGE - TIGHTENED AND RETESTED. TEST WITNESS WAIVED BY JOHN SPALDING WITH AOGCC. PULLED TEST PLUG AND SET WEAR RING. 27-Nov-00 20:00 21:30 PROD BHA MAKE UP BHA#2. NEW 4 3/4" BIT I 71/2" DOSRWD - CHANGED OUT MOTOR AND JARS. ORIENTED TOOLS. 27-Nov-00 21:30 00:00 PROD TRIP _IN RIH TO 3,500'. 28-Nov-00 00:00 04:00 PROD TRIP_IN RIH TO 8404'. 28-Nov-00 04:00 05:00 PROD CIRC WASH 70' TO BOTTOM - CIRC. 28-Nov-00 05:00 00:00 PROD DRIL DRILL FROM 8474' - 9138'. FIRE DRILL. 29-Nov-00 00:00 00:00 PROD DRIL DRILL FROM 9138' -9748'. SLOW ROP DUE TO BIT BALLING UP. 30-Nov-00 00:00 22:30 PROD DRIL DRILL FROM 9748' - 10370'. . 30-Nov-00 22:30 00:00 PROD CIRC PUMP SWEEPS AROUND AND CIRC HOLE CLEAN FOR WIPER TRIP. 01-Dec-00 00:00 03:30 PROD WIPERTRP FLOW CHECK - SLUG D.P. - MADE 20 STAND WIPER TRIPTO 8450'. NO PROBLEMS- HOLE IN GOOD SHAPE. 01-Dec-00 03:30 00:00 PROD DRIL DRILL FROM 10,370' - 11,107'. NO PROBLEMS. 02-Dec-00 00:00 00:00 PROD DRIL DRILL FROM 11,107' -11990'. BOP DRILL. 03-Dec-00 00:00 15:00 PROD DRIL DRILLED FROM 11,990' -12,469'. 03-Dec-00 15:00 17:00 PROD WIPERTRP MADE 22 STAND WIPER TRIP TO 10,330'. HOLE IN GOOD SHAPE. KICK WHILETRIPPING DRILL. 03-Dec-00 17:00 00:00 PROD DRIL DRILL FROM 12,469' -12,661'. 04-Dec-00 00:00 00:00 PROD DRIL DRILLED FROM 12661' - 13,302'. NO PROBLEMS. 05-Dec-00 00:00 06:30 PROD DRIL Dir Drlg 13,302' to 13,494' MD ( 5403' TVD) ART 2.8 hrs AST 2.3 hrs 05-Dec-00 06:30 09:00 PROD CIRC Surv - Pump Low Vis Sweep - Circu Hole Clean 05-Dec-00 09:00 18:00 PROD TRIP _OUT Monitor well (Static) - SIB & Blow dn Kelly - TOH - Tight hole @ 12420' 25K overpull - Work back thru until clean 05-Dec-00 18:00 19:30 PROD SURV Down Load MWD Info 05-Dec-00 19:30 20:30 PROD BHA UD BHA 05-Dec-00 20:30 00:00 PROD BOPE Test BOPs - Tested Choke Manif wfTOH 250psi/3500psi - Pull Wear bushing - Set test plug - Test BOPs 250psi/3500psi - Test Ann 250psi/3000psi- All "OK" -No failures- Pull test . plug 06-Dec-00 00:00 01:00 PROD BOPE Con't BOPs - Blow down Test Lines - Set wear bushing 06-Dec-00 01:00 04:00 PROD BHA PIU BHA #4 - Load Sources - Up Load MWD 06-Dec-00 04:00 06:00 PROD TRIP_IN TIH to Shoe @ 3461' 06-Dec-00 06:00 07:30 PROD RIGS PJSM - Cut Drlg Line (117' cut) 06-Dec-00 07:30 08:00 PROD CIRC Break Circu @ Shoe -Condition Mud 06-Dec-00 08:00 10:00 PROD TRIP _IN TIH to 5566' - Thick mud returns 06-Dec-00 10:00 11 :00 PROD CIRC Circu & ConditionThick mud returns 06-Dec-00 11 :00 18:30 PROD TRIP_IN TIH - Thick Mud returns - Break circu @ 6450',9210' & 12060' - Work thru tight spot @ 12040' 06-Dec-00 18:30 00:00 PROD DRIL Dir Drlg 13494' to 13735' MD (5539' TVD) ADT 3.2 hrs 07-Dec-00 00:00 09:00 PROD DRIL Dir Drlg 13735' to 14161' MD (5792' TVD) ADT 6.6 hrs 07-Dec-00 09:00 11 :30 PROD CIRC Circu Hole Clean - Rotate & Recip Pipe 07-Dec-00 11 :30 12:00 PROD TRIP _OUT Monitor well - Pump Dry Job - SIB & Blow dn Kelly Monday, April 30, 2001 - 4 TARN PARTICIPATING AREA - 2L-317 07-Dec-00 12:00 15:00 PROD WIPERTRP Wiper Trip to 11925' - Tight spots @ 13075',13001' & 12520' - 15 to 20K overpull - Work each until clean 07-Dec-00 15:00 17:00 PROD CIRC Circu & Condition - ***Note*** After logs were evaluated by geologist in town it was decided that not enough "Pay" present. We will plug back and Drlg to New BHL 07 -Dec-OO 17:00 17:30 PROD TRIP_OUT Monitor Well - Pump Dry Job - SIB & Blow dn Kelly 07-Dec-00 17:30 00:00 PROD TRIP _OUT TOH - Small Tight Spots@ 12519',12305',12270',11822' -Max overpull on any spot 25K 08-Dec-00 00:00 04:30 PROD TRIP _OUT Con't TOH - Monitor well @ Shoe & BHA into BOPs 08-Dec-00 04:30 05:00 PROD SAFETY PJSM wI Sperry on Sources - Clean Rig Floor for BHA 08-Dec-00 05:00 06:00 PROD SURV Remove Sources - Dn Load Data from FRTs 08-Dec-00 06:00 07:00 PROD BHA UD Sperry Tools & Mud Motor 08-Dec-00 07:00 07:30 PROD RIGS Service & Replace Air Boot on Riser 08-Dec-00 07:30 10:00 PROD TRIP_IN RIU Tbg Tools - PIU CMT Stinger 28 jts 2 7/8" Tbg & Mule Shoe . 08-Dec-00 10:00 13:30 PROD TRIP_IN TIH wI CMT Assy t! 8200' - Thick Mud coming back 08-Dec-00 13:30 14:00 PROD CIRC Circu & Condition 08-Dec-00 14:00 18:30 PROD TRIP _IN Con't TIH w/CMT Assy 08-Dec-00 18:30 22:00 PROD CIRC Circu & Condition for CMT Plug 08-Dec-00 22:00 00:00 PROD PLUGBACK PJSM - Set Bttm Plug - Pump 53.6 bbl15.8ppg "G" CMT in continuos balanced plug to cover 14161' thru 13300' - CIP 11:48PM 09-Dec-00 00:00 00:30 PROD TRIP _OUT TOH to 13218' 09-Dec-00 00:30 05:30 PROD CIRC Circu Hole Clean - @ 4200 stks had thick mud & large amount of wall cake to surface. Hole packing off and lossing partial returns. Had to help lift thick mud from hole by raising Drlg String. Used Pump (30 spm)on up stroke and slowed to 5 stks on down stroke.Lost 100 bbls to formation 09-Dec-00 05:30 09:30 PROD CIRC Mud circu freely -Shut down for flow Ck - Formation gave back 53 bbls mud - Circu & Condition 09-Dec-00 09:30 11 :00 PROD TRIP _OUT Attempt to trip up to next plug point - Hole swabbing slightly 09-Dec-00 11 :00 12:00 PROD CIRC PIU Kelly - Rotate & Attempt to clean up string - Circu & Condition - Pump nut plug sweep 09-Dec-00 12:00 14:30 PROD CIRC Con't to Circu Sweep to Surface 09-Dec-00 14:30 15:00 PROD TRIP _OUT Attempt TOH - Hole not taking correct fill 09-Dec-00 15:00 17:00 PROD TRIP _OUT PIU Kelly - Pump Singles out of hole . 09-Dec-00 17:00 18:00 PROD CIRC Circu & Condition Mud 09-Dec-00 18:00 22:30 PROD TRIP _OUT Con't Pump Singles out of Hole ( 72 Jts total) 09-Dec-00 22:30 23:30 PROD CIRC Circu Hole Clean - Spot High Vis Gel Pill 9950' thur 9750' (200') 09-Dec-00 23:30 00:00 PROD TRIP _OUT TOH to 9747' ( KO plug location)- RIU to Circu @ 9730' 10-Dec-00 00:00 00:30 PROD CIRC Circu & Condition for CMT Job 10-Dec-00 00:30 01:30 PROD PLUGBACK Pump Top KO Plug @ 9750' - Pump 24 bbls Slurry - Cover 9750' thru 9450' (300' Plug) Calculated TOC @ 9450' 10-Dec-00 01:30 02:00 PROD TRIP_OUT TOH to 9400' 10-Dec-00 02:00 08:00 PROD CIRC Circu to clean string - @ 3900 stks had thick mud to surface - Hole taking fluid - reduce pump rate - Work pipe to assist lift on Mud - Pump 5 spm on down stroke - Pump 35 spm on up stroke - Lost total 75 bbls Mud - Now circu freely - Showed gain 10-Dec-00 08:00 09:30 PROD CIRC Circu and Monitor gain - Recovered 70 bbls mud 10-Dec-00 09:30 12:00 PROD CIRC Circu & Condition Mud - Take on 200 bbls new mud - dump 200 bbls -Treating to reduce surface tention of mud ,reduce gels Monday, April 30, 2001 - 5 TARN PARTICIPATING AREA - 2L-317 10-Dec-00 12:00 19:00 PROD CIRC Circu & Condition Mud - Rotate pipe 25 to 30 rpms in attemp to help clean string and system - UD 1 jt per hour to reduce washout 10-Dec-00 19:00 00:00 PROD PRB_WOW Mud Condition good - Circu & Rotate string slowly to maintain mud properties - Phase 3 Condition declared - Reduced work to must maintain only - No medic - Long responce time for medical evac - WOW Standby 11-Dec-00 00:00 04:30 PROD PRB_WOW Con't WOW Phase 3 condition - Circu & Rotate to maintain good mud properties - Lay dn 1 jt per hr @ 8925' 11-Dec-00 04:30 05:00 PROD PRB_MISC Stop Pumps for 30 min - Flow Ck well - Well showing contenious slight flow 11-Dec-00 05:00 07:30 PROD CIRC CBU - Check for influx - On BTTMs Up - Max Gas units 40 11-Dec-00 07:30 08:00 PROD PRB_MISC Flow Ck well - Very slight flow - SIB Kelly & blow dn 11-Dec-00 08:00 12:00 PROD TRIP_OUT TOH to 4755' (42 stds) Hole not taking proper file 2.6 bbls over calculated - TIH to 8925' 11-Dec-00 12:00 14:00 PROD CIRC CBU - Max Gas units on Bttm Up 37 units - Stop pumps - Monitor well - Showing very slight . flow 11-Dec-00 14:00 19:00 PROD TRIP_OUT TOH - Ck for flow @ 10,30 & 45 Stds DP ,at camp sands & Shoe - Slight flow 11-Dec-00 19:00 00:00 PROD TRIP _OUT PJSM - R/U Tbg Tools - TOH UD 2 7/8" tbg cmt stinger 12-Dec-00 00:00 01:00 PROD BOPE PJSM for Test BOPs- Pull wear bushing - Set test plug 12-Dec-00 01:00 05:00 PROD BOPE Test BOPs - Choke Manif was tested on TOH in Csg 300psi/3500psi - Test BOPs to 300psi/3500psi - Annular tested 300psi/3000psi - No failures - AOGCC Rep Jeff Jones waived witness test 12-Dec-00 05:00 07:30 PROD BHA PJSM - P/U BHA - Orient Tools - Install sources - Program tools 12-Dec-00 07:30 08:30 PROD BHA Con't P/U BHA 12-Dec-00 08:30 10:30 PROD TRIP _IN TIH to Shoe- (Bit out Shoe 10') 12-Dec-00 10:30 12:00 PROD RIGS Cut Drlg Line (109' cut) 12-Dec-00 12:00 13:00 PROD RIGS Complete Cut drill line - Ajust brakes 12-Dec-00 13:00 14:00 PROD CIRC CBU @ 3480' 12-Dec-00 14:00 18:30 PROD TRIP _IN TIH - Break circu @ 5850' & 9381' 12-Dec-00 18:30 20:00 PROD CIRC CBU - Condition returns - Reduce ECDs 12-Dec-00 20:00 23:00 PROD PRB_EFC Swivel Packing Leaking - SIB Kelly R/U Circu Head - Circu & Recip pipe - C/O Swivel Packing - Had to remove Goose neck -Wash pipe had dropped down -Quick change could . not be removed. 12-Dec-00 23:00 00:00 PROD REAM Wash & Ream CMT Stringers 9381' to 9396' - Tag good CMT@ 9396' Monday, April 30, 2001 - 6 TARN PARTICIPATING AREA - 2L-317A 2L-317 A Rpt Date Start End Hole Type Op Operations Section 13-Dec-00 00:00 05:00 S1P1 REAM C/O CMT 9396' to 9455' MD 13-Dec-00 05:00 12:00 S1P1 DRIL Time Drlg ISidetrack off plug 9455'(Departure point) to 9546' MD (4070 TVD) ART .5 hrs AST 4.4 hrs 13-Dec-00 12:00 15:30 S1P1 DRIL Dir Drlg 9546' to 9676' MD ( High ECDs 12.2 Max) ART 1.5 hrs AST 1.0 hrs 13-Dec-00 15:30 18:00 S1P1 CIRC Pump Hi Vis Sweep - Circu hole clean - Rotate & Recip pipe at all times - Lost 38 bbls mud circ sweep out - After stopping pump regained 28 bbls - Well Breathing 13-Dec-00 18:00 18:30 S1P1 TRIP _OUT Monitor Well - Blow On & SIB Kelly - TOH to 9191' . 13-Dec-00 18:30 19:00 S1P1 TRIP _IN TIH to 9644' - No tight hole - No problems 13-Dec-00 19:00 23:00 S1P1 CIRC Pump 78 bbl LCM Pill (20 Ibs per/bbl Walnut Med,Barofiber & Micatex Fine) @ 9644' and Circu to Surface - Shakers Bypassed to allow LCM to stay in system 13-Dec-00 23:00 00:00 S1P1 CIRC UD 1 jt wi Kelly - Cont Circu with LCM material - Mix Barofiber & Walnut Med 10 min/sx - Maintaining light LCM in system lost 18 bbls. - Losses slowing 14-Dec-00 00:00 02:30 S1P1 CIRC Circu LCM Sweep @ 9613' -Fluid loss slight 14-Dec-00 02:30 03:30 S1P1 REAM Wash & Ream 9613' to 9676' - Fluid loss has stopped 14-Dec-00 03:30 12:00 S1P1 DRIL Dir Drlg 9676' to 9860' MD (4199' TVD) 14-Dec-00 12:00 13:00 S1P1 DRIL Dir Drlg 9860' to 9876' MD (High ECDs 11.1 +) 14-Dec-00 13:00 14:30 S1P1 CIRC UD 1 jt DP - Rotate & Recip DP - Circu Hole Clean -(ECDs lowered to 10.64) 14-Dec-00 14:30 20:00 S1P1 DRIL Dir Drlg 9876' to 10024' MD ( 4272' TVD) -( High ECDs 11.0+) 14-Dec-00 20:00 21:30 S1P1 CIRC UD 1 jt DP - Circu Hole Clean 14-Dec-00 21:30 00:00 S1P1 WIPERTRP Wiper Trip 25 Stds 15-Dec-00 00:00 02:00 S1P1 TRIP _IN TIH to 9965' 15-Dec-00 02:00 03:30 S1P1 REAM Wash & Ream 9965' to 10024' - Rotate & Recip & Circu- Pump to reduce ECDs 10.98 dn to 10.61 15-Dec-00 03:30 12:00 S1P1 DRIL Dir Drlg 10024' to 10308' MD (4411 TVD) ART 3.4 hrs , AST 2.5 hrs 15-Dec-00 12:00 00:00 S1P1 DRIL Dir Drlg 10308' to 10775' MD (4681 TVD) ART 5.5 hrs , AST 2.0 hrs . 16-Dec-00 00:00 12:00 S1P1 DRIL Dir Drlg 10775' to 11130' MD (4889' TVD) ART 4.7 hrs ,AST 2.5 hrs 16-Dec-00 12:00 13:00 S1P1 DRIL Dir Drlg 11130' to 11161' MD 16-Dec-00 13:00 14:30 S1P1 CIRC UD 1 jt DP - Rotate & Recip String - Circu Hole Clean 16-Dec-00 14:30 19:00 S1P1 WIPERTRP Wiper Trip 28 stds to 8422' - No Problems - No Drag 16-Dec-00 19:00 19:30 S1P1 CIRC Stage up Pumps - Circu until ECDs @ 10.78 16-Dec-00 19:30 00:00 S1P1 DRIL Dir Drlg 11161' to 11319' MD ( 5001' TVD) ART 3.0 hrs , AST 1.0 hrs 17 - Dec-OO 00:00 12:00 S1P1 DRIL Dir Drlg 11319' to 11825' MD (5295' TVD) ART 6.6 hrs AST 1.4 hrs 17-Dec-00 12:00 00:00 S1P1 DRIL Dir Drlg 11825' to 12130' MD ( 5469' TVD) ART 4.4 hrs AST 3.2 hrs 18-Dec-00 00:00 12:00 S1P1 DRIL Dir Drlg 12130' to 12566' MD (5733' TVD) ART 8.1 hrs , AST 0.0 hrs 18-Dec-00 12:00 14:00 S1P1 DRIL Dir Drlg 12566' to 12655' MD (5785' TVD) ART 1.6 ,AST 0.0 hrs 18-Dec-00 14:00 16:30 S1P1 CIRC Circu & Condition for Wiper Trip- Monitior Well - Pump Dry Job 18-Dec-00 16:30 00:00 S1P1 WIPERTRP Wiper Trip to Shoe @ 3461' - Tight Hole @ 11428',10351 ',6478',5870',4782- Max overpull 20K 19-Dec-00 00:00 00:30 S1P1 WIPERTRP Monitor well @ Camp Sands, continue TOH to shoe @ 3461' Friday, April 27, 2001 - 1 TARN PARTICIPATING AREA - 2L-317A 19-Dec-00 00:30 02:30 S1P1 RIGS Change out tugger and man rider sheaves. 19-Dec-00 02:30 11 :00 S1P1 WIPERTRP TIH to btm. 12,655', CBU at top of each sand 19-Dec-00 11 :00 15:30 S1P1 CIRC Circulate and Condition mud for csg. Spot lube pill. 19-Dec-00 15:30 00:00 S1P1 TRIP _OUT Monitor well, pump dry job, blow down kelly, TOH. Tight hole @ 10,370',8667',4807', 4312', & 3614' worked through OK. Max overpull20K. 20-Dec-00 00:00 03:00 PROD TRIP_OUT Finish TOH to HWDP. Safety meeting, LD HWDP. 20-Dec-00 03:00 05:00 PROD SURV Safety meeting, retrieve sources, down load S.S. 20-Dec-00 05:00 06:30 PROD TRIP_OUT Finish LD BHA. 20-Dec-00 06:30 09:30 PROD BOPE Drain stack, pull wear bushing. Change pipe rams to 5-1/2" Test rams -250 - 3500. RD test equip. 