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Home My WebLink About198-077MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-34 KUPARUK RIV UNIT 3K-34 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 3K-34 50-029-22879-00-00 198-077-0 W SPT 6285 1980770 1571 2275 2275 2275 2275 320 470 470 470 4YRTST P Austin McLeod 12/26/2025 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 UNIT 3K-34 Inspection Date: Tubing OA Packer Depth 600 1760 1735 1730IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM251227122426 BBL Pumped:0.8 BBL Returned:0.8 Friday, January 16, 2026 Page 1 of 1            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. From:Brooks, Phoebe L (OGC) To:NSK DHD Field Supv Cc:Regg, James B (OGC) Subject:RE: 10-426 form for 3K-pad SI non-witnessed MIT-IA"s 5-8-25 Date:Wednesday, June 18, 2025 2:28:23 PM Attachments:image001.png Matt/Bruce, I made a minor revision, changing the report date to 05/08/25. Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: NSK DHD Field Supv <n2238@conocophillips.com> Sent: Thursday, May 8, 2025 6:41 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: NSK Wells Integrity Eng CPF1 & CPF3 <n1617@conocophillips.com> Subject: 10-426 form for 3K-pad SI non-witnessed MIT-IA's 5-8-25 Morning, Please see the attached 10-426 form from the 3K-pad SI non-witnessed MIT-IA’s that was performed on 5-8-25. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor .58. 37' KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1861020 Type Inj N Tubing 1275 1275 1275 1275 Type Test P Packer TVD 6420 BBL Pump 1.2 IA 450 2030 1975 1950 Interval 4 Test psi 1605 BBL Return 1.2 OA 25 30 25 25 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1861040 Type Inj N Tubing 1450 1450 1450 1450 Type Test P Packer TVD 6431 BBL Pump 2.0 IA 700 2010 1930 1910 Interval 4 Test psi 1608 BBL Return 2.0 OA 150 150 160 160 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1861250 Type Inj N Tubing 1350 1360 1360 1360 Type Test P Packer TVD 6564 BBL Pump 1.6 IA 300 2030 2010 2000 Interval 4 Test psi 1641 BBL Return 1.6 OA 10 10 10 10 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1861510 Type Inj N Tubing 1200 1250 1250 1250 Type Test P Packer TVD 6606 BBL Pump 1.2 IA 140 1900 1880 1880 Interval 4 Test psi 1652 BBL Return 1.2 OA 10 10 11 11 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1980810 Type Inj N Tubing 1340 1350 1350 1340 Type Test P Packer TVD 6548 BBL Pump 1.0 IA 700 2040 2030 2030 Interval 4 Test psi 1637 BBL Return 1.0 OA 320 480 480 480 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1970770 Type Inj N Tubing 1080 1210 1100 1090 Type Test P Packer TVD 6621 BBL Pump 1.2 IA 220 1940 1915 1910 Interval 4 Test psi 1655 BBL Return 1.2 OA 540 620 580 580 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1980820 Type Inj N Tubing 1340 1475 1425 1400 Type Test P Packer TVD 6117 BBL Pump 1.0 IA 100 2110 2080 2070 Interval 4 Test psi1529BBL Return1.0OA25252525 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1980770 Type Inj N Tubing 820 840 840 840 Type Test P Packer TVD 6275 BBL Pump 1.3 IA 200 1800 1790 1790 Interval 4 Test psi 1569 BBL Return 1.1 OA 25 40 40 40 Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting 3K-31 3K-34 Notes: 3K-25 3K-26 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: 3K-07 Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 3K Pad Gschwind/Sheets 05/08/28 Notes: Notes: Notes: Notes: 3K-02 3K-04 3K-18 Form 10-426 (Revised 01/2017)2025-0508_MIT_KRU_3K-34 9 9 9 9 999 99 9 9 9 9 -5HJJ 3K-34 MEMORANDUM TO: Jim Regg_ P.I. Supervisor TelC `J'1 yI// zez'( FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Cas Conservation Commission DATE: Tuesday, May 11, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3K-34 KUPARUK RIV UNIT 3K-34 Src: Inspector Reviewed By: P.I. Supry --,13e— Comm Well Name KUPARUK RIV UNIT 3K-34 API Well Number 50-029-22879-00-00 Inspector Name: Lou Laut enstein Permit Number: 198-077-0 Inspection Date: 5/4/2021 _ Insp Num: mitl.ol.zlosososzsst Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-34 Type Inj I w- ITVD 6285 . Tubing 2940 - 2940. 