20-Dec-00 09:30 11:00 PROD CASG RU casing equip. to run 3-1/2". PJSM. 20-Dec-00 11 :00 13:00 PROD CASG Ran 21 jts 3-1/2" casing. . 20-Dec-00 13:00 18:00 PROD CASG RU casing equip. for 5-1/2". Ran casing to 3440' (shoe). 20-Dec-00 18:00 18:30 PROD CIRC Circulate BU. 20-Dec-00 18:30 00:00 PROD CASG Cont. to run casing and circ. every 2500'. 21-Dec-00 00:00 09:00 PROD CASG Continue to run 5-1/2" casing, circulating every 2500' 21-Dec-00 09:00 14:00 PROD CIRC Continue to run 5-1/2" casing to 219 jts (9839') hit bridge. Circulate & Recipricate @ 3 BPM 550 psi. Pumped hi-vis sweep with lub. worked thru bridge. 21-Dec-00 14:00 19:00 PROD CASG Continue to run casing. Ran 21 jts of 3-1/2" and 283 jts of 5-1/2" casing. Make up csg. hanger. landing jt. and cement head. 21-Dec-00 19:00 22:30 PROD CIRC Circulate and Condition Mud. 21-Dec-00 22:30 00:00 PROD CMT _CSG PJSM, pumped 5 bbl wash, pressure test. ::K22-Dec-00 00:00 01:30 PROD CMT _CSG Pumped 15 bbls CW 100 Wash, 10 bbls Fresh wt. 30 bbls Mud Push XL, @ 11.0 ppg, 32 bbls cement, 13 ppg Lead cement,64 bbls 15.8 ppg tail, dropped plug, displaced w/rig using seawater to calc displacement 289 bbls. Bumped plug, CIP @ 01 :25 hr, up wt = 165K dwn wt = 55K 22-Dec-00 01:30 03:30 PROD OTHER Bleed off, floats held. RD cement equipment, clean oft rig floor. Set packoff, RILDS, test to 5000 psi 10 min. 22-Dec-00 03:30 06:00 SURF CEMENT R/U and perform top job on 7-5/8"X16" 22 bbls cement. 22-Dec-00 06:00 10:00 PROD BOPE Change pipe rams to 3-1/2", test to 250 - 3500. . 22-Dec-00 10:00 00:00 PROD CASG PJSM, R/U and run 3-1/2" completion. 23-Dec-00 00:00 02:30 COMP SPAC_OUT STING INTO CSR W/PUMP ON TO VERIFY SEALS IN. 23-Dec-00 02:30 04:00 COMP CIRC R/U TEST CASING TO 3500 FOR 1/2 HR. P/U TBG HANGER, R/U CIRC. EQUIP. CIRC 290 BBLS CLEAN SEAWATER. 23-Dec-00 04:00 12:00 COMP OTHER STING INTO CSR, SPACE OUT LAND TBG. RILDS. TEST TBG TO 3500, TEST CSG. TO 3500. PUMPED 35 BBLS DIESEL FREEZE PROTECT, LET U-TUBE. R/U ON 7-5/8"X5-1/2" ANNULUS, PERFORM LOT FORMATION BROKE @ 300 PSI SURFACE W/9.6 PPG MUD (SHOE TVD 2316') PUMPED 5.8 BBL AWAY TOTAL. =EMW 11.1 PPG, RIG FLUSHED W/100 BBLS FW, HOT OIL FREEZE PROTECT W/45 BBLS DIESEL.. 23-Dec-00 12:00 00:00 COMP OTHER UD LANDING JT. PJSM, LAY DOWN DRILL PIPE. CLEAN UP TOOLS FROM RIG FLOOR. LAY DOWN MOUSE HOLE. PJSM, SLIP AND CUT 108' OF DRILL LINE. 24-Dec-00 00:00 03:00 COMP NU_ND NO BOP SYSTEM. 24-Dec-00 03:00 08:30 COMP NU_ND NU & TEST TREE. FMC REP (MIKE GILROY) TEST PACKOFF & TREE TO 5000 PSI "OK". PULL 2 WAY CHECK INSTALL BPV. RIG RELEASED 08:30 HRS 12-24-00 Frida~ApriI27,2001 -2 MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc { \ f MECHANICAL INTEGRITY RE'PORT ' '- dOtJ--d-\C) :: ?UD D A -::::::: : \J.I'\·~'- 0<...) :.~G RELSJ..S'::: . \d J"d ~- DO OPER & FIELD (: V p,.. 'L...)~'...JL- To..~ W=:LL NUMBER d' \-.- "\ \ ~ ~ ~~LL DATA To: \d~HD.. S'l<65TVD¡ :?:BTD: \d<04~ HI! S~9:;ÛTVD Ca.sing: S \I~ Shoe: \l~~J HD TVD i -\-a~<Y....( ..,.. -=-:":1e~ : .~ \,) Shoe: \d~l;' t1D TVD i , . '-- ~"Q _ '..1 0 ~;:; g : ~ \ ") Pac k e!:" \ \ ~d ') till b~ f L-{ . :::'ole Size ~" .4/, 8:j~CP._ANIC;~ INTEGRITY - PART 11 ';:f 1~ '0 ~ j 1 ,1.) 19.. ' .:1 ? : ~ t 'j .& ~ ¡ rt9 ! M JtŒCHÞ_?\1ICÞ..L INTEGRITY - PART 42 I ¡- I :J. g Cement Volumes:' , I'D ¡11 ,/1 ! c..r,tt ~ ¡ O",,·"Ó.- ~ wi g ~ ..ut ./ i V)':; ¡- ¥.- ,/ I~~i ! ~ i 0 f e L 0 :: <' tf r'\'j) , i C p,;" rf\ 3J/jjú ': /"":) 0.. /L) , :(¡~,pt?tJ ! -1J ^ J ~ Proàuc.tion Log: Type I ¡J ~j'''ú ' I t; 5'cr . .' r; i CONCLUSIONS: . f] . rJ' [) . ~ Ó ?art f1: ~ 'S:' \)..)(}~<.cÄ.a;s.~ .. . J"--. (\) ~ :? ar~ ; 2 : \"\ ~ \~ \ ~\'c..ö-..~ rES '062004 .' ..'. Æ- n¡,l;;>lb,-OL-\ - \-:)~', "\\-:::\ss~-\ '<>..'.fj.~ ·i-...a-\--Ç, \\~ ð~~\ '" s~\, \j.j<¿\ \ ~'>ctvCJ.\~~J. DV: MD ·T\tï) :OP: \ \ Sl.\·~ 1-1D :~rD TVD¡ Set: ê.t a.nå P er£s \~ \'6~- \=> aço ~ to Annulus Press Test: ; 15 min 30 min ~p Comments: jn"-~ S ~á.'-)\~\ "~ ~ h,t;¡- 0 \ / '~()O~>< ~(j, ~~\c~~. q 0 c;'(. C, .A.mt. Liner Cs g ._ j DV Cült ·';01 to cove:!:." perfs Q ~q(o·'l..S '\<.0 ~''i-. o~ ~,\ .v....JQ~ <;,'-.)~\ C '\Q.......\ \<::> ca....::.~'-~ "* ~~..<:;,. ,\>\0"-> soo 0 Theoretical Toe C ~<J¿c. 'I-- S i \C)C\? Qb~' c;CJ::X:)t ~ '3/~ '-0 \ .-." Cement Bond Log (Yes or No) \t.~ :In AOGCC File ,'{t: ~ CBL Evaluation, z.oneabove perfs --.!-'i>~"\-'\(}.\ \'1 t---O \:.'C\£t\ ~ '\~co.~~ I ~~L N~ 5'h~~o \ s\-c~SJ t-..t¡ "" ~ \~~ Evaluation DATA SUBMITTAL COMPLIANCE REPORT 7/3012003 Permit to Drill 2002100 Well Name/No. KUPARUK RIV U TARN 2L-317A Operator CONOCOPHILLIPS ALASKA INC MD 12655 c,/" TVD ,-2-2.44-- Completion Dat 7/22/2001" Completion Statu WAGIN '" APl No. 50-103-20336-01-00 Current Status WAGIN---'-- _~'~ UIC Y ~~ REQUIRED INFORMATION Mud Log No Sample N_9 Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital TyPe Media Fret Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments Well Cores/Samples Information: Name Directional Survey FINAL Directional Survey FINAL ~ 5 FINAL LIS Verification FINAL 10057 FINAL RST 5 FINAL ~ GR/ROP/RES 2/5 FINAL ~I~D, GR/RES 2/5 FINAL ~"I~1~ GR/DEN/NEU 2/5 FINAL ,...MD GR/DEN/NEU 2/5 FINAL e'R'es'~eservoi r Saturation 5 FINAL Interval Start Stop Sent 3400 11827 3400 11890 3461 3461 3461 3461 11890 12611 12310 12611 12174 12655 12655 12655 12655 12174 Open 5/17/2001 fl1~57 3400-12611 2/23/2001 Dir Survey Digital Data 2/23/2001 Dir Survey Paper Copy ch 3/23/2001 11827-12310 Color Print ch 5/18/2001 LIS Verification Paper Copy ch 5/18/2001 4~57 3400-12611 Digital Data ch 5/18/2001 11890-12174 BL, Sepia OH 7/2/2001 3461-12655 BL, Sepia OH 7/2/2001 3461-12655 BL, Sepia OH 7/2/2001 3461-12655 BL, Sepia OH 7/2/2001 3461-12655 BL, Sepia CH 7/2/2001 11890-12174 BL Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y/~ Chips Received?~--.-¥-f'~-'-'~ Analysis ~ .... R~.n~.iv~.d? Daily History Received? ~ / N Formation Tops (~/N DATA SUBMITTAL COMPLIANCE REPORT 7~30~2003 Permit to Drill 2002100 Well Name/No. KUPARUK RIV U TARN 2L-3'I7A Operator CONOCOPHILLIPS ALASKA INC MD 12655 'I-VD 2244 Completion Dat 7/22/2001 Comments: Completion Statu WAGIN Current Status WAGIN APl No. 50-103-20336-01-00 Compliance Reviewed By: .................. ~ Date: Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1641 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color 2K-27 ~;~:~:~.'r~!ii STATIC BOTTOMHOLE PRESSURE 11/07/01 I 1 2L-317A ~1")1~-,-~ ~ WATERFLOW LOG/RST-C W/PSP 11/08/01 I 1 2N-304 ;~01- I~O 'SBHP & JEWELRY LOG 11/12/01 I 1 2N-307 IC)~-~! -J INJECTION pROFILE 11/09/01 I 1 2N-325 /C)~--Ib~ INJECTION PROFILE 11/11/01 ,,, I 1 2N-331 / Gl ~'"1 ~'"1 INJECTION PROFILE 11/11/01 I 1 2,-343 /, ~ ~_ ~c~ D INJECTION PROFILE 11/13/01 I 1 2N-349A .-~O0-~C[ INJECTION PROFILE 11/13/01 1 1 .,, RECEIVED , 2 ZOO1 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Than~ 0ii & Gas Cons. Commission Ancl~rage 11/26/01 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 12, 2001 Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-404 Sundry Notice forms for Phillips Alaska, Inc., wells 2N-303, 2N- 317, 2N-343, 2N-349 and 2L-317A. The notices are to report annulus "top job" cement operations for the five Tarn Field wells. Also attached are brief summaries and field report for the cementing operation. Please call Jerry Dethlefs or me at 907-659-7224 if you have any questions. Sincerely, Peter Nezaticky Phillips Problem Well Supervisor Attachments RECEIVED, Alaska 0il & Gas Cons. Commissio~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 191' FNL, 746' FEL, Sec. 22, T1 ON, R7E, UM At top of productive interval 51' FSL, 2583' FEL, Sec. 24, T10N, R7E, UM At effective depth At total depth 45' FNL, 2242' FEL, Sec. 25, T10N, R7E, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service__X (asp's 460903, 5927654) (asp's 469608, 5922580) (asp's 469947, 5922478) 6. Datum elevation (DF or KB feet) RKB 35 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2L-317A 9. Permit number / approval number 200-210 / 10. APl number 50-103-20336-01 11. Field / Pool Kuparuk River Field / Tarn Pool 12. Present well condition summary Total depth: measured true vertical 12655 feet 5785 feet Plugs (measured) Effective depth: measured 12529 feet true vertical 5707 feet Casing Length Size CONDUCTOR 78' 16" SURF CASING 3308' 7-5/8" PROD CASING 11789' 5-1/2" LINER 704' 3-1/2" LINER Junk (measured) Cemented Measured Depth True vertical Depth 9 cu yds High Early 78' 78' 360 sx AS III Lite, 240 sx Class G 3461' 2317' 90 sx C~ass G 11942' 5362' 300 sx C~ass G 12646' 5780' Perforation depth: measured 12182'- 12187', 12187'- 12267' true vertical 5501' - 5504', 5504' - 5550' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 11936' MD. Packers & SSSV (type & measured depth) Casing Seal Receptacle @ 11922' MD. CAMCO 'DS' NIPPLE W/NO-GO PROFILE @ 514' MD. RECEIVED NOV 1 200t Alaska 0il & Gas Cons. Commissim', Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas. Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil _ Gas __ Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Peter Nezaticky 659-7224 Signed Title Wells Supervisor Peter Nezaticky Date 11/12/01 Prepared by Sharon AIIsup-Drake 263-4612 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT"~PLICATE SUNDRY NOTICE 10-404 Phillips Kuparuk Well 2L-317A Annular Cement "Top-Job" November 08, 2001 Phillips Alaska, Inc., Kuparuk well 2L-317A surface casing has "grown" several inches to the point where the casing hanger was no longer contacting the conductor pipe. The cement top between the surface casing and conductor pipe (7 5/8" x 16") was measured at 5.6 ft feet below grade. Arctic Set I cement (15.7 ppg) was pumped into the annular void (1.5 bbls) via a hose, filling from the bottom-up. The cement top was brought to the surface of the conductor pipe. The State Inspector was notified of the cement job and waived attendance, but will inspect the wellhead post cementing. The field Well Service Report is attached. Alaska Oil & Gas Cons. Cornmissio~ Anchorage PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2L-317A(W4-6)) WELL JOB SCOPE JOB NUMBER 2L-317A ANN-COM M 0714011755.5 DATE DAILY WORK UNIT NUMBER 11/08/01 CEMENT TOP JOB DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES YES DS-ANDERSON, K. NEZATICKY FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE K85329 35TN2L1 LL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 1300 PSI 1300 PSI 900 PSI 900 PSII 450 PSI 450 PSI DALLY SUMMARY CEMENT TOP JOB ON THE SURF X COND ANNULUS (OOA).[WH Maintenance1 TIME LOG ENTRY 14:30 ON LOCATION. MIRU 15:15 CENTRALIZE WELLHEAD. START MIXING CEMENT. 15:30 MIXED 4 BBL OF 15.7 PPG ARTIC SET CEMENT. PUMPED 1.5 BBL THROUGH A 1" HOSE AT THE BOTTOM OF THE 5.6 FT VOID TAKING RETURNS TO A VAC TRUCK. 15:40 CEMENT TO THE TOP OF THE CONDUCTOR HANGER. RDMO. RECEIVED Alaska Oil & Gas Cons. Co~nmissior~ Anchorage PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 August23,2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2L-317A (200-210) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforation operations on the KRU well 2L-317A. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad RECEIVED SEP 0 5 2001 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Per/orate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_ RKB 153 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service__x Kuparuk River Unit 4. Location of well at surface 8. Well number 191' FNL, 746' FEL, Sec. 22, T1 ON, R7E, UM (asp's 460903, 5927654) 2L-317A At top of productive interval 9. Permit number / approval number 51' FSL, 2583' FEL, Sec. 24, T1 ON, R7E, UM (asp's 469608, 5922580) 200-210 / At effective depth 10. APl number 50-103-20336-01 At total depth 11. Field / Pool 45' FNL, 2242' FEL, Sec. 25, T1 ON, R7E, UM (asp'$ 469947, 5922478) Kuparuk River Field / Tarn Oil Pool 12. Present well condition summary Total depth: measured 12655 feet Plugs (measured) true vertical 5785 feet Effective depth: measured 12529 feet Junk (measured) true vertical 5707 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 78' 16" 9 cu yds High Early 78' 78' SURF CASING 3308' 7-5/8" 360 sx AS III Lite, 240 sx Class G 3461' 2317' PROD CASING 11789' 5-1/2" 90 sx C~ass G 11942' 5362' LINER 704' 3-1/2" 300 sx C~ass G 12646' 5780' LINER Perforation depth: measured 12182'-12187', 12187'-12267' J[~ CEi% '~"D''~' ~ true vertical 5501'-5504', 5504'-5550' $£P 0 5 200I Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 11936' MD. Alaska Oil & Gas Cons. Commission Packers & SSSV (type & measured depth) 11922' CSR Anchorage CAMCO 'DS' NIPPLE W/NO-GO PROFILE @ 514' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Injector - Subsequent to operation Shut-in 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil __ Gas __ Suspended _ Service _Water Injector X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney263-4574 Signed /~ /~~r~/~ Title: Wells Team Leader Date Mike Mooney . Prepared by Sharon A//sup-Drake 263-4612 Form 10-404 Rev 06/1,5/88 · ORIGINAL SUBMIT IN DUPLICATE Date Comment 2L-317A Event History 07/21/01 07/22/01 PERFORATED TWO INTERVALS [12247'-12267'] & [12227'-12247'] W/2-1/2" HC GUNS, DP CHARGES, 6 SPF, 60 DEG PHASING. FOR GUNS TO REACH PERFORATING INTERVAL DEPTH, HAD TO PUMP AT 1.5 BPM USING A TOTAL OF 230 BBLS DIESEL FOR TWO GUN RUNS. JOB IN PROGRESS. PERFORATED TWO INTERVALS [12207'-12227'] & [12187'-12207'] W/2-1/2" HC GUNS, DP CHARGES, 6 SPF, 60 DEG PHASING. FOR GUNS TO REACH PERFORATING INTERVAL DEPTH, HAD TO PUMP AT 1.5 - 1.7 BPM USING A TOTAL OF 190 BBLS DIESEL. Page I of 1 8/23/01 'PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Tranthsm Phone (907) 265-6434 Fax: (907) 265-6224 April 3, 2001 Commissioner state of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t~ Avenue Suite 100 Anchorage, Alaska 99501 Subject:. Completion Report for 2L-317A (200-210) . Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kuparuk well 2L-317A. ff you have any questions regarding this matter, please contact me at 265-6434 or Brian Noel at 265- 6979.' Silcerely' ~ ' J. Trantham Drilling Engineering Supervisor PA1 Drilling RECEIVED AUG 2 3 Z001 Alaska Oil & Gas Cons. Commission Anchorage " STATE OF ALASKA ' WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status ot well Classification of Service Well OII D Gas D Suspended D Abandoned D Service r~ WAG Injector 2. Name o! Operator 7. Permit Number Phillips Alaska, Inc. 200-210 3. Address 8. APl Number . P. O. Box 100360, Anchorage, AK 99510-0360 ~-~. 50-103-20336-01 4. Location ot well at sudace ¥~]~'~t~ 9. Unit or Lease Name 192' FNL, 748' FEL, Sec. 22, T10N, R7E, UM (ASP: 460903, 5927655) . I ~ Kuparuk River Unit At Top Preducing Interval :."i .~:Z.'. ~ ~'~ ¢.~/'i !, 9.~ .,=-;~"'"!/~",5, ,-,~,~r.-~ .~' 10. Well Number 51' FSL, 2583' FEL, Sec. 24, T10N, R7E, UM (ASP 469608, 5922580) ~? .~.~..~';~'~.~' i '"'"~"~' ............ ' ....... "'" .2L-317A At Total Depth 49' FNL, 2244' FEL, Sec. 25, T10N, R7E, UM (ASP: 469947, 5922478) :~. ......................... Kuparuk River Field , 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. Tarn Pool RKB 35', Pad 117 teetI ADL 380053, 380052 & 380051 ALK 4601 12. Date Spudded 13. Date T;D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if oflshom 16. No. o! Completions December 13, 2000 December 18, 2000 December 23, 2000J N/A fee{ MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) '19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 12655' MD / 5785' TVD 12646' MD / 5780' TVD YES r'~ No ~J N/A fee~ MD 1245' 22. Type Electric or Other Logs Run GR/Res/Den/Neu, SCMT 23. CASING, LINER AND CEMENTING RECORD SETrlNG DEPTH MD CASING SIZE 'WT. pER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD'.1 AMOUNT PULLED 16" 62.5# H-40 Surface 105~ 24' 9 cu. Yds High Early 7.625' 29.7# L-80 Surface. 3461' 9.875" 360 sx AS III Lite, 240 sx Class G 5.5" 15.5~ L-80 Surface 11942' 6.75" 90 sx Class G 3.5" 9.3# L-80 11942' 12647' 6.75' 3o0 sx Class G . . 24. perforatl(~ns open to Production (MD + TVD ot Top and Bottom and 25. TUBING RECORD Interval, size and number) ..SIZE DEPTH SET (MD) PACKER SET (MD) ,,, 3.5' 11937' 11922' (CSR) None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED None 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector Date'ot Test ' Hours Tested Production tor OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO Test Period > . I ' Flow Tubing. Casing Pressure Calculated . OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY. APl (con') 24-H°ur Rate >' 28. CORE DATA , Brief description of Iithology, porosity, lractums, apparent dips and pmssence of o11, gas or water. Submit core chips. " RECEIVED N/A AUG 2 3 2001 Alaska Oil & Gas Cons] Commission , Anchorage , Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Sul~mit In duplicate 29. GEOLOGIC MARKE{[i" ~ 30. ~,,'" 4~ 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 12112' 5460' T-2 12312' 5577' Annulus left open - freeze protected with diesel. 31. LIST OF A'I-I'ACHMENTS Summary of Daily Operations, Directional SurVey 32. I h~j eby certily that the following is true and correct to the best of my knowledge, Questions? Call Brian Noel 265-6979 _ James Trantham INSTRUCTiONs Prepared by Sharon AIIsup-Drake General: This fOrm is designed for sUbmitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water' disposal, water supply for injection, observation, injection for in-situ combUstiOn. 'Item 5: Indicate Which elevation is used as reference (where. not otherwise shown) for'depth measurements given in other spaces on this form and in any attachments.. Item 16 and 24:' If this well is completed for separate production from more than one interval (multiple cOmpletion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent .to such interval. Item 21: Indicate whether from grOund level.(GL) or other elevation (DF,' KB, e~tc.). , Item 23: ^ttached Supplemental records for this well should show the details of any multiple stage cementing and the location of tho cementing tool. Item 27: 'Method of OPeration: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, ~{~,~. Injection, Gas Injection, Shut-in, Other-explain. , ' I-<i CEtVE.D , ' Item'28: if no cores taken, indicate "none'. AUG ~ 3 2001 Form 10-407 Alaska 0il & .Gas Cons. Cornrnissior~ Anchorage Date: 02/12/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2L-317A WELL_ID: AK0070A TYPE: STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: TARN PARTICIPATING AREA SPUD:12/13/00 START COMP: RIG:NABORS 19E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20336-01 12/13/00 (D1) MW: 9.6 VISC: 43 PV/YP: 10/15 APIWL: 3.8 TD/TVD: 9676/4123. (9676) DIR DRLG @ 9699' (RIG ON HI LINE POWER LAST 24 HRS-NO SUPV:DEARL W. GLADDEN Clean out cement 9396' to 9455'. Time drilling/sidetrack off plug 9455' to 9546'. Dir drilling 9546' to '9676'. Pump hi vis sweep, circ hole clean. Rotate & recip pipe at all. times. Lost 38 bbls mud circ sweep out. Well breathing. TOH to 9191'. TIH to 9644'. No tight hole, no problems. Pump LCM pill. 12/14/00 (D2) MW: 9.6 VISC: 46 PV/YP: 13/17 APIWL:. 3.8 TD/TVD:10024/4272 (348) DIR DRLG 6 3/4" HOLE @ 10118' (RIG ON HI LINE POWER LA SUPV:DEARL W. GLADDEN Circ LCM sweep @ 9613, fluid loss slight. Wash & ream 9613' to.9676', fluid loss has stopped. Dir drilling, from 9676' to 9876'. Circ hole clean. Dir drilling from 9876' to 10024'. Circ hole. clean. Wiper trip 25 stds. 12/15/00 (D3) MW: 9.6 VISC: 48.PV/YP: 17/18 APIWL: 3.9 TD/TVD:10775/4681 (751) DIR DRLG 6 3/4" HOLE @ 10941' (RIG ON HI LINE POWER LA SUPV:DEARL W. GLADDEN TIH to 9965'.' Wash & ream from 9965' to 10024', rotate & ., recip and'circulate, pump to reduce ECDs to 10.61. Directional drilling from 10024' to 10775'. 12/16/00 (D4). ' MW: 9.6 VISC: 44 PV/YP: 12/15 APIWL: 3.8 TD/TVD:l1319/5001 (544) DIR DRLG 6 3/4" HOLE @ 11621' (RIG ON HI LINE POWER L SUPV:DEARL W. GLADDEN Directional drilling from 10775' to 11161'. Rotate & recip string~ circu hole clean. Wiper trip 28 stds to 8422', no problems, no drag. Circu until ECDs @ 10.78.. Dir drilling from 11161' to 1131'9' ,, 12/17/00 (D5) .MW: 9.6 VISC: 48 PV/YP: 13/16 TD/TVD:12130/5469 ( 811) DIR DRLG 6 3/4" HOLE @ 12362 (RIG ON HI SUPV:DEARL W. GLADDEN Directional drilling 11319' to 12130'. APIWL: .4'0 LINE POWER LAS Date: 02/12/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 12/18/00 (D6) MW: 9.6 VISC: 44 PV/YP: 13/15 APIWL: '3.1 TD/TVD:12655/5785 (525) TIH -WIPER TRIP TO SHOE SUPV:OVERSTREET/GLADDEN Directional drilling from 12130' to 12655' MD. Circu and condition for wiper trip, monitor well, pump dry job. wiper trip to shoe @ 3461'. 12/19/00 (D7) MW: 9.6 VISC: 43 PV/YP: 13/15 APIWL: 3.1 TD/TVD:12655/5785 ( 0) CHANGE OUT RAMS IN BOP, RIG UP TOOLS TO RUN CASING. SUPV:RICK OVERSTREET Monitor well @ camp sands, continue TOH to shoe @ 3461'. TIH to bottom 12655', CBU at top of each sand. Circulate and condition mud for casing. Spot lube pill. Monitor well, pump dry job, blow down kelly, TOH. '12/20/00 (D8) MW: 9.6 VISC: 40 PV/YP: 15/12. APIWL: .3.2 TD/TVD:12655/5785 ( 0) CONTINUE TO RUN.5-1/2" X 3-1/2" CASING (24 HR HI-LINE) SUPV:RICK OVERSTREET Finish TOH to HWDP. Safety meeting. RU casing equipment to . run 3.5".. PJSM. Run 3.5" casing. Circulate BU. Continue t° run casing and circulate. 12/21/00 (D9) MW: 8.6 VISC: 28 PV/yp: 1/ 0 APIWL:' 0.0 TD/TVD:12655/5785 ( 0) RD DOWELL FROM CASING CEMENT JOB AND TOP JOB. SUPV:RICK OVERSTREET Continue to run 5.5".casing to 219 its, hit bridge @ 9839'. Circulate and reciprocate.' Pumped hi-vis sweep .with lub. worked thru bridge. Continue to run casing. Ran 3.5" and 5.5" casing. Circulate and condition mud. PJSM. 12/22/00 (D10) MW: 8.6 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 TD/TVD:12655/.5785 ( '0) DISPLACE WITH CLEAN SEAWATER, FREEZE PROTECT. SUPV:RICK OVERSTREET Pumped cement. Dropped plug, bumped plug. Floats.held. Set packoff and test to 5000 psi. PerfOrm top jOb on 7-5/8" x 16" cement. PSJM.. Run 3.5" completion. 12/23/00 (Dll) MW: 0.0 VISC: 28 PV/YP: 0/ .0 APIWL: 0.0 TD/TVD:12655/5785 ( 0) NU TREE SUPV:RICK OVERSTREET Test .tUbing to 3500 psi, test casing to 3500 psi. Freeze protect well. Perform LOT, EMW=ll.1 ppg. PJSM. ' Date: 02/12/01 ARCO ALASKA INC. WELL SUMMARY REPORT PaGe: 3 12/24/00 (D12) MW: 0.0 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12655/5785 ( 0) NU TREE AND TEST SUPV:RICK OVERSTREET ND BOP system. NU and test tree to 5000 psi, OK. RiG released @ 0830 hrs. 12/24/00. ~Jeff A Spencer ~1~~~06/18/01 05:39 PM "'~ TO: tom_maunder@admin.state.ak.us, bob_crandall@admin.ak.us, Brian D Noel/PPCO@Phillips cc: Jason Putnam/PPCO@Phillips, Satellites Prod Engrs/PPCO@Phillips, Stephen Bross/PPCO@Phillips Subject: Tarn Development - AOGCC Meeting Notes (06/13) Gentlemen, Please find below a summary of what was discussed at last Wednesday's (06/13) meeting regarding Tarn Field development. Attendance: AOGCC Phillips Tom Maunder Jeff Spencer Bob Crandall Brian Noel .ECbIVED JUL i' Y0[?l A/aSk~ 0il & Gas Cons. Commission jel12L-317A: (New Injection Well) Anchorage Because a CBL showed poor cement bonding in and immediately above the Bermuda interval, an alternative method was proposed by Phillips to demonstrate zonal isolation using a Water Flow Log (WFL). After reviewing the CBL, cement job data and other completion related information, the following plan was agreed to during an April 19th meeting. Note: Provide a detailed procedure, wellbore schematic, copy of CBL, details on the initial 2L-317A cement job, and a completed Sundry Form 403 to AOGCC prior to commencing any field work. 1. Perforate a 5' interval approximately 70' MD below the top of the Bermuda interval (T3). Projected depths of the initial perfs are expected to be 12182-12187' MD. 2. Establish injection into the well using water from a pump truck/transport at 1-2 BPM. Note: The expected maximum water injection rate into 2L-317A is <3000 BWPD. 3. Run WFL to determine if there is any behind pipe upward flow out of the Bermuda interval. 4. Review WFL with AOGCC. If upward flow is detected above the Bermuda interval, determine an appropriate remedial fix. The WFL did not show any upward flow and was reviewed with AOGCC personnel on June 13th. Once we provide copies of the WFL and a completed Sundry Form 403, we can proceed with Steps #5, 6 & 7, as outlined below. Note: Copies of the CBL, wellbore schematic and details of primary cement job were previously provided to AOGCC. 5. If no upward flow is detected, add perforations in the net pay intervals below the initial perforations and complete well as an MWAG injector. Note: Leave well SI until water is available for injection. 6. Commence water injection at normal operating rates and monitor daily rates & pressures. Note: Injection rates and pressure data are to be reported on a monthly basis similar to other MIT waivered injection wells. 7. After 2-3 months of water injection, run another WFL log to confirm that injection is staying within desired interval. AOGCC prefers WFL be run after 3 months of water injection. 8. If second WFL shows no upward flow or behind pipe channelling, commence normal MWAG operations after reviewing log with AOGCC. Producer-to-Injector Conversions: 2L-305 Reviewed CBL on 2L-305 with AOGCC and it showed excellent bonding throughout the zone of interest. Approval to convert to MWAG injector will be forthcoming from AOGCC once we provide copies of the CBL, wellbore schematic, primary cement job information and a completed Sundry Form 403. ' Note: FutUre P-to-I Conversion candidates showing good cement bOnding can be submitted for approval directly to the AOGCC (with appropriate supplementary information as shown above). 2N-326 Reviewed CBL on 2N-326 with AOGCC and it showed what appeared to be contaminated cement throughout the zone of interest. The VDL indicated some bonding to the formation but either due to weak compressive strength of the cement and/or incorrect CBL tool settings, the bond to the pipe appeared relatively poor. So although the CBL provides some evidence of cement behind pipe and it was our recollection that the frac job went as planned, the AOGCC requested that we run a WFL to ensure no upward flow above the Tarn producing horizon (Bermuda interval). Therefore, the action plan for 2N-326 is as follows: 1. Establish injection into the well using water from a pump truck/transport at 4 - 5 BPM. Note: The expected maximum water injection rate into 2N-326 is ~7000 BWPD. 2. Run WFL to determine if there is any behind pipe upward flow above the Bermuda interval. Note: This well was fracture stimulated from a 10' perf interval near the base of the Bermuda. 3. If upward flow is detected above the Bermuda interval, determine an appropriate remedial fix and review with AOGCC. 4. If no upward flow is detected, send copies of the CBL, WFL, wellbore schematic, fracture stimulation summary,' primary cementing information and Sundry Form 403 to AOGCC. 5. Upon receiving approval from AOGCC, complete well as an MWAG injector. Other Tarn P-to-I Conversion candidates will follow procedures similar to those outlined above for receiving approval from AOGCC. Thanks again for taking the time to meet with us and have a great week, Jeffrey A. Spencer Tarn Development Coordinator Phillips Alaska, Inc. 907-265-6813 jspencer@ppco.com APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate X Other _X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 191' FNL, 746' FEL, Sec. 22, T10N, R7E, UM At top of productive interval 51' FSL, 2583' FEL, Sec. 24, T10N, R7E, UM At effective depth At total depth 45' FNL, 2242' FEL, Sec. 25, T10N, R7E, UM 5. Type of Well: Development _ Exploratory __ Stratigraphic __ Service__X (asp's 460903, 5927654) ~sp~ 469608, 592258~ (asp's 469947, 5922478) 6. Datum elevation (DF or KB feet) RKB 153 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2L-317A 9. Permit number / approval number 200-210 10. APl number 50-103-20336-01 11. Field / Pool Kuparuk River Field/Tarn Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 78' SURF CASING 3308' PROD CASING 11789' LINER 704' LINER Size 16" 7-5/8" 5-1/2" 3-1/2" 12655 feet Plugs (measured) 5785 feet 12646 feet Junk (measured) 5780 feet Cemented 9 cu yds High Early 360 sx AS III Lite, 240 sx Class G 90 sx Class G 300 sx Class G Measured Depth 105' 3461' 11942' 12646' Trueve~icalDepth 105 2317 5362 5780 Perforation depth: measured 12182'- 12187' true vertical 5501'-5503' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 3-1/2", 9.3#, L-80 Tbg @ 11936' MD. 11922' CSR CAMCO 'DS' NIPPLE W/NO-GO PROFILE @ 514' MD. RECEIVED JUL 0 .001 .Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: July 25, 2001 16. If proposal was verbally approved Oil __ Name of approver Date approved Service 17. I hereby~ify t~hat the foregoi~e and ~ri~ct to the best of my knowledge. Signed ~N-'0J'j~"N---,._. ~ ~,v~ Title: Tarn Engineer Gas __ WAG Suspended __ Questions? Call Jason Putnam 265-6970 Date 7/c,'~/0 } Prepared by Sharon A//sup-Drake 263.46'12 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test_ Location clearance_ Mechanical Integrity Test __ Sq~tzsequent form required 1p- Approved by 0_rde_r_of_the _C_o.m_rnjs_sion ...~. _.~__!~.[. ~!~_1~ _Fl..Y,' Commissioner term '1 u-~+u,~ r~ev uo/-i o/o~ ' '"' i]RIGINAL I Approval no. 3~1' l~ I PHILLIP Alaska, Inc. Subsidiary ol= PHILLIPS PETROLEUM COMPANY Date: Subject: From/Location: Telephone: To/Location: June 26, 2001 2L-317A: Perforate/ISBHP/Run DV S. B. Andrus/D. E. Hensley NSK-14 x7687, pgr 921, radio 243 Central Wells Group NSK 69 File Code: Well 2L-317A (3 copies) WELL: PROPERTY CODE/ACTIVITY CODE: CAPITAL or EXPENSE BUDGET CATEGORY JOB SCOPE PRIMARY OBJECTIVE: ESTIMATED COST: 2L-317A/Injector 35TN2L1LG/AK0070 Capital Perforate/Stimulate Perf/Perf Support Perforate/ISBHP/Run DV $55,000 E-line X Perforate X ISBHP Slick-line X Run DV in open GLM at 11,869' MD-RKB X PT IA to 2500 psi Well 2L-317A was recently completed as a 3-1/2" Monobore injector. The results of the CBL showed poor cement bonding in and immediately above the Bermuda interval. Therefore, a Water Flow Log (WFL) was conducted which did not show any behind pipe upward flow in the Bermuda interval. PAI has reviewed the results of the WFL with the AOGCC and agreed to proceed with the 2L-317A completion activities. The well has been dummy gun drifted and tagged; therefore, no pre E-line work is necessary. The GLM at 11,869' MD-RKB was left open to allow tools to be pumped down the well if necessary. Contact the Tarn DSO to have the radio repeater turned off prior to perforating. RU EL. Perforate Well 2L-317A per the recommended perforation procedure listed below. See attached log with perforation picks identified. The maximum hole angle is 77° at 4349' MD-RKB with an average tangent angle of 73°. · 10' Marker located ~ 12,101' MD-RKB · Following perforation work, obtain an initial static bottom hole pressure at these designated stops: 12,225' and 12,052' MD-RKB. · RU SL. Run DV in open GLM at 11,869' MD-RKB and pressure test IA to 2500 psi. Perforation Specifications: Reference Log: Interval: Sperry Sun MWD DGR/EWR dated 12/19/00 12,187'- 12,268' MD-RKB (81') 2L-317A Perf_Isbhp_runDV.doc Page 1 of 2 Jason Putnam 07/02/01 01:39 PM To: tom_maunder@admin.state.ak.us, bob_crandall@admin.ak.us cc: Subject: Tarn Development - AOGCC Meeting Notes (06/13) Mr. Maunder, We are ready to move forward on the P to I conversion of 2L-305 and also the final well work (perforations) to begin injecting water into 2L-317A. I will drop off the 403 Sundry Forms for both wells along with the additional requested information to your office today. If you have any questions please don't hesitate to call. Thank you, Jason D. Putnam Tarn Surveillance Engineer Phillips Alaska Inc. (907) 265-6970 ..... Forwarded by Jason Putnam/PPCO on 07/02/01 01:43 PM ..... , Jeff A Spencer i06/18/01 05:39 PM JUL 0 ?fi. rtl Alaska Oil & ~ COns. ~nchorage Commission '~ To: tom_maunder@admin.state.ak.us, bob_crandall@admin.ak.us, Brian D Noel/PPCO@Phillips cc: Jason Putnam/PPCO@Phillips, Satellites Prod Engrs/PPCO@Phillips, Stephen Bross/PPCO@Phillips Subject: Tarn Development - AOGCC Meeting Notes (06/13) Gentlemen, Please find below a summary of what was discussed at last Wednesday's (06/13) meeting regarding Tarn Field development. Attendance: AOGCC Phillips Tom Maunder Jeff Spencer Bob Crandall Brian Noel L showed poor cement bonding in and immediately above the Bermuda interval, an hod was proposed by Phillips to demonstrate zonal isolation using a Water Flow Log (WFL). After reviewing the CBL, cement job data and other completion related information, the following plan was agreed.to during an April 19th meeting. Note: Provide a detailed procedure, wellbore schematic, copy of CBL, details on the initial 2L-317A cement job, and a completed Sundry Form 403 to AOGCC prior to commencing any field work. 1. Perforate a 5' interval approximately 70' MD below the top of the Bermuda interval (T3). ~d depths ofthe initial perfs are expected to be 12182-12187' MD. injection into the well using water from a pump truck/transport at 1-2 BPM. '~ ote: The expected maximum water injection rate into 2L-317A is <3000 BWPD. 3. Run_WFL to determine if there is any behind pipe upward flow out of the Bermuda_interval._ 4. Review WFL with AOGCC. If upward flow is detected above the Bermuda interval, determine an / ~PhPer~~l~t~ilenmoldsi~ifiwX~ny upward flow and was reviewed with AOGCC personnel on June 13th. Once we provide copies of the WFL and a completed Sundry Form 403, we can proceed with Steps #5, 6 & 7, as outlined below. Note: Copies of the CBL, wellbore schematic and details of primary cement job were previously provided to AOGCC. 5. If no upward flow is detected, add perforations in the net pay intervals below the initial perforations and complete well as an MWAG injector. Note: Leave well SI until water is available for injection. 6. Commence water injection at normal operating rates and monitor daily rates & pressures. Note: Injection rates and pressure data are to be reported on a monthly basis similar to other MIT waivered injection wells. 7. After 2-3 months of water injection, run another WFL log to confirm that injection is staying within desired interval. AOGCC prefers WFL be run after 3 months of water injection. 8. If second WFL shows no upward flow or behind pipe channelling, commence normal MWAG operations after reviewing log with AOGCC. 2L-305 Reviewed CBL on 2L-305 with AOGCC and it showed excellent bonding throughout the zone of interest. Approval to convert to MWAG injector will be forthcoming from AOGCC once we provide copies of the CBL, wellbore schematic, primary cement job information and a completed Sundry Form 403. Note: Future P-to-I Conversion candidates showing good cement bonding can be submitted for approval directly to the AOGCC (with appropriate supplementary information as shown above). 2N-326 Reviewed CBL on 2N-326 with AOGCC and it showed what appeared to be contaminated cement throughout the zone of interest. The VDL indicated some bonding to the formation but either due to weak compressive strength of the cement and/or incorrect CBL tool settings, the bond to the pipe appeared relatively poor. So although the CBL provides some evidence of cement behind pipe and it was our recollection that the frac job went as planned, the AOGCC requested that we run a WFL to ensure no upward flow above the Tarn producing horizon (Bermuda interval). Therefore, the action plan for 2N-326 is as follows: 1. Establish injection into the well using water from a pump truck/transport at 4 - 5 BPM. Note: The expected maximum water injection rate into 2N-326 is ~7000 BWPD. 2. Run WFL to determine if there is any behind pipe upward flow above the Bermuda interval. Note: This well was fracture stimulated from a 10' perf interval near the base of the Bermuda. 3. If upward flow is detected above the Bermuda interval, determine an appropriate remedial fix and review with AOGCC. 4. If no upward flow is detected, send copies of the CBL, WFL, wellbore schematic, fracture stimulation summary, primary cementing information and Sundry Form 403 to AOGCC. 5. Upon receiving approval from AOGCC, complete well as an MWAG injector. Other Tarn P-to-I Conversion candidates will follow procedures similar to those outlined above for receiving approval from AOGCC. Thanks again for taking the time to meet with us and have a great week, Jeffrey A. Spencer Tarn Development Coordinator Phillips Alaska, Inc. 907-265-6813 jspencer@ppco.com WELL LOG TRANSMITTAL To' State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 29, 2001 RE: MWD Formation Evaluation Logs 2L-317 A, AK-MM-00271 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2L-317 A: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20336-01 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-1'03-20336-01 2"x 5" MD Neutron & Density Logs: 50-103-20336-01 2"x 5" TVD Neutron & Density Logs: 50-103-20336-01 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia RECEIVED 'JUL 0 2 2001 Almmkm 011 & Gms Oonm, Oommimmlen Anchorage PI4,.LIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 June 26,2001 Commissioner Camille Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2L-317A (200-210) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforation operations on the KRU well 2L-317A. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney~ Staff Engineer Phillips Drilling MM/skad 0 R I 61 l'{ A L RECEIVED JUN 26 2001 Alaska 011 & {las C01~s. Commlssio. Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulal~ Plugging Perlorate X Pull tub ng .. Aller ~:asing Repair well. Other. 