2940 - 2940 PTD 1 1980770 Type Test I SPT ITest psi 1571 - IA 680 2000 1960 - 1960 BBL Pumped: BBL Returned: I OA 40 - 40 40 40 Interval 4YRTST p/P P Notes: Tuesday, May 11, 2021 Page 1 of 1 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct 13, 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor Roger Mouser Digitally signed by Roger Mouser Date: 2020.10.13 13:10:42 -08'00' By Samantha Carlisle at 1:21 pm, Oct 13, 2020 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 10/13/20 2K 2M 3K 3O 3Q 3R 3S pad Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 2K-30 50103207580000 2170720 22" 0.3 6" 3/8/2020 2.5 9/29/2020 2K-32 50103207570000 2170420 29" 0.5 6" 3/8/2020 3 9/29/2020 2M-37 50103207450000 2160820 30" 0.4 9" 7/31/2020 2.1 9/29/2020 2M-38 50103207460000 2160830 4" N/A 4" N/A 2.5 9/29/2020 3K-32 50029227630000 1970760 10"Conductor extension 10" 4/27/2019 2.5 9/27/2020 3K-34 50029228790000 1980770 14" Conductor extension 14" 4/27/2019 9 9/27/2020 3O-01A 50029218360000 2151910 62" 0.70 11" 3/8/2020 4.25 9/27/2020 3O-19 50029227530000 1970500 13"Conductor extension 13" 4/27/2019 4.25 9/27/2020 3O-20 50029227500000 1970450 21 5.00 17" 9/27/2020 6 9/27/2020 3Q-22 50029226250000 1951860 20' 3.25 8" 3/8/2020 4.25 9/26/2020 3R-101 50029235740000 2170130 21" 0.40 8" 8/14/2020 1 9/26/2020 3R-102 50029235720000 2161570 54" 1.10 6" 8/14/2020 6 9/26/2020 3R-105 50029236510000 2191340 22" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-106 50029236410000 2190970 36" 0.60 9" 8/14/2020 3.5 9/26/2020 3R-107 50029236600000 2191810 32" 0.60 9.5" 8/14/2020 1 9/26/2020 3R-111 50029236430000 2191050 25" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-112 50029236370000 2190850 36" 0.60 14"8/14/2020 7 9/26/2020 3S-611 50103207740000 2181030 11' 10" 2.50 8"6/30/2019 2.5 9/27/2020 3S-612 50103207770000 2181110 43" 0.75 8" 6/30/2019 3.5 9/27/2020 3S-613 50103207350000 2160200 22" 0.75 8" 6/30/2019 1.7 9/27/2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 5 -RE 11 E -'LVED IHNJ 7 A min 1. Operations Abandon Plug Perforations Li cul Fracture Stimulate Li Pull Tubing Operationsshut wn Li Performed: Suspend El Perforate ❑ Other Stimulate ❑ Alter Casing ❑� ChaAG P r m ❑ Plug for Retlrill ❑ Perforate New Pool ❑ Repair Well Re-enter Susp Well ❑ Other: Conductor Extension❑✓ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 198-077 3. Address: Stratigraphic ❑ Service ❑� 6. API Number: P.O.Box 100360, Anchorage, Alaska 99510 50-029-22879-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025628, ADL002559, ADL0025629 KRU 3K-34 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N 11. Present Well Condition Summary: N/A Ku aruk River/Ku aruk River Oil Total Depth measured 13535' feet Plugs measured N/A feet true vertical 6872' feet Junk measured N/A feet Effective Depth measured 13535' feet Packer measured 12458' feet true vertical 6872' feet true vertical 6275' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 16" 121' 121/ Surface 7035' 7.625" 7076' 4016' Intermediate 12661' 5.5" 12690' 6384' Production Liner 1057' 3.5" 13535' 6872' Perforation depth Measured depth 13170-13276 feet True Vertical depth 6650-6713 feet Tubing (size, grade, measured and true vertical depth) 3.5" L-80 12486' 6287' Packers and SSSV (type, measured and true vertical depth) Baker Seal Assembly 12458' 6275' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A Subsequent to operation: N/A N/A N/A 14. Attachments (required per 20 AAC 25.07 7Data[O:] after work: TGSTOR Daily Report of Well Operations 21 ❑ Development ❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulat WINJ ❑✓ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-557 Authorized Name: Roger Mouser Contact Name: Roger Mouser/Roger Winter Authorized Title: Well Integrity Field Supervisor o Contact Email: N1927concoohillios com Authorized Signature: �'I A—y�/►1 Date: 06/14/2019 Contact Phone: 659-7506 VT7- 7/ 9// 9 Form 10-404 Revised 4/2017 .-f 01 /ter RBDMS ? JUN 2 12019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 14, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski: Enclosed please find the 10-404 Sundry from ConocoPhillips Alaska, Inc. well 3K-34, PTD# 198-077, Sundry # 318-557 for conductor extension. Please contact Roger Mouser or Roger Winter at 659-7506 if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor Date Event Summary Executive Summary 3K-34 conductor extension 04/27/19 lWelder welded 14" OAL of 16" 0.500 wall extension on top of existing conductor a�. Ahk RAMON ' I .e -: "Copyright 2019. All rights reserved. This r permission to copy for its own use. Copying prohibited without the express consent of Co 1' v a�. Ahk RAMON ' I .e -: "Copyright 2019. All rights reserved. This r permission to copy for its own use. Copying prohibited without the express consent of Co ,a- Il` is provided to the AOGCC with er purpose or by other party is Alaska, Inc" v s ,a- Il` is provided to the AOGCC with er purpose or by other party is Alaska, Inc" i. yright 2019. All rights reservA,,,.