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 191' FNL, 746' FEL, Sec. 22, T1 ON, R7E, UM At top of productive interval 51' FSL, 2583' FEL, Sec. 24, T10N, R7E, UM At effective depth At total depth 45' FNL, 2242' FEL, Sec. 25, T10N, R7E, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service__X (asp's 460903, 5927654) (asp's 469608, 5922580) (asp's 469947, 5922478) 6. Datum elevation (DF or KB feet) RKB 153 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2L-317A 9. Permit number / approval number 200-210 / 10. APl number 50-103-20336-01 11. Field / Pool Kuparuk River Field / Tarn Oil Pool 12. Present well condition summary Total depth: measured true vertical 12655 feet 5785 feet Effective depth: measured 12646 feet true vertical 5780 feet Casing Length Size CONDUCTOR 78' 16" SURF CASING 3308' 7-5/8" PROD CASING 11789' 5-1/2" LINER 704' 3-1/2" LINER Plugs (measured) Junk (measured) Cemented Measured Depth True vertical Depth 9 cu yds High Early 78' 105' 360 sx AS III Lite, 240 sx Class G 3461' 2317' 90 sx c~ass G 11942' 5362' 3oo sx c~ass G 12646' 5780' Perforation depth: measured 12182'-12187' true vertical 5501'-5503' Tubing (size, grade, and measured depth) 3-1 ~". 9.3~-', L-80 I bg '~' 11936 MD. Packers & SSSV (type & measured depth) ! 1922' CSR (';,AMC(') DS NIPPLE W'NC)-GC) PROFI/.E .t~ 51,1 MD. RECEIVED JUN 26 2001 Alaska 0il & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Avera.qe Production or Injection Data Gas-Mc/ Water-Bbl Injector Shut-in Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Oil .... Gas __ Suspended __ Service _Water Injector___X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 4 /~x/'/~t~.,~ Title Staff Engineer Michael Mooney ~ Form 10-404 Rev 06/15/88 · Of IGllqAL Questions? Call Mike Mooney 263-4574 SUBMIT IN DUPLICATE 2L-317A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 5/6/01: MIRU & PT equipment. RIH w/perforating guns & shot 5' of perforations as follows: Added perforations: 12181' - 12187' MD Used 2.5" HSD carriers & shot the perfs at 6 spf at 60 degree phasing. POOH w/guns. RD. 5/17/2001 Schlumberger NO. 1147' Schlumberger Technology Corporation, by and through i's Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 2L-317A ~'~)~-~ )O RST-WFL 0Sl06101 2V-02 /~'~-](p/ INJECTION PROFILE 05/05101 2D-13 ~(-/-O/_' PRODUCTION PROFILE 05108101 t i ,ECE ED s,o ~/x , _ ) .^~.: HAY 1 8 2001 Alaska Oil & Gas Cons. Comm~ Please sign and return one copy of-this transmittal to Sherrie at the above address or fax to (907) 661-83t7. Thank YqiJ1chorag(l WELL LOG TRANSMITTAL To: State of Alaska May 10, 2001 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD FOrmation Evaluation Logs 2L-317A, AK-MM-00271 d~o~-~ ~o 1 LDWG formatted Disc with verification listing. APi#: 50-103-20336-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: RECEIVED ~AY 1 8 2.001 Alaska Oil & Gas Cons, Commissmn ~n~orage PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 April 3, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 2L-317A (200-210) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kupamk well 2L-317A. If you have any questions regarding this matter, please contact me at 265-6434 or Brian Noel at 265- 6979. Silcerely, ,, - J. Trantham Drilling Engineering Supervisor PAI Drilling JT/skad RECEIVED APR 04 2.001 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas D Suspended D Abandoned D Service r~l WAG Injector 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 200-210 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20336-01 4. Location of well at surlace 9. Unit or Lease Name 192' FNL, 748' FEL, Sec. 22, T10N, R7E, UM (ASP: 460903, 5927655) ~"J.OC.-~~I. Kuparuk River Unit 49' FNL, 2244' FEL, Sec. 25, T10N, R7E, UM (ASP: 469947, 5922478) . Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Tarn Pool RKB 35', Pad 117 feet] ADL 380053, 380052 & 380051 ALK 4601 12. Date Spudded 13. Date T.D. Reached '14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions December 13, 2000 December 18, 2000 December 23, 2000 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set .21. Thickness of Permafrost 12655' MD / 5785' TVD 12646' MD / 5780' TVD YES r~ No r"]~1 N/A feet MD 1245' 22. Type Electric or Other Logs Run GR/Res/Den/Neu, SCMT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP BO'FI'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 105' 24" 9 cu. Yds High Early 7.625" 29.7# L-80 Surface 3461' 9.875" ,360 sx AS III Lite, 240 sx Class G 5.5" 15.5# L-80 Surface 11942' 6.75" 90 sx Class G 3.5" 9.3# L-80 11942' 12647' 6.75" 300 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 11937' 11922' (CSR) None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED None 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I Test Pedod > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. .,^ REC[IVED Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T-3 12112' 5460' T-2 12312' 5577' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I h~eby certify that the following is true and correct to the best of my knowledge. Questions? Call Brian Noel 265-6979 Signed .,-. ~ rY'k,.~_~'q~ I ,~k~/[ ,~t.~,._ Title Drilling En.qineerln.q Supervisor Date~ James Trantham Prepared by Sharon Al/sup-Drake INSTRUCTIONS General.' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24.' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21; Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In~ct~n~,C_~s~ I~j~qFk Shut-in, Other-explain. VY.L Item 28-' If no cores taken, indicate "none". APR 04 2001 Form 10-407 Alaska Oil & t~.s Con,~,, {;om~':,~:iss,,),o!'~ Date: 02/12/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2L-317A WELL_ID: AK0070A TYPE: STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: TARN PARTICIPATING AREA SPUD:12/13/00 START COMP: RIG:NABORS 19E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20336-01 12/13/00 (D1) MW: 9.6 VISC: 43 PV/YP: 10/15 APIWL: 3.8 TD/TVD: 9676/4123 (9676) DIR DRLG @ 9699' (RIG ON HI LINE POWER LAST 24 HRS-NO SUPV:DEARL W. GLADDEN Clean out cement 9396' to 9455' Time drilling/sidetrack off plug 9455' to 9546'. Dir drilling 9546' to 9676'. Pump hi vis sweep, circ hole clean. Rotate & recip pipe at all times. Lost 38 bbls mud circ sweep out. Well breathing. TOH to 9191'. TIH to 9644'. No tight hole, no problems. Pump LCM pill. 12/14/00 (D2) MW: 9.6 VISC: 46 PV/YP: 13/17 APIWL: 3.8 TD/TVD:10024/4272 (348) DIR DRLG 6 3/4" HOLE @ 10118' (RIG ON HI LINE POWER LA SUPV:DEARL W. GLADDEN Circ LCM sweep ~ 9613, fluid loss slight. Wash & ream 9613' to 9676', fluid loss has stopped. Dir drilling from 9676' to 9876'. Circ hole clean. Dir drilling from 9876' to 10024'. Circ hole clean. Wiper trip 25 stds. 12/15/00 (D3) MW: 9.6 VISC: 48 PV/YP: 17/18 APIWL: 3.9 TD/TVD:10775/4681 ( 751) DIR DRLG 6 3/4" HOLE @ 10941' (RIG ON HI LINE POWER LA SUPV:DEARL W. GLADDEN TIH to 9965'. Wash & ream from 9965' to 10024', rotate & recip and circulate, pump to reduce ECDs to 10.61. Directional drilling from 10024' to 10775' 12/16/00 (D4) MW: 9.6 VISC: 44 PV/YP: 12/15 APIWL: 3.8 TD/TVD:ll319/5001 (544) DIR DRLG 6 3/4" HOLE @ 11621' (RIG ON HI LINE POWER L SUPV:DEARL W. GLADDEN Directional drilling from 10775' to 11161'. Rotate & recip string, circu hole clean. Wiper trip 28 stds to 8422', no problems, no drag. Circu until ECDs @ 10.78. Dir drilling from 11161' to 11319' 12/17/00 (D5) MW: 9.6 VISC: 48 PV/YP: 13/16 APIWL: 4.0 TD/TVD:12130/5469 ( 811) DIR DRLG 6 3/4" HOLE @ 12362 (RIG ON HI LINE POWER LAS SUPV:DEARL W. GLADDEN Directional drilling 11319' to 12130' RECEIVED Date: 02/12/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 12/18/00 (D6) MW: 9.6 VISC: 44 PV/YP: 13/15 APIWL: 3.1 TD/TVD:12655/5785 ( 525) TIH -WIPER TRIP TO SHOE SUPV:OVERSTREET/GLADDEN Directional drilling from 12130' to 12655' MD. Circu and condition for wiper trip, monitor well, pump dry job. Wiper trip to shoe @ 3461' 12/19/00 (D7) MW: 9.6 VISC: 43 PV/YP: 13/15 APIWL: 3.1 TD/TVD:12655/5785 ( 0) CHANGE OUT RAMS IN BOP, RIG UP TOOLS TO RUN CASING. SUPV:RICK OVERSTREET Monitor well @ camp sands, continue TOH to shoe @ 3461' TIH to bottom 12655', CBU at top of each sand. Circulate and condition mud for casing. Spot lube pill. Monitor well, pump dry job, blow down kelly, TOH. 12/20/00 (D8) MW: 9.6 VISC: 40 PV/YP: 15/12 APIWL: 3.2 TD/TVD:12655/5785 ( 0) CONTINUE TO RUN 5-1/2" X 3-1/2" CASING (24 HR HI-LINE) SUPV:RICK OVERSTREET Finish TOH to HWDP. Safety meeting. RU casing equipment to run 3.5". PJSM. Run 3.5" casing. Circulate BU. Continue to run casing and circulate. 12/21/00 (D9) MW: 8.6 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 TD/TVD:12655/5785 ( 0) RD DOWELL FROM CASING CEMENT JOB AND TOP JOB. SUPV:RICK OVERSTREET Continue to run 5.5" casing to 219 its, hit bridge @ 9839' Circulate and reciprocate. Pumped hi-vis sweep with lub. worked thru bridge. Continue to run casing. Ran 3.5" and 5.5" casing. Circulate and condition mud. PJSM. 12/22/00 (D10) MW: 8.6 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 TD/TVD:12655/5785 ( 0) DISPLACE WITH CLEAN SEAWATER, FREEZE PROTECT. SUPV:RICK OVERSTREET Pumped cement. Dropped plug, bumped plug. Floats held. Set packoff and test to 5000 psi. Perform top job on 7-5/8" x 16" cement. PSJM. Run 3.5" completion. 12/23/00 (Dll) MW: 0.0 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12655/5785 ( 0) NU TREE SUPV:RICK OVERSTREET Test tubing to 3500 psi, test casing to 3500 psi. Freeze protect well. Perform LOT, EMW=ll.1 ppg. PJSM. RECEIVED APR 04 2001 Alaska Oil & Gas Cons. ComraissJm~ Anchorage Date: 02/12/01 ARCO ALASKA INC. WELL SI/MMARY REPORT Page: 3 12/24/00 (D12) MW: 0.0 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12655/5785 ( 0) NU TREE AND TEST SUPV:RICK OVERSTREET ND BOP system. NU and test tree to 5000 psi, OK. Rig released @ 0830 hrs. 12/24/00. RECEIVED APR 04, 2001 '~ ~ ~,, 16-Jan-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well 2L-317A c,~OO-,~ JO Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,403.67' MD 9,455.00' MD 12,655.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Arco Alaska Inc. Kuparuk River Unit Phillips Alaska Kuparuk 2L, Slot 2L-317 2L-317A Surveyed: 18 December, 2000 S UR VEY REPORT January, 2001 Your Ref: AP1501032033601 Surface Coordinates: 5927654.49 N, 460902.70 E (70° 12' 47.7469"N, Kelly Bushing: 152.81ft above Mean Sea Level 150°18'55.1540"W) mpemm-v-sun~ DRILLING SERVICES Survey Reft svy9352 A Halliburton Company Sperry-Sun Drilling Services Survey Report for 2L-317A Your Ref: AP1 50103203360~ Surveyed: ~8 December, 2000 Arco Alaska Inc. Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 9403.67 74.070 124.700 3875.44 4028.25 9455.00 73.660 124.460 3889.70 4042.51 9517.97 70.780 123.760 3908.93 4061.74 9581.21 67.710 123.150 3931.34 4084.15 9675.81 65.870 120.290 3968.62 4121.43 9770.99 65.130 118.410 4008.10 4160.91 9865.67 64.400 117.140 4048.46 4201.27 9961.13 63.490 115.220 4090.39 4243.20 10055.72 63.280 113.120 4132.77 4285.58 10150.38 61.140 110.510 4176.91 4329.72 10245.08 58.190 108.780 4224.74 4377.55 10339.89 56.120 106.500 4276.16 4428.97 10434.55 54.520 104.280 4330.02 4482.83 10529.42 54.360 104.340 4385.20 4538.01 10624.36 54.560 103.920 4440.38 4593.19 10719.08 53.560 104.180 4495.98 4648.79 10813.27 54.070 104.240 4551.59 4704.40 10908.36 54.580 105.160 4607.04 4759.85 11002.97 53.910 105.460 4662.32 4815.13 11097.99 54.550 106.190 4717.87 4870.68 11192.99 54.080 105.900 4773.28 4926.09 11288.05 54.720 106.010 4828.62 4981.43 11383.10 54.850 105.750 4883.43 5036.24 11477.30 54.630 104.470 4937.81 5090.62 11572.73 54.450 103.480 4993.17 5145.98 11667.46 54.090 103.650 5048.49 5201.30 11760.89 54.510 102.190 5103.01 5255.82 11856.75 53.870 103.280 5159.10 5311.91 11951.77 54.280 104.720 5214.86 5367.67 12046.39 55.010 106.460 5269.61 5422.42 4261.90 S 6510.99 E 5923358.93 N 467391.53 E 4289.88 S 6551.59 E 5923330.74 N 467431.98 E 4323.51 S 6601.23 E 5923296.86 N 467481.45 E 4356.11 S 6650.56 E 5923264.00 N 467530.61 E 4401.82 S 6724.49 E 5923217.90 N 467604.31E 4444.28 S 6799.98 E 5923175.06 N 467679.57 E 4484.19 S 6875.75 E 5923134.76 N 467755.14 E 4522.03 S 6952.70 E 5923096.52 N 467831.89 E 4556.65 S 7029.85 E 5923061.50 N 467908.86 E 4587.78 S 7107.57 E 5923029.96 N 467986.42 E 4615.27 S 7184.53 E 5923002.07 N 468063.24 E 4639.42 S 7260.42 E 5922977.53 N 468139.00 E 4660.09 S 7335.46 E 5922956.47 N 468213.93 E 4679.17 S 7410.24 E 5922937.01N 468288.61E 4698.03 S 7485.16 E 5922917.76 N 468363.43 E 4716.64 S 7559.55 E 5922898.76 N 468437.73 E 4735.31S 7633.25 E 5922879.72 N 468511.32 E 4754.91S 7707.96 E 5922859.73 N 468585.94 E 4775.18 S 7782.02 E 5922839.07 N 468659.88 E 4796.21S 7856.19 E 5922817.66 N 468733.95 E 4817.53 S 7930.34 E 5922795.95 N 468807.99 E 4838.78 S 8004.66 E 5922774.32 N 468882.19 E 4860.03 S 8079.35 E 5922752.69 N 468956.78 E 4880.08 S 8153.61E 5922732.25 N 469030.93 E 4898.85 S 8229.03 E 5922713.09 N 469106.26 E 4916.89 S 8303.79 E 5922694.67 N 469180.92 E 4933.85 S 8377.74 E 5922677.32 N 469254.78 E 4950.98 S 8453.56 E 5922659.80 N 469330.51E 4969.60 S 8528.22 E 5922640.79 N 469405.07 E 4990.34 S 8602.54 E 5922619.67 N 469479.29 E Dogleg Rate (°/t00ft) 0.92 4.69 4.94 3.39 1.96 1.44 2.04 2.00 3.33 3.49 2.97 2.56 0.18 0.42 1.08 0.54 0.95 0.75 0.92 0.55 0.68 0.26 1.13 0.87 0.41 1.35 1.14 1.30 1.69 Vertical Section 7768.70 7817.84 7877.64 7936.65 8023.53 8110.13 8195.72 8281.29 8365.43 8448.33 8528.76 8606.59 8681.95 8756.30 8830.65 8904.43 8977.62 9052.17 9126.48 9201.27 9276.19 9351.21 9426.56 9500.94 9575.69 9649.49 9722.06 9796.34 9870.35 9945.13 Phillips Alaska Kuparuk 2L Comment TIE ON POINT OHST January, 200¢ - ¢¢:42 Page 2 of 4 DriilQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for 2L-317A Your Ref: APl 501032033601 Surveyed: 18 December, 2000 Arco Alaska Inc. Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl, Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 12141.11 54.760 107.190 5324.09 5476.90 5012.77 S 8676.71 E 12235.83 54.350 106.700 5379.02 5531.83 5035.26 S 8750.52 E 12330.51 53.630 106.840 5434.69 5587.50 5057.36 S 8823.85 E 12425.10 52.960 106.320 5491.22 5644.03 5079.00 S 8896.53 E 12520.31 51.980 106.270 5549.22 5702.03 5100.18 S 8969.00 E Global Coordinates Northings Eastings (ft) (ft) 5922596.86 N 469553.33 E 5922573.98 N 469627.03 E 5922551.51N 469700.24 E 5922529.49 N 469772.81E 5922507.93 N 469845.17 E 12583.54 51.780 105.860 5588.26 5741.07 5113.95 S 9016.81 E 12655.00 51.780 105.860 5632.47 5785.28 5129.29 S 9070.81 E 5922493.92 N 469892.90 E 5922478.29 N 469946.83 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.813° (14-Jan-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 119.880° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12655.00ft., The Bottom Hole Displacement is 10420.62ft., in the Direction of 119.487° (True). Dogleg Rate (°/'~OOft) 0.68 0.60 0.77 0.83 1.03 0.60 0.00 Vertical Section 10020.61 10095.81 10170.40 10244.20 10317.60 10365.90 10420.37 Phillips Alaska Kuparuk 2L Comment PROJECTED SURVEY January, 2001- ~:42 Page 3 of 4 DrillOuest 2.00.06 Sperry-Sun Drilling Services Survey Report for 2L-317A Your Ref: AP1 501032033601 Surveyed: ~8 December, 2000 Arco Alaska Inc. Kuparuk River Unit Phillips Alaska Kuparuk 2L Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 9403.67 4028.25 4261.90 S 6510.99 E 9455.00 4042.51 4289.88 S 6551.59 E 12655.00 5785.28 5129.29 S 9070.81 E Comment TIE ON POINT OHST PROJECTED SURVEY Survey tool program for 2L-317A From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 12655.00 Vertical Depth (ft) 5785.28 Survey Tool Description MWD Magnetic (2L-317) January, 200~ - ~:42 Page 4 of 4 Dr#/Quest 2.00.06 Schhlmberger NO. 1087 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 3J-01 /~.~/~o~ IN~'SC~TON PROFI~.~. 03/09/01 I 1 3J-09 /~.~-~/~{ ~'N~'SC?~'ON PROFZ~.~- 03/08/01 I 1 2L-317A 21122 SC~ 03/04/0~ I 3/20/01 RECEIVED I~ Z 3 2001 Please sign and return one copy of this transmittal to Sherrie at the above addr6ss or fax to (907) 561-8~1~ ~'~'~S. ~~ ~~e ALASKA OIL AND GAS CONSERVATION COPlPlISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 James Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re'. Kuparuk River Unit 2L-317A Phillips Alaska, Inc. Permit No: 200-210 Sur. Loc. 192'FNL, 748'FEL, Sec. 22, T10N, R7E, UM Btmhole Loc. 103'FNL, 2011 'FEL, Sec. 25, T1 ON, R7E, UM Dear Mr. Tranham: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC .25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC. 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before oPeration, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincer.~,,/~' jSincer tDaniel T. Seamoun Commissioner BY ORDER OF THE COMMISSION ' DATED this / 2._ 7~. day of December, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,. ,. : , . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill r~ Redrill r-] lb. Type of well. Exploratory r'~ Stratigraphic Test D Development Oil L~ [~ Deepen [~] Service ~,~velopment Gas D single Zone [~] Multiple Zone Re-entry . 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 35 feet 3. Address 6. Property Designation ~'~")o5-2,~,... Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 AD L 380053 ALK 4601 .~qcO//~ Tarn Pool 4. Location of well at sudace 7. Unit or property Name ' 11. Type Bond (see 2O AAC 25.0251) 192' FNL, 748' FEL, Sec. 22, T10N, R7E, UM Kuparuk River Unit Statewide At top of productive Interval 8. Well number Number 38' FSL, 2533' FEL, Sec. 24, T10N, R7E, UM 2L-317A #59-52-180 At total depth 9. Approximate spud date Amount 103' FNL, 2011' FEL, Sec. 25, T10N, R7E, UM December 8, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 103' @ TD feetI 2L-321 1060' @ 9500' M D feet 2560 12937' M D / 5931 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 9500' MD Maximum hole angle 73 Maximum surface 1845 psig At total depth (TVD) 2400 psig 18. Casing program Settin~ Depth size Specifications Top Bottom Quant~ of Cement Hole Casin~t Wei~lht Grade Couplin~l Length MD TVD MD TVD /include sta~e data) 6.75" 5.5" x 15.5# L-80 LTC Mod 11892' 35' 35' 11927' 5345' 100 sx Class G & 380 sx GasBLOK 6.75" 3.5" 9.3# L-80 8rd EuE 1010' 11927' 5345' 12937' 5931' (included above) 19. To be completed for Redrill, Re-entry. and Deepen Operations. Present well condition summary Total Depth: measured 14161 feet Plugs (measured) proposed 14161'-13300' tree vertical 5792 feet proposed 9650'-9350' Effective Depth: measured 14161 feet Junk (measured) tree vertical 5792 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 70' 16" 9 cu yds High Early 105' 105' Surface 3426' 7.625" 360 sx AS III Lite, 240 sx Class G 3461' 2319' Intermediate Production RECEIVED Perforation depth: measured ,one DEC 1 1 2000 Alaska 0il & Gas Cons. C0mmissio~ true vertical None ' Anchorage 20. Attachments Filing fee [~] Property Plat D BOP Sketch ~ Diverter Sketch E~] Drilling program r~ Drilling fluid program F~i Time vs depth plot DRefractlon analysis r'~ Seabed report D 20 AAC 25.050 requirements r'~ 21. i hereby certify that the foregoing Is true and correct to the best of my knowledge Questions? Ca//Brian Noel265-653 Signed J~amesTO~ntham~~.~,~ ~'O~. X.~/W~'5' Title: OrillingEnginooringSupervisor Date 7'~'~h~r/'/l~tvt Pre~)ared bv Sharon AIIsu~).Dral(~ Commission Use Onl} Permit Number J APInumber I ,,,row,,~,o ISee cover letter Conditions of approval Samples required [] Yes [~ No Mud log required ~ Yes [~] No Hydrogen sulfide measures r~ Yes D No Directional survey required [] Yes r-] No RequireUworklngpressureforBOPE [--]2M; r"l 3M; r-I SM; I-1 10M;r-1 ,. D ' ' ~ ORIGINAL. ~:.¢ (.~N '::, i.., ~i'.,~ ": by order of Approvedby [') T~¥h3r ~e;a~',ou~r',, Commissioner thecommisslon ... Date'/ Form 10-401 Rev. 12/1/85 · ORIGINAL Submit in triplicate Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 December 8, 2000 Daniel T. Seamount, Jr., Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2L~317A Sidetrack Surface Location: 192' FNL, 748' FEL Sec. 22, T10N R7E, UM or ASP4, NAD 27 coordinates of X=460,903 & Y=5,927,654 Sidetrack Location: 772' FSL, 553' FWL Sec. 24, T10N, R7E, UM Target Location: 38' FSL, 2533' FEL Sec. 24, T10N, R7E, UM Bottom Hole Location: 103' FNL, 2011' FEL Sec. 25, T10N, R7E, UM Dear Commissioner Seamount, Phillips Alaska, Inc. hereby files this Application for Permit to Drill (sidetrack) the development well KRU 2L-317. The original wellbore was drilled to a TD of 14,161' MD on 12/7/00 and encountered insufficient net pay for completing the well. Plans to sidetrack were discussed with Tom Maunder. The sidetrack location is approximately 1826' from the current bottom hole location and we plan to complete the well as an injector. Nabors Rig 19e will sidetrack the well. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be 15umped down an approved and existing annulus on Drillsite 2L, or hauled to an approved Prudhoe or GKA Class II disposal well. Also note that Phillips Alaska, Inc. does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. The following are Phillips' designated contacts for reporting responsibilities to the Commission: 1) Completion Report Sharon AIIsup-Drake, Drilling Technologist 263-4612 (20 AAC 25.070) 2) Geologic Data and Logs Bill Morris, Geologist 263-4588 (20 AAC 25.071) If you have questions or require additional information, please contact Brian Noel at 265- 6979 or me at 265-6434 in our Anchorage office. Sincerely, James Trantham Drilling Engi.neering Supervisor Attachments: Information as required cc: KRU 2L-317AWell File RECEIVED DEC 1 1 2000 Alaska Oil & Gas Cons. C0mmissJor Anchorage Phillips Alaska, Inc. is a Subsidiary of Phillips 66 Phillips Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD-Injector KRU 2L-317A Sidetrack Current wellbore status: Surface casing was set at 3461' MD and cemented with full returns to surface. Production hole was drilled to 14,161' MD with the Tarn (Bermuda) interval top (T3.1) picked at 13,462' MD, but there was not enough net pay to complete. The rig is in the process of setting a continuous 15.8 ppg class G cement plug from TD to 13,300' MD to cover the entire Bermuda interval. Then 300' of 17.0 ppg class G cement will be set from 9650-9350' MD for a kick-off plug. The plan is to sidetrack to a new bottom hole location target in the Bermuda interval approximately 1829' north & west of the current BHL as follows: 1. Sidetrack off cement plug at--MD and drill 6-3/4" hole to TD according to directional plan. Run LWD logging equipment with gamma ray, resistivity, and density-neutron tools. Note: If significant.hydrocarbon zones are present above the intermediate casing point, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 2. Run and cement 5-1/2" L-80 BTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 3. Pressure test casing to 3,500 psi. 4. 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. 5. Set TWC, ND BOPE and install production tree. 6. Secure well. Rig down and move out. 7. Handover well to Operations Personnel. (Cement bond log will be run prior to perforating well). RECEIVED DEC 1 1 2000 Alaska Oil & Gas Cons, C0mmissior Anchorage Phillips Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2L-317A Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Kick off to TD 9.0-9.6 ppg 6-20 5-20 35-50 2-6 4-8 <6 through Tarn 9-10 <11% RECEIVED DEC ? 1 00o Alaska Oil & Gas Cons. Commission Anchorage Drillinq Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Degasser Fluid Agitators Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calCulated using a reservoir pressure of 2400 psi at a target mid-point of 5546' TVD. Gas gradient is anticipated to be 0.1 psi/ft. Using this data, the MASP is calculated to be: MASP=((2400/5546)-0.1 )*5546 MASP=1845 psi Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2L pad are expected to be -2,400 psi (0.43 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 8.9 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,546'. Target (Midpoint T2-T3) (2400+150)/(0.052'5546)=8.84. Phillips Alaska, Inc. RECEIVED Well Proximity Risks: The nearest well to 2L-317A is 2L-321. sidetrack depth of 9500'. DEC 1 I 2000 Alaska 0il & Gas Cons. Commission The wells are1060' from eac~C~l~r at the Drillinq Area Risks: Analysis of pressure data from offset wells shows that a mud weight of 9.0-9.5 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 7-5/8" casing shoe was tested after drill out on 11/21/00 to leak-off, which calculated to a 13.6 ppg EMW at 3501' TVD. 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 2L-317A sidetrack surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. Following drilling operations, ARCO Alaska, Inc. will submit application for approval of 2L-317A sidetrack 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. = (12.0 ppg) * (0.052) * Max Pressure = 2,935 psi Shoe TVD) + 1,500 psi (2,300') + 1,500 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Phillips Alaska, Inc. 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 BTC-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 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). RECEIVED DEC 1 1 2000 Alaska 0il & Gas Cons. C0mmissior~ Anchorage Tarn 2L-317A Injector Proposed Completion Schematic PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Conductor 16" 62.5# H-40 (105' MD / 105' TVD) Surface csg, 7 5/8" 29.7# L-80 BTCM (3461' MD / 2317' TVD) All Depths Reference Nabors 19E RKB Production csg. 5-1/2" 15.5# L-80 BTC Mod run from XO/CSR to surface (+/- 11,927' MD / 5345' TVD) Production csg. 3-1/2" 9.3# L-80 EUE 8rd Mod run TD to XO/CSR (+/- 12,937' MD / 5931' TVD) L. 3-1/2" 5M FMC Gen 5 tubing hanger with 3-1/2" L-80 EUE 8rd Mod pin down. K. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to surface. J. 3-1/2" Camco 'DS' landing nipple with 2.875" No-Go profile set at +/-500'. I. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to 'DS' landing nipple. H. 3-1/2" x 1" Camco 'KBG-2-9' Mandrel w/DV and latch at +/-2250' MD. 3-1/2" x 6' L-80 handling pups installed on top & bottom of GLM. G. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to mandrel. F. 3-1/2" Baker 'CMU' sliding sleeve with 2.813" Camco profile. E. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing. D. 3-1/2" x 1" Camco 'KBG-2-9' Mandrel w/DV and latch. 3-1/2" x 6' L-80 handling pups installed on top & bottom of GLM. C. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing. B. 3-1/2" Camco 'D' landing nipple with 2.75" No-Go profile. A. Baker 3-1/2" 'GBH-22' Locator Seal Assembly w/12' of seals & Iocator 3-1/2" x 6' handling pup installed on top. EUE 8RD-Mod box up. Baker XO - CSR top sub (Iocator seat) Baker 80-40 5-1/2" x 3-1/2" Casing Seal Receptacle (CSR) Baker XO - set at +/- 11,927' MD / 5345' TVD (200' MD above T3 top) Future Thru-Tubing Perforations RECEIVED DEC 1 1 2000 Alaska 0il & Gas Cons. Commission Anchorage BDN, 12/08/00, vl Slructure : 7am Drill Site 2L Well : 317A Field :'larn Developmeni Field location : North Slope, Alaska Vertical Section (feet) Slruciure : lam Drill Site 2L Well ; $17A i:ield : Yarn Developmenl Field Location : Norfh Slope, Alaska East (feet) Created by finch For: B Noel Dute p~otted: 7-De<:-2000 Plot Reference is 5I?A Version ~2. True Vertical Depths om reference RK8 (Nobors 19E) Phillips Alaska, Inc. Structure : Tarn Drill Site 2L Well : 517A Field : T(~rn Development Field Loc(]fion : North Slope, PROFILE COMMENT DATA Point Tie-In Survey KOP- Sidetrack Pt C40 EOC --. C57 18 B o CD · T7 T5 Target- Mid Bermuda T2 C55 MD Inc Dir TVD 9498.72 9500.00 10031.95 10546.05 10576.85 10816.45 11299.15 12126.65 12275.16 12419.69 12656.90 73.32 75.52 61.20 54.54 54.54 54.54 54.54 54.54 54.54 54.54 54.54 124.25 124.25 112.95 105.07 105.07 105.07 105.07 105.07 105.07 105.07 105.07 4054.84 4055.21 4261.00 4428.15 4446.00 4701.00 4981.00 5461.00 5546.00 5651.00 5757.00 North -4515.61 -4514.50 -4550.12 -4637.25 -4645.78 -4756.88 -4859.11 -5014.57 -5045.40 -5076.45 -5122.44 East 6586.50 6587.52 7015.31 7266.14 7290.57 7636.15 8015.79 8666.65 8781.90 8897.15 9068.00 V. Sect 7859.75 7860.98 8549.56 8610.45 8654.71 8980.90 9561.05 10012.68 10128.07 10245.47 10414.52 Deg/1 O0 0.00 0.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TD - Casing Pt 12956.90 54.54 105.07 5951.02 -5185.97 9505.96 10650.77 0.00 S, 3 Eas: (feet) -> . 66:39 · 68co Phillips Alaska, Inc. Tarn Drill Site 2L 317A slot #317 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 317A Version #2 Our ref : prop4314 License : Date printed : 7-Dec-2000 Date created : 4-Dec-2000 Last revised : 7-Dec-2000 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 12 49.742,w150 18 33.414 Slot location is n70 12 47.863,w150 18 55.129 Slot Grid coordinates are N 5927654.439, E 460902.699 Slot local coordinates are 191.01 S 748.01 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath Closest approach with 3-D Minimum Distance method Last revised Distance M.D. 1340.3 11400.0 11400 3056.4 9498.7 9498 2244.3 9498.7 9498 3425.5 9498.7 9498 8624.3 9498.7 9498 8624.3 9498.7 9498 3785.9 9498.7 9498 1060.0 9498.7 9498 1742.0 9498.7 9498 0.0 9498.7 9498 PMSS <0-11140'>,,313,Tarn Drill Site 2L 18-Mar-1999 315 PMSS <0-8236'>,,315,Tarn Drill Site 2L 29-Dec-1998 PMSS <0-9727'>,,307,Tarn Drill Site 2L 4-Apr-1999 PMSS <0-9200'>,,325,Tarn Drill Site 2L 19-Nov-1998 PMSS <0-6864'>,,Arete,Tarn Drill Site 2L 14-Mar-2000 329A PMSS <2506 - 6190'),,329A, Tarn Drill Site 16-Nov-1998 PMSS <0-9210'>,,305,Tarn Drill Site 2L 15-Dec-1998 PMSS <0-12403'>,,321,Tarn Drill Site 2L il-Jan-1999 323 PMSS <0-10400'>,,323,Tarn Drill Site 2L 29-Dec-1998 PMSS <0-14161'>,,317,Tarn Drill Site 2L 7-Dec-2000 Diverging from M.D. RECEIVED DEC 2000 Alaska Oil & Gas Cons, Commission Anchorage Phillips Alaska, Inc. Tarn Drill Site 2L 317A slot #317 Tarn Development Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 317A Version #2 Our ref : prop4314 License : Date printed : 7-Dec-2000 Date created : 4-Dec-2000 Last revised : 7-Dec-2000 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on n70 12 49.742,w150 18 33.414 Slot location is n70 12 47.863,w150 18 55.129 Slot Grid coordinates are N 5927654.439, E 460902.699 Slot local coordinates are 191.01 S 748.01 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 200 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 <0-11140'>,,313,Tarn Drill Site 2L 18-Mar-1999 315 PMSS <0-8236'>,,315,Tarn Drill Site 2L 29-Dec-1998 PMSS <0-9727'>,,307,Tarn Drill Site 2L 4-Apr-1999 PMSS <0-9200'>,,325,Tarn Drill Site 2L 19-Nov-1998 PMSS <0-6864'>,,Arete,Tarn Drill Site 2L 14-Mar-2000 329A PMSS <2506 - 6190'),,329A,Tarn Drill Site 16-Nov-1998 PMSS <0-9210'>,,305,Tarn Drill Site 2L 15-Dec-1998 PMSS <0-12403'>,,321,Tarn Drill Site 2L ll-Jan~1999 323 PMSS <0-10400'>,,323,Tarn Drill Site 2L 29-Dec-1998 PMSS <0-14161'>,,317,Tarn Drill Site 2L 7-Dec-2000 Closest approach with Last revised Distanc. )874.8 2890.7 1789.4 2783.3 8603.7 8603.7 3355.7 )308.4 1376.2 )0.0 3-D Minimum'Distance method M.D. 11240 0 9498 7 9498 7 9498 7 9498 7 9498 7 9498 7 11180 0 9498 7 10420 0 Diverging from M.D. 11240 9498 9498 9498 9498 11780 9498 12400 10460 10420 RECEIVED DEC 7 2000 Alaska Oil & Gas Cons. COmmission Anchorage Phillips Alaska, Inc. CLEARANCE LISTING Page 1 Tarn Drill Site 2L,317A ~- Your ref : 317A ?. 'sion #2 Tarn Development Field,North Slope, Ai~ Last revised 7-D~ 00 Reference wellpath Object wellpath : PMSS <0-14161'>,,317,Tarn Drill Site 2L Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 9500.0 4055.2 4314.3S 6587.3E 9500.0 4055.2 4314.3S 6587.3E 297.3 0.0 )0.0 9600.0 4085.9 4366.5S 6666.9E 9600.0 4084.7 4368.0S 6666.3E 201.0 1.9 )0.0 9700.0 4120.3 4415.2S 6747.1E 9699.7 4113.7 4420.8S 6745.7E 193.9 8.8 )0.0 9800.0 4158.6 4460.3S 6827.8E 9798.8 4142.4 4474.4S 6824.1E 194.7 21.8 )0.0 9900.0 4200.4 4501.6S 6908.7E 9897.4 4171.5 4527.6S 6901.8E 194.8 39.5 )0.0 10000.0 4245.8 4539.0S 6989.5E 9994.6 4200.6 4580.2S 6978.2E 195.4 62.1 )0.0 10100.0 4294.6 4572.4S 7070.1E 10089.1 4229.4 4633.0S 7051.1E 197.4 91.0 )0.0 10200.0 4346.6 4601.8S 7150.3E 10181.9 4257.4 4686.1S 7121.8E 198.7 126.0 )0.0 10300.0 4401.7 4627.1S 7229.8E 10274.2 4285.4 4739.2S 7192.0E 198.7 165.9 )0.0 10400.0 4459.4 4648.7S 7308.6E 10365.8 4312.3 4790.7S 7262.7E 197.9 209.6 )0.0 10500.0 4517.4 4669.9S 7387.2E 10461.9 4341.7 4843.3S 7337.6E 196.0 251.8 )6.1 10600.0 4575.4 4691.0S 7465.9E 10551.8 4370.3 4892.4S 7407.3E 196.2 293.4 )29.7 10700.0 4633.4 4712.2S 7544.5E 10642.4 4398.6 4941.9S 7477.7E 196.2 335.2 )57.7 10800.0 4691.5 4733.4S 7623.2E 10735.3 4426.8 4991.7S 7550.9E 195.6 376.8 )87.1 10900.0 4749.5 4754.6S 7701.8E 10826.9 4454.3 5040.0S 7623.7E 195.3 418.0 117.6 11000.0 4807.5 4775.8S 7780.5E 10914.3 4480.6 5086.6S 7692.7E 195.8 459.6 11100.0 4865.5 4796.9S 7859.2E 11002.3 4507.2 5134.6S 7761.6E 196.1 501.9 148.7 179.7 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #317 and TVD from RKB (Nabors 19E) (151.00 Ft above mean sea level Vertical section is from wellhead on azimuth 119.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ DEC 000 Alaska Oil & 6as Cons. O0mmissi0~ Anchorage Phillips Alaska, Inc. Tarn Drill Site 2L 317A slot #317 Tarn Development Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 317A Version #2 Our ref : prop4314 License : Date printed : 7-Dec-2000 Date created : 4-Dec-2000 Last revised : 7-Dec-2000 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 12 49.742,w150 18 33.414 Slot location is n70 12 47.863,w150 18 55.129 Slot Grid coordinates are N 5927654.439, E 460902.699 Slot local coordinates are 191.01 S 748.01 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED DEC 7 7 2.000 Alaska 011 & Gas Cons. Cornmissior~ Anchorage Phillips Alaska, Inc. Tarn Drill Site 2L,317A Tarn Development Field,North Slope, Al. Measured Inclin. Azimuth True Vert R E C Depth Degrees Degrees Depth C 0 0 TANGULAR RDINATES 9498.72 73.32 124.25 4054.84 4313 9500.00 73.32 124.25 4055.21 4314 9600.00 70.99 122.27 4085.85 4366 9700.00 68.67 120.23 4120.34 4415 9800.00 66.39 118.13 4158.56 4460 .61 S 6586.30 E .30 S 6587.32 E .51 S 6666.90 E .21 S 6747.13 E .27 S 6827.79 E 9900.00 64.13 115.96 4200.41 4501 10000.00 61.91 113.70 4245.78 4539 10031.95 61.20 112.95 4261.00 4550 10100.00 59.72 111.34 4294.55 4572 10200.00 57.58 108.88 4346.58 4601 .57 S 6908.66 E .00 S 6989.52 E .12 S 7015.31 E .45 S 7070.15 E .82 S 7150.32 E 10300.00 55.49 106.30 4401.73 10346.05 54.54 105.07 4428.13 10376.85 54.54 105.07 4446.00 10500.00 54.54 105.07 4517.43 10816.45 54.54 105.07 4701.00 4627.05 S 7229.82 E 4637.25 S 7266.14 E 4643.78 S 7290.37 E 4669.86 S 7387.23 E 4736.88 S 7636.13 E 11000.00 54.54 105.07 4807.47 11299.15 54.54 105.07 4981.00 11500.00 54.54 105.07 5097.51 12000.00 54.54 105,07 5387.55 12126.63 54.54 105.07 5461.00 4775.76 S 7780.50 E 4839.11 S 8015.79 E 4881.65 S 8173.77 E 4987.55 S 8567.05 E 5014.37 S 8666.65 E 12273.16 54.54 105.07 5546.00 12419.69 54.54 105.07 5631.00 12500.00 54.54 105.07 5677.59 12636.90 54.54 105.07 5757.00 12936.90 54.54 105.07 5931.02 5045.40 S 8781.90 E 5076.43 S 8897.15 E 5093.44 S 8960.32 E 5122.44 S 9068.00 E 5185.97 S 9303.96 E PROPOSAL LISTING Page 1 Your ref : 317A~ sion #2 Last revised 7-D~ ~00 Dogleg Vert Deg/100ft Sect 0.00 7859.75 Tie-In Survey 0.00 7860.98 KOP- Sidetrack Pt 3.00 7955.99 3.00 8049.81 3.00 8142.20 3.00 8232.90 3.00 8321.66 3.00 8349.56 C40 3.00 8408.23 3.00 8492.38 3.00 8573.88 3.00 8610.45 EOC 0.00 8634.71 C37 0.00 8731.69 0.00 8980.90 T8 0.00 9125.45 0.00 9361.03 T7 0.00 9519.20 0.00 9912.96 0.00 10012.68 T3 0.00 10128.07 Target- Mid Bermuda 0.00 10243.47 T2 0.00 10306.71 0.00 10414.52 C35 0.00 10650.77 TD - Casing Pt Ail data is in feet unless otherwise stated. Coordinates from slot #317 and TVD from RKB (Nabors 19E) (151.00 Ft above mean sea level Bottom hole distance is 10651.67 on azimuth 119.14 degrees from wellhead. Total Dogleg for wellpath is 25.38 degrees. Vertical section is from wellhead on azimuth 119.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Tarn Drill Site 2L,317A ~' Tarn Development Field,North Slope, A1 PROPOSAL LISTING Page 2 Your ref : 317A ~ ~$ion #2 Last revised 7-D~ 00 Comments in wellpath MD TVD Rectangular Coords. Comment 9498.72 9500.00 10031.95 10346.05 10376.85 10816.45 11299 15 12126 63 12273 16 12419 69 12636 90 12936 90 4054.84 4313.61 S 6586.30 E Tie-In Survey 4055.21 4314.30 S 6587.32 E KOP- Sidetrack Pt 4261.00 4550.12 S 7015.31 E C40 4428.13 4637.25 S 7266.14 E EOC 4446.00 4643.78 S 7290.37 E C37 4701.00 4736.88 S 7636.13 E T8 4981.00 4839.11 S 8015.79 E T7 5461.00 5014.37 S 8666.65 E T3 5546.00 5045.40 S 8781.90 E Target- Mid Bermuda 5631.00 5076.43 S 8897.15 E T2 5757.00 5122.44 S 9068.00 E C35 5931.02 5185.97 S 9303.96 E TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 4054.84 4313.61S 6586.30E n/a 4054.84 4313.61S 6586.30E 7 5/8'' Casing n/a 4054.84 4313.61S 6586.30E 14306.90 5931.02 5185.97S 9303.96E 5 1/2'' Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2L-317ST Rvsd 7-Dec- 469658.000,5922565.000,0.0000 5546.00 5045.40S 8781.90E 4-Dec-2000 Oil & ?a~ Phillips Alaska, Inc. Tarn Drill Site 2L 317A slot #317 Tarn Development Field North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 317A Version #2 Our ref : prop4314 License : Date printed : 7-Dec-2000 Date created : 4-Dec-2000 Last revised : 7-Dec-2000 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on nT0 12 49.742,w150 18 33.414 Slot location is n70 12 47.863,w150 18 55.129 Slot Grid coordinates are N 5927654.439, E 460902.699 Slot local coordinates are 191.01 S 748.01 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. Tarn Drill Site 2L,317A ~' Tarn Development Field,North Slope, A1 PROPOSAL LISTING Page 1 Your ref : "sion #2 317A Last revised 7-D~ Measured Inclin. Azimuth True Vert R E C T A N G U L A R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth C O O R D I N A T E S Sect Major Minor Vert. Azi. 9498.72 73.32 124.25 4054.84 4313.61 S 6586.30 E 7859.75 596.16 34.39 79.27 303.19 9500.00 73.32 124.25 4055.21 4314.30 S 6587.32 E 7860.98 596.25 34.39 79.28 303.19 9600.00 70.99 122.27 4085.85 4366.51 S 6666.90 E 7955.99 603.63 34.75 80.25 303.18 9700.00 68.67 120.23 4120.34 4415.21 S 6747.13 E 8049.81 610.93 35.14 81.19 303.15 9800.00 66.39 118.13 4158.56 4460.27 S 6827.79 E 8142.20 618.11 35.56 82.11 303.09 9900.00 64.13 115.96 4200.41 4501.57 S 6908.66 E 8232.90 625.15 36.00 82.99 303.01 10000.00 61.91 113.70 4245.78 4539.00 S 6989.52 E 8321.66 632.00 36.46 83.84 302.91 10031.95 61.20 112.95 4261.00 4550.12 S 7015.31 E 8349.56 634.12 36.61 84.10 302.87 10100.00 59.72 111.34 4294.55 4572.45 S 7070.15 E 8408.23 638.64 36.94 84.66 302.78 10200.00 57.58 108.88 4346.58 4601.82 S 7150.32 E 8492.38 645.03 37.43 85.44 302.64 10300.00 55.49 106.30 4401.73 4627.05 S 7229.82 E 8573.88 651.15 37.93 86.19 302.49 10346.05 54.54 105.07 4428.13 4637.25 S 7266.14 E 8610.45 653.91 38.17 86.53 302.41 10376.85 54.54 105.07 4446.00 4643.78 S 7290.37 E 8634.71 655.76 38.32 86.75 302.36 10500.00 54.54 105.07 4517.43 4669.86 S 7387.23 E 8731.69 663.14 38.95 87.65 302.16 10816.45 54.54 105.07 4701.00 4736.88 S 7636.13 E 8980.90 682.17 40.57 89.97 301.68 11000.00 54.54 105.07 4807.47 4775.76 S 7780.50 E 9125.45 693.21 41.51 91.31 301.40 11299.15 54.54 105.07 4981.00 4839.11 S 8015.79 E 9361.03 711.26 43.04 93.50 300.98 11500.00 54.54 105.07 5097.51 4881.65 S 8173.77 E 9519.20 723.39 44.07 94.98 300.70 12000.00 54.54 105.07 5387.55 4987.55 S 8567.05 E 9912.96 753.66 46.65 98.64 300.06 12126.63 54.54 105.07 5461.00 5014.37 S 8666.65 E 10012.68 761.35 47.30 99.56 299.91 12273.16 54.54 105.07 5546.00 ~045.40 S 8781.90 E 10128.07 770.24 48.06 100.64 299.73 12419.69 54.54 105.07 5631.00 5076.43 S 8897.15 E 10243.47 779.15 48.82 101.71 299.56 12500.00 54.54 105.07 5677.59 5093.44 S 8960.32 E 10306.71 784.03 49.23 102.30 299.47 12636.90 54.54 105.07 5757.00 5122.44 S 9068.00 E 10414.52 792.36 49.94 103.30 299.31 12936.90 54.54 105.07 5931.02 5185.97 S 9303.96 E 10650.77 810.62 51.50 105.49 298.99 POSITION UNCERTAINTY SUMMARY Depth' Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 9499 ARCO (H.A. Mag) User specified 596.16 34.39 79.27 9499 12937 ARCO (H.A. Mag) User specified 810.62 51.50 105.49 1 Ellipse dimensions are half axis. 2 Casing dimensions are not included. 