� tograph is provided to the A".. '-t, Al .permission to copy • • �- � -• Jam.. ti a • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Tuesday,May 16,2017 P.1.Supervisor 51 i ct(t 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-34 FROM: Chuck Scheve KUPARUK RIV UNIT 3K-34 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry n12-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-34 API Well Number 50-029-22879-00-00 Inspector Name: Chuck Scheve Permit Number: 198-077-0 Inspection Date: 5/10/2017 Insp Num: mitCS170510161630 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min --- Well 3K-34 Type Inj TVD 6285 = Tubing 2340 2340 - 2340 _ 2340 - PTD 1980770 Type Test SPT 1Test psi 1571 ' IA 730 1810 - 1790 1790 - BBL Pumped: 0.8 - BBL Returned: 0.7 - OA 210 350 - 350 - 350 Interval 4YRTST P/F P ✓ Notes: SCANNEDJUL 1 1 201?. Tuesday,May 16,2017 Page 1 of 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /'~'~--- Ct) ~ '~ File Number of Well History File PAGES TO DELETE RESCAN Complete [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of vadous kinds [] Other COMMENTS: Scanned by: Bevedy Mildred Dareth~owell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is/ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg DATE: Wednesday,May 15,2013 P.I.Supervisor -"Ref 511 7't 3 SUBJECT: Mechanical Integrity Tests ( CONOCOPHILLIPS ALASKA INC 3K-34 FROM: Bob Noble KUPARUK RIV UNIT 3K-34 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv3%- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-34 API Well Number 50-029-22879-00-00 Inspector Name: Bob Noble Permit Number: 198-077-0 Inspection Date: 5/12/2013 Insp Num: mitRCNl30513054724 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-34 Type Inj T W TVD bzss IA 740 2000 . 1980 1980 — Type Test. psi PTD Test ' 1571 . OA 120 140 _ � 140 140 YI? ✓ -- 1 077 P � 2900 2900 Interval aYRTST P/F P Tubing 2900 - F 2900 1 Notes: ScWED FEB 2 2014 Wednesday,M 1 2 1 Pae 1of1 ay 5, 0 3 g MEMORANDUM TO: Jim Regg ~~~, ~,`~ I v c~ P.I. Supervisor ~ f FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 20, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-34 KUPARUK RIV UNIT 3K-34 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~~ Comm Well Name: KUPARUK RIV UNIT 3K-34 Insp Num: mitCS09051s165718 Rel Insp Num: API Well Number: 50-029-22879-00-00 Permit Number: 198-077-0 Inspector Name: Chuck Scheve Inspection Date: 5/15/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well sK-3a - Type Inj. ~'~' TVD 6zss IA zoo zlao / ztso ztso P.T.D I9sozzo • TypeTest SPT Test psi p~F P Interval axRTST IszLZS OA zao ~ Tubing I zsso zso zsso ~ zso 2so zsso 25s0 _ Notes: Pretest pressures observed and found stable . Well demonstrated good mechanical integrity. ' {~ ~`; Wednesday, May 20, 2009 Page 1 of 1 . . ~ ConocoPhillips Alaska JUt 0 3 2007 81 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 2, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED JUL ~ 5 2007 \q~~o1'1 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. 4¡~ M.J. Loveland ConocoPhillips Well Integrity 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 oft Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft na aal 1 C-19 203-054 28" none 28" na 12 6/24/2007 1 C-123 201-084 22" none 22" na 24 7/1/2007 1C-127 201-114 18" none 18" na 12 7/1/2007 1 C-133 201-077 16" none 16" na 8.5 7/1/2007 .-190 203-003 27" none I 27" na 10~ Iii 3K-12 186-165 6" none 6" na 3 6/24/2007 3K-19 201-108 6" none 6" na 3 6/24/2007 3K-20 201-088 4" none 4" na 1 6/24/2007 3K-23 197-097 8" none 8" na 5 6/24/2007 3K-24 198-249 4" none 4" na 1 6/24/2007 3K-25 198-081 6" none 6" na 3 6/24/2007 3K-26 197-077 8" none 8" na 5 6/24/2007 3K-27 197-046 6" none 6" na 3 6/24/2007 3K-31 198-082 8" none 8" na 5 6/24/2007 3K-34 198-077 7" none 7" na 4 6/24/2007 3K-35 197-109 3" none 3" na 2 6/24/2007 Date 7/1/2007 Jim Regg P.I. Supervisor ') "¡?~? d /4'( i),<; Alaska Oil and Gas Conservation Comn.. .!n ~..au:~ Ul .t\.1a~Ka H ....J.:J J.'f ... '-' ... ~l 'III .u u 1 'f .I. TO: DATE: Wednesday, May 25, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHlLLIPS ALASKA INC 3K-34 KUPARUK. RlV UNIT 3K-34 ,,/ \C\ct-,O FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv dßL- Comm NON-CONFIDENTIAL Well Name: KUPARUK RlV UNIT 3K-34 Insp Num: mitCS050521161125 Rei Insp Num: API Well Number: 50-029-22879-00-00 Permit Number: 198-077-0 Inspector Name: Chuck Scheve Inspection Date: 5/21/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I 3K-34 Type Inj. IA Well w TVD 6285 300 2140 2140 2140 P.T. 1980770 TypeTest SPT Test psi 1571.25 OA 400 650 650 650 Interval 4YRTST P/F P Tubing 2850 2850 2850 2850 Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. SCANNED JUL û ~£ 2005 Wednesday, May 25,2005 Page I of I ) ') STATE OF ALASKA .,¥,~()11 ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ,!¡.I<"" I Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; and Jim_Regg@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. SCANNED MAY 2 6 2005 FIELD I UNIT I PAD: Kuparuk I KRU/3K DATE: 05121/05 OPERATOR REP: Arend 1 Sauvageau - AES AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. well3K-02 I Type Inj I S I T.V.D. 6421 I Tub~ng I 27501 27501 27501 2750lnterval 4 P.T.D. 1861020 Type Test P Test psi 1605 Casing 1100 2000 1950 1950 P/F P Notes: OA: 500 1 550 1 550 1 550 well3K-04 I Type Inj I S I T.V.D. 6431 I Tubing I 30001 30001 30001 3000 I Interval I 4 P.T.D. 1861040 Type Test P Test psi 1608 Casing 1000 2100 2040 2040 P/F P Notes: OA: 250 1 350 1 350 1 350 well3K-05 I Type Inj I S I T.V.D. 6341 I Tub~ng I 27501 27501 27501 2750lnterval 4 P.T.D. 1861230 Type Test P Test psi 1585 Casing 1400 2100 2070 2070 P/F P Notes: OA: 880 1 940 1 940 1 940 Well\3K-07 I Type Inj I S I T.V.D.\ 6565 I Tub~ng I 29501 29501 29501 2950 1 Interval I 4 P.T.D. 1861250 Type Test P T est psi 1641 Casing 450 2100 2040 2040 P/F P Notes: OA: 220 1 340 / 340 /340 well3K-12 I Type Inj I S I TV.D. 6644 I Tub~ng I 28501 28501 28501 2850 I Interval I 0 P.T.D. 1861650 Type Test P Test psi 1661 Casing 400 2040 2000 1980 P/F P Notes: MIT IA done early to get on pad cycle OA: 200 / 480 / 480 / 480 well3K-13 I Type Inj I S I T.V.D. 6376 I Tub~ng I 28501 28501 28501 2850 Interval I 4 P.T.D. 1861360 Type Test P Test psi 1594 Casing 550 2110 2050 2050 P/F P Notes: OA: 400 / 600 1 600 / 600 Well\3K-15 1 Type Inj I S I TV.D. 6448 I Tubing I 28501 28501 28501 2850 \ Interval I 4 P.T.D. 1861380 Type Test P Test psi 1612 Casing 500 2070 2000 1980 P/F P Notes: OA: 300 / 450 / 450 / 450 Well\3K-18 I Type Inj \ S \ TV.D. 6605 1 Tub~ng I 22001 22001 22001 2200\ Interval \ 4 P.T.D. 1861510 Type Test P T est psi 1651 Casing 100 2800 2750 2740 P/F P Notes: OA: 440 / 560 I 560 / 560 Well\3K-19 I Type Inj I S 1 TV.D. I 6331 1 Tubing I 27501 27501 27501 2750 I Interval I 4 P.T.D. 2011080 Type Test P T est psi 1583 Casing 1000 2130 2130 2130 P/F P Notes: OA: 460 / 620 1 620 1 620 Well\3K-25 I Type Inj 1 N 1 T.v.D. I 6552 I Tub~ng \ 27~1 275\ 275\ 275\ Interval I 4 P.T.D. 1980810 Type Test P Test psi 1638 Casmg 2140 2120 2120 P/F P Notes: OA: 300 / 600 / 600 1 600 Well\3K-26 \ Type Inj I S I TV.D. I 6656 I Tubing \ 27501 27501 27501 2750\,nterval\ 4 P.T.D. 1970770 Type Test P T est psi 1664 Casing 900 2180 2160 2160 P/F P Notes: OA: 720 / 780 / 780 1 780 we1l13K-30 I Type Inj I S I T.V.D. 6580 I Tubing I 28501 28501 28501 2850 I Interval I 4 P.T.D. 1971130 Type Test P T est psi 1645 Casing 250 2100 2070 2070 P/F P Notes: OA: 200 / 460 1 450 1 450 well3K-31 I Type Inj I S I TVD. I 6117 I Tub~ng I 285~1 28501 28501 285Ollnterval 4 P.T.D. 1980820 Type Test P Test psi 1529 Casing 2140 2120 2120 P/F P Notes: OA: 300 / 600 / 600 1 600 Well3K-34 I Type Inj I S I TVD. I 6285 I Tub~ng I 28501 28501 28501 285Ollnterval 4 P.T.D. 1980770 Type Test P T est psi 1571 Casing 300 2140 2140 2140 P/F P Notes: OA: 400 I 650 I 650 1 650 Test Details: TYPE INJ codes TYPE TEST Codes INTERVAL Codes F = Fresh Water Inj M = Annulus Monitoring I = Initial Test G = Gas Inj P = Standard Pressure Test 4 = Four Year Cycle S = Salt Water Inj R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey Test during Workover D = Differential Temperature Test 0= Other (describe In notes) MIT Report Form MIT KRU 3K 05-21-05.xls 5/24/2005 Revised: 05/19/02 Well Compliance Report File on Left side of folder 198-077-0 MD 13536 KUPARUK RIV UNIT 3K-34 50- 029-22879-00 ARCO TVD 06877 Completion Date:C~17/98 Completed Status: 1W1NJ Current: Name Interval Sent Received T/C/D D 8457 ~ SPERRY MPT/GR/EWR4 L CMT MAP ~¢II~AL 12472-13352 L DGR/NGP/EWR4-MD ~ 7140-13539 L DGR/NGP/EWR4-TVD t~AL 4043-6872 L STAT PRESSRVY '~N~AL 13190 OH 7/1/98 7/1/98 CH 5 8/3/98 8/6/98 OH 7/1/98 7/1/98 OH 7/1/98 7/1/98 CH 5 8/3/98 8/6/98 R SRVY RPT FINAL SPERRY 0-13535.40 OH 6/25/98 6/25/98 Daily Well Ops ~/t~-3/tla° -- ~4//~ ~0 Are Dry Ditch Samples Required? yes,And ReceiveO.g-4~.-na~. Was the well cored? yes ~°~°~- Analysis Description Rec~-- Sample%~tW'-~''''~: Comments: Tuesday, May 30, 2000 Page 1 of 1 ..... - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2'. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 32' RKE 3. Address: Exploratory ~. 