3 Ellipses are calculated on 2.58 standard deviations. 4 Uncertainty calculations start at drill depth zero. 5 Surface position uncertainty is not included. 6 Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Ail data is in feet unless otherwise stated. Coordinates from slot #317 and TVD from RKB (Nabors 19E) (151.00 Ft above mean sea level). Bottom hole distance is 10651.67 on azimuth 119.14 degrees from wellhead. Vertical section is from wellhead on azimuth 119.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Tarn Drill Site 2L,317A Tarn DeveloDment Field,North Slope, A1 PROPOSAL LISTING Page 2 Your ref : 317A~,' sion ~2 Last revised 7-D~ ,00 Comments in wellpath .................... MD TVD Rectangular Coords. Comment 9498.72 9500.00 10031.95 10346.05 10376.85 10816.45 11299 15 12126 63 12273 16 12419 69 12636 90 12936 90 4054.84 4313 4055.21 4314 4261.00 4550 4428.13 4637 4446.00 4643 4701.00 4736 4981.00 4839 5461.00 5014 5546.00 5045 5631.00 5076 5757.00 5122 5931.02 5185 61 S 6586.30 E Tie-In Survey 30 S 6587.32 E KOP- Sidetrack Pt 12 S 7015.31 E C40 25 S 7266.14 E EOC 78 S 7290.37 E C37 88 S 7636.13 E T8 .11 S 8015.79 E T7 .37 S 8666.65 E T3 .40 S 8781.90 E Target- Mid Bermuda .43 S 8897.15 E T2 .44 S 9068.00 E C35 .97 S 9303.96 E TD - Casing Pt Casing positions in string 'A' ToD MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 4054.84 4313.61S 6586.30E n/a 4054.84 4313.61S 6586.30E 7 5/8'' Casing n/a 4054.84 4313.61S 6586.30E 14306.90 5931.02 5185.97S 9303.96E 5 1/2'' Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2L-317ST Rvsd 7-Dec- 469658.000,5922565.000,0.0000 5546.00 5045.40S 8781.90E 4-Dec-2000 ~,. -.,,#eeion American Express' Cash Advance Draft 102 DATE ~)~~ ~ ~ ~---~-~)-~o~, o:~, I~u~ ~ Inm~m~d Pay~n[ S~m, Inc, En~w~, Co~do NOT VALID FOE AHOUNT OVEE $1~ / P,~, ,t No~, B~k of G--d Jun~n - Down~wn, N~ ~~ON ~U~~ .~R,0. ~.~,.~ &~- ~I~ ~ ~:~O~iOOhOO~155 .,,Oi?5DOO55~""OiO~ WELL PERMIT cHECKLIST COMPANY /~[t..//~'/,i~_5' WELL NAME ,,?-/--.- ~'/'7~ PROGRAM: exp ~ dev ~ redrll ~ serv v~ wellbore sag ~ FIELD & POOL ~'~/_~ ~"" INIT CLASS'~C_.~/~ (/'/d~_--- ,,/'/_~'~lt~;/A,/' GEOL AREA ~d~ UNIT# (~ //'/C/_~ ~ !ADMINISTRATION DATE ENGINEERING DATE 1. Permit fee attached. 2. Lease number approl:;ri;t;.'~. '.~-.i '.~/. ".~<'~. '.~./i ~.~ i~.~ / 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available' in drilling unit ............ 8. If deviated, is wellbore plat included ............. ·.. 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .~,~r,~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur wi. thout operation shutdown ........... 29. Is presence of H2S gas probable ................. ann. disposal para req ~ ON/OFF SHORE . ) N ~ N GEOLOGY AP~PR DATE ,~1'~ i z . It.or:, ANNULAR DISPOSAL35, With proper cementing records, this plan (A) will contain waste in a.suitable receiving zonei ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. 31. Data presented on potential overpressure zones y 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition suwey (if off-shore) ............. ?N 34. Contact name/phone for weekly progress repo~s [ex~ bnly] Y N Y N Y N Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ,,~'"~ t~t/I. (. J U H ""'---_~ ,._A'iU: Commentsllnstructions: 0 Z 0 Z -I -I- c:\msoffice\wordian\diana\checklist (rev. 11/01//00) 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 APPE .N. DIXi No 'special'effort has been made to chronologically organize this category of information. c DD-- 1o Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed May 09 16:18:42 2001 Reel Header Service name ............. LISTPE Date ..................... 01/05/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/05/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Cou~ents ................. 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: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-00271 B. HENNINGSE D. GLADDEN 2L-317 A 501032033601 Phillips Alaska Inc. Sperry Sun 09-MAY-01 MWD RUN 2 AK-MM-00271 D. LABRECQUE M. WHITELEY MWD RUN 4 AK-MM-00271 B. HENNINGSE D. GLADDEN 22 i0N 7 E 192 748 152.81 151.48 117.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.500 7.625 3461.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 & 2 (FROM 2L-317) WERE DIRECTIONAL, WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. WELL 2L-317 WAS.SIDETRACKED AT A DEPTH OF 9455'MD / 4042'TVD, AT WHICH POINT RUN 4 BEGAN. 4. MWD RUN 4 WAS DIRECTIONAL WITH DGR, EWR4, COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHWARTZ, PHILLIPS ALASKA, DATED 1/30/01. 6. MWD RUNS 1, 2, & 4 REPRESENT WELL 2L-317A WITH API%:50-103-20336-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12655'MD / 5785.19'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 RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 7.5" & 6.75" MUD WEIGHT: 9.6 - 9.7 PPG MUD SALINITY: 350 - 500 PPM CHLORIDES FORMATION WATER SALINITY: 24000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP NCNT NPHI FCNT DRHO RHOB PEF $ START DEPTH 3400 5 3407 0 3407 0 3407 0 3407 0 3407 0 3461 0 9376.5 9377.0 9377.0 9392.0 9392.0 9392.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 1 3400.5 8474.0 2 8414.0 9460.0 4 9376.5 12654.5 STOP DEPTH 12611 5 12618 5 12618 5 12618 5 12618 5 12618 5 12654 5 12573 5 12573 5 12574 5 12590 0 12590 0 12590 0 EQUIVALENT UNSHIFTED DEPTH Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD (API 4 1 68 4 2 ROP MWD (FPH 4 1 68 8 3 RPX MWD (OHM 4 1 68 12 4 RPS MWD (OHM 4 1 68 16 5 RPM MWD (OHM 4 1 68 20 6 RPD MWD (OHM 4 1 68 24 7 FET MWD (HR) 4 1 68 28 8 NPHI MWD (PU) 4 1 68 32 9 FCNT MWD (CP3 4 1 68 36 10 NCNT MWD (CP3 4 1 68 40 11 RHOB MWD (G/C 4 1 68 44 12 DRHO MWD (G/C 4 1 68 48 13 PEF MWD (B/E 4 1 68 52 14 Name Service Unit DEPT GR MWD ROP MWD RPX MWD RPS MWD RPM MWD RPD MWD FET MWD NPHI MWD FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD FT API FPH OHM OHM OHM OHM HR) PU) CP3 CP3 SIC G/C B/E Min Max Mean Nsam 3400.5 12654.5 8027.5 18509 43.03 239.46 130.372 18423 0 214.79 73.0658 18388 0.95 1485.66 4.73127 18424 0.53 2000 5.44931 18424 1.19 2000 10.6408 18424 0.32 2000 13.1523 18424 0.6 334.18 2.97297 18424 10.51 56.91 33.0216 6394 133.4 1135.9 316.13 6396 15646.7 35740.8 22226.8 6395 1.369 3.194 2.41077 6397 -0.04 0.73 0.074738 6397 2.1 9.17 3.29887 6397 First Reading 3400.5 3400.5 3461 3407 3407 3407 3407 3407 9377 9377 9376.5 9392 9392 9392 Last Reading 12654 5 12611 5 12654 5 12618 5 12618 5 12618 5 12618 5 12618 5 12573 5 12574 5 12573 5 12590 12590 12590 First Reading For Entire File .......... 3400.5 Last Reading For Entire File ........... 12654.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... 'Version Number ........... 1.0.0 Date of Generation ....... 01/05/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPM RPS RPX RPD FET ROP $ 3400 5 3407 0 3407 0 3407 0 3407 0 3407 0 3461 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) STOP DEPTH 8413.5 8419 5 8419 5 8419 5 8419 5 8419 5 8474 0 27-NOV-00 Insite 4.15 Memory 8474.0 70.4 75.4 TOOL NUMBER PB01735GRV4 PB01735GRV4 7.500 LSND 9.60 49.0 9.7 600 6.0 MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY IHZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 2.510 1.567 1. 980 -2.630 68.0 113.0 68.0 68.0 Name Service Order Units Size Nsam Rep, Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD010 API 4 1 68 4 2 ROP MWD010 FT/H 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 3400.5 8474 GR MWD010 API 58.06 174.72 ROP MWD010 FT/H 1 214.79 RPX MWD010 OHMM 0.95 1485.66 RPS MWD010 OHMM 0.53 2000 RPM MWD010 OHMM 2.14 2000 RPD MWD010 OHMM 0.32 2000 FET MWD010 HOUR 0.62 7.38 Mean Nsam 5937.25 10148 122.808 10027 81.7193 10027 5.14236 10026 6.36586 10026 14.7345 10026 20.0034 10026 1.4776 10026 First Reading 3400.5 3400.5 3461 3407 3407 3407 3407 3407 Last Reading 8474 8413.5 8474 8419.5 8419.5 8419.5 8419.5 8419.5 First Reading For Entire File .......... 3400.5 Last Reading For Entire File ........... 8474 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8414 0 9460 0 FET 8420 0 9419 5 RPD 8420 0 9419 5 RPM 8420 0 9419 5 RPS 8420 0 9419 5 RPX 8420 0 9419 5 ROP 8474 5 9460 0 $ # LOG HEADER DATA DATE LOGGED: 05-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9455.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 54.9 MAXIMUM ANGLE: 74.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS TOOL NUMBER PB01735GRV4 PB01735GRV4 7.500 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 LSND 9.60 46.0 9.0 3O0 4.0 1.900 1.092 1.930 1.950 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 73.0 132.0 73.0 73.0 Name Service Unit DEPT FT GR MWD020 API ROP MWD020 FT/H RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR Min 8414 43.03 2 48 1 84 1 93 2 08 2 19 0 81 Max 9460 230 03 145 64 23 19 18 76 22 82 14 16 26 28 Mean Nsam 8937 2093 145.959 2093 63.8963 1972 4.16281 2000 4.29245 2000 4.60947 2000 4.73305 2000 2.98726 2000 First Reading 8414 8414 8474.5 8420 8420 8420 8420 8420 Last Reading 9460 9460 9460 9419.5 9419.5 9419.5 9419.5 9419.5 First Reading For Entire File .......... 8414 Last Reading For Entire File ........... 9460 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... t.0.0 Date of Generation ....... 01/05/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. 4 .5000 BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT PEF RHOB DRHO GR RPM RPS RPD FET RPX ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 9376 5 9377 0 9377 0 9392 0 9392 0 9392 0 9413 0 9420 0 9420 0 9420 0 9420 0 9420 0 9460 5 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: STOP DEPTH 12573 5 12573 5 12574 5 12590 0 12590 0 12590 0 12611 5 12618 5 12618 5 12618 5 12618 5 12618 5 12654 5 18-DEC-00 Insite 4.15 Memory 12655.0 51.8 MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 70.8 TOOL NUMBER PB01729FGR4 PB01729FGR4 PB01729FGR4 PB01729FGR4 6.750 LSND 9.60 48.0 9.0 350 3.9 1.500 .781 1. 600 1.800 70.0 140.8 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT GR MWD040 ROP MWD040 RPX MWD040 RPS MWD040 RPM MWD040 RPD MWD040 FET MWD040 NPHI MWD040 FCNT MWD040 FT API FPH OHM OHM OHM OHM HR) PU) CP3 4 1 68 0 1 4 1 68 4 2 4 1 68 8 3 4 1 68 12 4 4 1 68 16 5 4 1 68 20 6 4 1 68 24 7 4 1 68 28 8 4 1 68 32 9 4 1 68 36 10 NCNT MWD040 RHOB MWD040 DRHO MWD040 PEF MWD040 (CP3 4 1 68 (G/C 4 1 68 (G/C 4 1 68 (B/E 4 1 68 40 44 48 52 11 12 13 14 Name DEPT GR ROP RPX RPS RPH RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Unit FT MWD040 AP1 MWD040 FPH MWD040 OHM MWD040 OHM MWD040 'OHM MWD040 'OHM MWD040 HR) MWD040 PU) MWD040 'CP3 MWD040 CP3 MWD040 SIC MWD040 G/C MWD040 B/E Min Max 9376.5 12654.5 61.92 239.46 0 113.38 1.14 24.96 1.16 45.55 1.19 2000 1.21 1672.16 0.6 334.18 10.51. 56.91 133.4 1135.9 15646.7 35740.8 1.369 3.194 -0.04 0.73 2.1 9.17 Mean 11015.5 137.002 62.3151 4.26477 4.37466 6.11106 5.04801 5.31184 33.0216 316.13 22226.8 2.41077 0.074738 3.29887 First Last Nsam Reading Reading 6557 9376.5 12654.5 6398 9413 12611.5 6389 9460.5 12654.5 6398 9420 12618.5 6398 9420 12618.5 6398 9420 12618.5 6398 9420 12618.5 6398 9420 12618.5 6394 9377 12573.5 6396 9377 12574.5 6395 9376.5 12573.5 6397 9392 12590 6397 9392 12590 6397 9392 -12590 First Reading For Entire File .......... 9376.5 Last Reading For Entire File ........... 12654.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 PhYsical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/05/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/05/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File