7. Unit or Property: P.O. Box 100360 Stratagrapic,~ ~ Anchorage, AK 99510-0360 ServicE)~E~. aruk River Unit 4. Location of well at surface: ' 8. Well number: 1047' FSL, 316' FWL, Sec 35, T13N, R9E, UM 3K-34 At top of productive interval: 9. Permit number/approval number: 2566' FSL, 342' FEL, Sec 6, T12N, R10E, UM 98-0077 At effective depth: 10. APl number: 50-029-22879-00 At total depth: 11. Field/Pool: 2380' FSL, 113' FWL, Sec 5, T12N, R10E, UM Kuparuk River Field/Pool 12. Present well condition summary Total Depth: measured 15536 feet Plugs (measured) true vertical 6877 feet Effective Deptl measured 13436 feet Junk (measured) true vertical 6811 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 89' 16" 135 Sx ASI 121' 121' Surface 7044' 7-5/8" 570 Sx AS III LW& 7076' 4015' 240 Sx Class G Production 12658' 5.5" 225 Sx Class G 12690' 6385' Liner 1058' 3.5" 135 Sx Class G 13535' 6872' Perforation Depth measured 13170'-13210 true vertical 6650'-6673 i~,-~ i~ '~.~ ~~:~-~ ~--~ ~' i~ Tubing (size. grade, and measured depth) 3-1/2", 9.3#, L-80, @ 12486' ME: . ~.' =:~. Packers and SSSV (type and measured depth) -:.., .: ~ ~, ~,~ Baker sabl-3 Packer @ 12482 MD; NO SSSV 'L :~ :~-~ .~, 13. Stimulation or cement squeeze summary ...~,~ .~.'~ PERFORATED A2 SAND FROM 13326'-13376' Intervals treated (measured) ~. ~, Treatment description including volumes used and final pressure 14. Representitive Daily Average Production or Injection Data Oii-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 3300 500 2700 Subsequent to operation 0 0 2947 225 2872 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~X Oil _ZX Gas _ Suspended _ Service~)~ ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~_~_~___~~ -- Title: d,j~,~,, '~'~-------7_,,~- Date Form 10-404 Rev 06/'~ SUBMIT IN DUPLICATE '~,,~ AR~O Alaska, Inc. KUPARUK RIVER UNIT '~-~JELL SERVICE REPORT 3K-34(4-1)) WELL JOB SCOPE JOB NUMBER 3K-34 PERFORATE, PERF SUPPORT 0801981649.3 DATE O8/O3/98 DAY 1 FIELD ESTIMATE DALLY WORK PERFORATE A2 SANDS OPERATION COMPLETE SUCCESSFUL I KEY PERSON O Yes ~ No ~ Yes ~_~ No I SWS-ELMORE AFC# ICC# I DAILY COST ACCUM COST AK9293 230DS36KL $18,354 $20,658 850 PSII 330 PSII 600 PSI 550 PSI 250 PSII 250 PSI I 0.000 " UNIT NUMBER 8305 SUPERVISOR JONES Signed IMin ID I Depth 0.000" 0 FT DAILY SUMMARY SWS PERFORATED FROM 13,326' TO 13,376' IN 2 RUNS WITH 2.5" HC, DP, 4 SPF, 180 DEG PHASED, RANDOM ORIENT. UNABLE TO PERF BTM 20', TAGGED DOWN @ 13,280'. [Per[] TIME LOG ENTRY 07:45 SWS MIRU, HELD TGSM, SECURED RADIO SILENCE. ARM GUN & PT LUB TO 3000#. 10:00 MIH W/20'- 2.5" HC, DP, 4 SPF, 180 DEG PHASED, RANDOM ORIENT, W/2.5" PETROLINE ROLLERS ABOVE & BELOW, CCL. SEASONED NEW LINE RIH. FOUND SWS CMT LOG 6-23-98 OFF DEPTH, 3' SHALLOW WHEN COMPARED TO SPERRY SUN ROP/DGR/NGP LOG 6-13-98. ADJUST PERF DEPTH UP 3'. CORR TO CUT LOG & PERF FROM 13,253' TO 13,273' (PERF @ 13,256' TO 13,276' ON SPERRY SUN LOG). 14:00 POH, TOOLS PULLED STICKY PAST OLD PERFS. LD GUNS, ALL SHOTS FIRED. 15:30 MU GUN & PT LUB TO 3000#. 16:15 MIH W/20' - 2.5" HC GUN AS ABOVE, CORR TO ABOVE LOGS & PERF TO CMT LOG 13,233' TO 13,253' (PERFS 13,236' TO 13,256' BY SPERRY LOG). 18:30 POH & LD GUNS, ALL SHOTS FIRED. 20:00 RIG DOWN. 20:45 RELEASED SWS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL , $0.00 $40.00 APC $250.00 $250.00 HALLIBURTON $0.00 $1,264.00 LITTLE RED $0.00 $1,000.00 SCHLUMBERGER $18,104.12 $18,104.12 TOTAL FIELD ESTIMATE $18,354.12 $20,658.12 ARCO Alaska, Inc. '~. .... Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 21, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3K-34 (Permit No. 98-077) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3K-34. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Team Leader Kuparuk Drill Site Development GCA/skad STATE OF ALASKA ~- ~" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG r CE,iVED 1 Status of Well Classification of Service Well OIL r~ GAS [] SUSPENDED E~] ABANDONED~ SERVICE [~ Injector 2 Name of Operator 7 Pe~it Number Alaska 0il & Gas C0 ARCO Alaska, Inc 98-077 3 Address 8 APl Number ~11~11~1 P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22879 1047' FSL, 316' ~L, Sec. 35, T13N, R9E, UM t ¢~ '~ - * Kuparuk River Unit At Top Producing Inte~al j~~~ ~ 10 Well Number 2566' FSL, 342' FEL, Sec. 6, T12N, R10E, UM ~ '~ ~ 3K-34 At Total Depth ~ ~~ ~ ~[. 11 Fiald and ~oo~ 5 filevafion in foet {indicato KB, DF, otc.) ~ koaso ~i~nation ~d Sofial ~o. Kuparuk ~ivor Oil Rig RKB 32' ADL 25628 ALK 2561 12 Date27_Apr.98Spudded 13 Date12-Jun-98T'D' Reached 14 Date17-Jun-98Comp', Susp. or Aband, 15 WaterNADepth, if offshorefeet MSL 16 NO.lOf Completions 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey 20 Depth where SSSV set ~ 21 Thickn~s of permafrost 13536' MD & 6877' ~D 13436' MD & 6811' ~D YES ~ NO ~ N/A feet MD 1556' APPROX 22 Type Electdc or Other Logs Run G~Res 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP B~ HOLE SIZE CEMENT RECORD 16' 151.53~ X-65 SURF. 121' 30' 135 sx AS I 7.625' 29.7¢ L-80 SURF. 7076' 9.875' 570 sx AS III LW, 240 sx Class G, 60 sx AS I 5.5" 15.5¢ L-80 SURF. 12690' 6.75' 225 sx Cla~ G 3.5' 9.3¢ L-80 12478' 13535' 6.125' 135 bbls Class G 24 Pedorations open to Production (MD+~D of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 12486' 12478' 13170'-13210' MD 6650'-6673' ~D 4 spf 26 ACID, FRACTURE, CEMEh DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13170'-13210' ~njected 97,343¢ prop in the fo~ation w/ 6¢ ppa of ¢1~18 ~ the pads ..O .CT.O.T.ST ni~ctor Dato o~Iosl Hours Tested ~O~OOTIO~ FO OIk-BBk GAS-MGF W~Tfi~-BBt ~OK~ S,~IGAS-OIk ~ross. 24-HO~ ~ATfi: 28 GOSE DATA ~rio[ dascdption of Iitholooy, porositg, ffacturos, apparonl dips an0 presence of oil, ~as or wator. Submil corn chips. 1.998 is. ~ge Form 10-407 Submit in duplicate Pev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 12924' 6514' Bottom Kuparuk C 13000' 6556' Top Kuparuk A 13158' 6647' Bottom Kuparuk A 13358' 6767' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32, I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ # ~ Prepared by Name/Number Sharon AIIsup-Drake/263-4612 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 only 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 6/30/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:3K-34 WELL_ID: AK9293 TYPE: AFC: AK9293 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:04/27/98 START COMP: RIG:NORDIC BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22879-00 04/23/98 (D1) TD: 0'( SUPV:GRW o) MW: 0.0 VISC: MOVING RIG IN Prep rig for move. 0 PV/YP: 0/ 0 APIWL: 0.0 04/24/98 (D2) TD: 0'( SUPV:GRW o) MW: 0.0 VISC: MOVE RIG 0 PV/YP: 0/ 0 APIWL: 0.0 Move camp modules from West Sak #2 pad to 3K pad. Move rig modules to iR turnoff. Broke chain in #4 Lampson-repair. 04/25/98 (D3) TD: 121'(121) SUPV:GRW MW: 0.0 VISC: MOVING RIG 0 PV/YP: 0/ 0 APIWL: 0.0 Finish repairing chain on %4 Lampson. Move rig modules. 04/26/98 (D4) TD: 121'( SUPV:GRW o) MW: 0.0 VISC: PICKING UP DRILL PIPE 0 PV/YP: 0/ 0 APIWL: 0.0 Repair greaser lines on %2 Lampson. Finish moving drill module to 3K pad. N/U diverter stack. Accept rig 4/24/98. 04/27/98 (D5) TD: 1082' (961) SUPV:GRW MW: 9.0 VISC: 105 PV/YP: 21/34 DRILLING APIWL: 8.4 Finish N/U diverter. Function test diverter. Cleanout conductor from 60' to 1212' Drill from 121' to 1082' 04/28/98 (D6) TD: 5270' (4188) SUPV: GRW MW: 9.2 VISC: 102 PV/YP: 20/36 TRIPPING OUT Drill from 1082' to 5270' APIWL: 9.2 04/29/98 (D7) TD: 6704' (1434) SUPV:DB/PR MW: 9.5 VISC: 99 PV/YP: 21/60 TRIP OUT OF HOLE APIWL: 6.8 Drill from 5270' to 5604' Circ lo/hi vis sweep. Pump slug. TOOH - slight swabbing. Drill from 5604' - 6704' 04/30/98 (D8) TD: 7090' (386) SUPV:DB/PR 05/01/98 (D9) TD: 7090'( SUPV:DB/PR 0) MW: 9.6 VISC: 88 PV/YP: 27/47 LANDING CASING APIWL: 7.0 Drilling from 6705' to 7090' Run 7-5/8" casing. MW: 9.7 VISC: 83 PV/YP: 32/42 RIH TO DRILL OUT STAGE TOOL. APIWL: 5.8 RUN CSG F/2236 T/4179' CIRC OUT 107 BBL CONTAMINATED MUD AND CEMENT - CONTINUE TO CIRC AND COND. INSTALL SPEED HEAD AND TORQUE TO 15KAND ANULUS VALVE. CHANGE OUT STRIPPER RUBBER. 05/02/98 (D10) TD: 7140'( 50) SUPV:DB/PR MW: 8.5 VISC: 48 PV/YP: 13/ 9 RIH W/BHA 4. APIWL: 15.8 PERFORM ACCUMULATOR TEST. PJSM. DRIL CMT - BAFFLE - CMT - FLOAT - CMT - SHOE - CMT - 20' NEW HOLE. 05/03/98 (Dll) TD: 8933'(1793) SUPV:DB/PR MW: 9.0 VISC: 53 PV/YP: 17/13 DRILLING 6-3/4" HOLE. APIWL: 7.6 SAFETY MTG - BOP DRILL - INSTALL SAFETY VALVE. DRIL F/7040 T/8933' 05/04/98 (D12) TD:ll176' (2243) SUPV:DB/PR MW: 9.3 VISC: DRILLING @ 11250' 6 PV/YP: 22/18 APIWL: 6.0 Drill from 8933' to 11176' Flowing on connection at 11109' CBU, monitor, flow back, lo/hi sweep, monitor, pump slug. TOOH to shoe @ 7038', wiper trip, pull slow swabbing. 05/05/98 (D13) TD:12438' (1262) SUPV:DB MW: 9.4 VISC: 53 PV/YP: 20/13 START SHORT TRIP APIWL: 5.0 Drill from 11204' to 12334' MD. Circulate lo/hi visc sweeps, monitor hole, slow flow and slowing - hole breathing. Shut-in and do formation leak-off test. Leaked off at 11.2+ EMW at 4021' TV-D, 10.5+ ppg EMW at present depth 6228' TVD. CBU, no gas cut. Drill to 12438' MD. 05/06/98 (D14) TD:12690' (252) SUPV:DB POH. MW: 9.7 VISC: 48 PV/YP: 18/ 7 APIWL: 5.0 DRIL F/12438 T/12690' TEST FORMATION - LEAKED OFF AT 507 PSI W/9.7 PPG MUD. RIH. HOLE SLICK; NO FILL ON BOTTOM. CIRC BOTTOMS UP AND CONDITION MUD. 05/07/98 (D15) TD:12690' ( 0) SUPV:DB POH MW: 9.8 VISC: 63 PV/YP: 24/21 APIWL: 4.6 Monitor hole, static. RIH, hit small tight spots at 12360' and 12410'. No fill on bottom. Start POH, hole swabbing. Test formation, formation broke down at 417 psi, 12.0 ppg EMW at shoe at 4021' TVD, 11.2+ ppg EMW at present TD at 6387' Circ and condition mud, adding fine and medium LCM. 05/08/98 (D16) TD:12690' ( 0) SUPV:DB MW: 10.1 VISC: 70 PV/YP: 0/ 0 RIH, CIRC APIWL: 4.4 Circulate and add fine & medium LCM to mud system. Pump slug, hole swabbing. Circulate out stands to 8922' to prevent swabbing, tight spot at 11765' Pump slug, swabbing. Test BOPE to 300/3000 psi. 05/09/98 (D17) TD:12690' ( 0) SUPV:DB MW: 9.8 VISC: 54 PV/YP: 0/ 0 CIRC ON BOTTOM APIWL: 5.2 RIH with LWD tools. Replace quick release valves on Hi-Drum clutch. Back ream, partial returns. Reduce weight to 9.8 PPg. 05/10/98 (D18) TD:12690' ( 0) SUPV:DB MW: 9.8 VISC: 53 PV/YP: 19/15 RUNNING 5.5" CASING APIWL: 4.6 Ream from 12365' to 12538' Broke thru and reamed freely from 12538' to bottom at 12690'. Test formation, 11.2 ppg EMW at shoe at 4021' TVD, 10.7 ppg EMW at TD at 6387' TVD. 05/11/98 (D19) TD:12690'( 0) SUPV:DEB MW: 9.5 VISC: 47 PV/YP: 1/ 8 Prepare to bleed off annulus APIWL: 5.2 Run 5.5" casing. Circulate at 7958' and 9008', partial returns. Pump cement. Shut-in annulus after bumping plug to stop continued flow, due to breathing. 05/12/98 (D20) TD:12690' ( 0) SUPV:DCL MW: 0.0 VISC: RIG RELEASED 0 PV/YP: 0/ 0 APIWL: 0.0 Open well. Flowed 200 bbls. ND BOPE. Install packoff and master valve. Test to 3000 psi. Freeze protect. Release rig at 1900 hrs. 5/12/98. 06/08/98 (D21) TD:12690' ( 0) SUPV:DCLRLM MW: 0.0 VISC: Pick up BHA 0 PV/YP: 0/ 0 APIWL: 0.0 Move rig from 3K-31 to 3K-34. ND tree, NU BOPE and test to 500/3500 psi. 06/09/98 (D22) TD:12690' ( 0) SUPV:DW 06/10/98 (D23) TD:12700' ( 10) SUPV:DW MW: 10.3 VISC: 50 PV/YP: 22/17 Drill 4.75" hole to 12700' APIWL: 4.2 RIH w/BHA hitting ice. Circulate warm fluid to warm up well bore. MW: 10.3 VISC: 50 PV/YP: 16/24 Drilling 4.75" hole @ 12775' APIWL: 4.5 Clean out cement from 5.5" casing from 12509' to 12597' Drill to 12700'. Perform LOT, 13.0 ppg EMW. Work on Sperry-Sun tool. 06/11/98 (D24) TD:12953'(253) SUPV:DW MW: 10.4 VISC: 46 PV/YP: 15/19 Drilling @ 13,173' APIWL: 4.0 Drill 4.75" hole from 12700' to 12870' Wash pipe packing leaking. Stabilizers torquing hard passing through float and shoe. Short trip into 5.5" casing shoe @ 12690' Replace wash pipe and packing. Continue drilling 4.75" hole from 12870' to 12953' 06/12/98 (D25) TD:13535'(582) SUPV:DW MW: 10.3 VISC: 50 PV/YP: 19/22 Drilled to 13535' TD APIWL: 4.0 Continue drilling 4.75" hole from 12953' to 13535' TD. Short trip to 5.5" casing shoe 12690' Hole in good condition. 06/13/98 (D26) TD:13535'( 0) SUPV:DW MW: 10.3 VISC: 50 PV/YP: 13/22 Cement 3.5" liner @ 13535' Run with 3.5" liner to 12655' APIWL: 4.0 06/14/98 (D27) TD:13535' ( 0) SUPV:DW MW: 10.8 VISC: 50 PV/YP: 16/28 Test 3.5" liner APIWL: 4.3 Continue to circulate 2-7/8" pipe & 3.5" liner volume @ 12655' before running through open hole. Unable to circulate. Pump cement. Pressure increasing. Circulate down Dp and reciprocate. Started getting lots of solids from well bore and would not clean up. 06/15/98 (D28) TD:13535'( 0) SUPV:DLW MW: 8.5 VISC: 0 PV/YP: 0/ 0 Load pipe house w/3.5" tubing APIWL: 0.0 Safety meeting. RIH with 2-7/8" DP. Rotate and reciprocate pipe two bottoms up. Displace mud with sea water. 06/16/98 (D29) TD:13535' ( 0) SUPV:BP 06/17/98 (D30) TD:13535' ( 0) SUPV:BP MW: 8.5 VISC: 0 PV/YP: 0/ 0 Testing backside to 3500 psi Run 3.5" completion assembly. MW: 8.5 VISC: 0 PV/YP: 0/ 0 Rig released Finish running 3.5" completion. N/D BOPE. NU tree and test to 250/5000 psi. Pull off well, secure well. Released rig 1200 hrs 6/17/98. APIWL: 0.0 APIWL: 0.0 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(3K-34(W4-6)) WELL JOB SCOPE 3K-34 PERFORATE, PERF SUPPORT DATE DALLY WORK 06/24/98 PERFORATE A-3 SANDS DAY OPERATION COMPLETE I SUCCESSFUL 2 YES _J YES Initial Tbg Press I FinaITbg Press I Initial Inner Ann 0 PSIt 50 PSII 0 PSI DAILY SUMMARY JOB NUMBER 0616981014.3 UNIT NUMBER 2128 KEY PERSON SUPERVISOR SWS-JOHNSON JONES Final Inner Ann I Initial Outer Ann I Final Outer Ann 30 PSII 0 PSII 0 PSI SWS (JOHNSON, THORNHILL & CREWS) PERFORATED A3 SANDS FROM 13170' TO 13210' W/4 SPF, BH, 180 DEG PHASED, NO ORIENT. RAN SBHP @ 13190', 2863 PSI. TIME LOG ENTRY 08:00 SWS (JOHNSON & CREW) & APC MIRU, HELD TGSM, SECURED RADIO SILENCE. ARMED GUN & PT LUB TO 3000#. 09:30 MIH W/20 FT, 2.5" HC, 4 SPF, BH, 180 DEG PHASED, NO ORIENT W/2.5" PETROLINE ROLLERS ABOVE & BELOW. CORR TO CMT LOG 6-23-98. HP = 2775 PSI, PUT 800 PSI WELLHEAD PRESS & PERFED FROM 13190' TO 13210'. PRESS DROPPED TO 75.0 PSI. 11:40 POH & LD GUN, ALL SHOTS FIRED. 13:00 MU 20 FT, 2.5" HC GUN AS ABOVE & PT LUB TO 3000#. 13:45 MIH W/20 FT, 2.5" HC GUN AS ABOVE, CORR TO ABOVE LOG. PUT 800 PSI WELLHEAD PRESS & PERFED FROM 13170' TO 13190'. PRESS DROPPED TO 450 PSI. CREWS CHANGED OUT. 17:00 POH & LD GUN, ALL SHOTS FIRED. 19:00 MU 1 11/16" CPLT, WB, CCL. PT LUB TO 3000#. MIH, CORR TO ABOVE LOG & OBTAIN A SBHP @ 13190' = 2863 PSI. 21:45 POH & LD TOOLS. 22:45 RIG DOWN. 23:45 RELEASE SWS. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~" K1(3K-34(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-34 FRAC, FRAC SUPPORT 0628981835.4 DATE DAILY WORK UNIT NUMBER 07/04/98 "A" SAND INITIAL FRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES YES DS-GALLEGOS CHAN EY FIELD AFC# CC# Signed ESTIMATE 999193 230DS36KL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 115 PSI 3500 PSI 500 PSI 500 PSI 0 PSII 0 PSI DAILY SUMMARY "A" SAND FRAC COMPLETED INTO FLUSH AND SCREENED OUT. INJECTED 97343 LBSOF PROP IN THE FORM W/6# PPA OF #12/18 @ THE PERF'S. MAXIMUM PRESSURE 7200 PSI & F.G. (.72). UNABLE TO FREEZE PROTECT THE TBG.[Frac-Refrac] TIME 07:00 08:45 09:30 10:30 11:15 12:30 LOG ENTRY MIRU DOWELL FRAC EQUIP, LRS HOT OIL UNIT, & APC VAC TRK. HELD SAFETY MEETING (16 PEOPLE ON LOCATION). PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 11000 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 30 TO 15 BPM. SLURRY VOLUME PUMPED 493 BBLS. USED 5900 LBS OF #20/40 PROP FOR SCOURING. MAXIMUM PRESSURE 7000 PSI AND ENDING PRESSURE 4300 PSI. STEPPED RATE DOWN AND S/D. OBTAINED ISlP OF 1876 PSI W/F.G. OF (.72). PULSED TO DETERMINE CLOSURE & MONITORED WHTP. PUMP ADDITIONAL SCOUR STAGE W/50# DELAYED XL GW @ 25 BPM. SLURRY VOLUME PUMPED 240 BBLS. USED 5434 LBS OF #20/40 PROP. MAXIMUM PRESSURE 6400 PSI AND ENDING PRESSURE 6000 PSI. STEPPED RATE DOWN AND S/D. OBTAINED ISIP OF 2183 PSI W/F.G. @ (.77). CLOSURE TIME 5.5 MINS @ 1764 PSI. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SLURRY VOLUME PUMPED 226 BBLS. MAXIMUM PRESSURE 4300 PSI AND ENDING PRESSURE 3800 PSI. S/D AND OBTAINED ISIP OF 2105 PSI W/F.G. @ (.76). MONITORED WHTP FOR CLOSURE. CLOSURE TIME 10 MINS @ 1870 PSI. PAD VOLUME = 310 BBLS. PUMP FRAC W/50# DELAYED XL GW @ 15 BPM. COMPLETED HALF THRU THE FLUSH AND SCREENED OUT. SLURRY VOLUME PUMPED 1017 BBLS PUMPED 111789 LBS OF PROP (16722 LBS OF #20/40 & 95067 LBS OF #12/18). INJECTED 97343 LBSOF PROP IN THE FORMATION W/6# PPA OF #12/18 @ THE PERF'S. LEFT 14446 LBS OF PROP IN THE WELLBORE, ESTIMATE FILL TO BE @ 10400' W/BHP OF 2900 PSI. UNABLE TO FREEZE PROTECT THE TBG. 14:15 STARTED R/D. DEPRESSURED THE INNER CSG BACK TO 500 PSI AND R/D LRS HOT OIL UNIT. TIME 15:00 16:00 LOG ENTRY REMOVED THE TREESAVER (ALL CUPS RETURNED). R/D COMPLETED AND ALL WELL SERVICE PERSONNEL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. Sperry-Sun Drilling Services Survey Report for 3K-34 Your Ref: API-500292287900 Kuparuk Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0,000 0.000 -67,55 0.00 113.25 0,000 0.000 45,70 113.25 174.25 0.500 23.000 106.70 174.25 260.25 4,250 26.000 192.69 260.24 350.25 3.500 86,000 282.62 350.17 437.25 6.750 115.000 369.27 436.82 546.88 12.570 120,270 477.30 544.85 639.79 16.260 112.700 567.28 634.83 728.75 18.660 110.260 652.13 719.68 819.48 21.420 110.190 737.36 804.91 909.37 24.180 110.860 820.22 887.77 1000.50 27.490 113.210 902.23 969.78 1091.09 30.300 112.920 981.54 1049.09 1180.17 32,350 111.740 1057.63 1125.18 1277.77 33.220 112,600 1139.68 1207.23 1371.42 34.660 112.500 1217.37 1284.92 1467.56 36.370 111.960 1295.63 1363.18 1561.50 36.940 111,870 1370.99 1438.54 1657.39 38.190 113.430 1447.00 1514.55 1752.23 39,640 111,190 1520.79 1588.34 1846.95 42.170 110.020 1592.38 1659.93 1942.88 45.540 109,420 1661.54 1729.09 2037.88 49.140 109.900 1725.91 1793.46 2132.62 52.070 113.160 1786.04 1853.59 2228.66 55.340 112.490 1842.88 1910.43 2323.47 55.790 112.030 1896.49 1964.04 2417.76 57.730 111.230 1948.18 2015.73 2512.14 59.350 111.360 1997.43 2064.98 2606.83 61,920 111,610 2043.86 2111.41 2701.55 64.770 108.460 2086.36 2153.91 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 0.00 N 0.00 E 6008041.53 N 529305.78 E 0.00 0.00 N 0.00 E 6008041.53 N 529305.78 E 0.000 0.00 0.25 N 0.10 E 6008041.78 N 529305.88 E 0.820 0.01 1.43 N 0.66 E 6008042.97 N 529306.44 E 0.873 0,11 2.51N 3.83 E 6008044,05 N 529309.60 E 3.413 2.70 0.53 N 11.12 E 6008042.11 N 529316.90 E 4.665 10.21 8.21 $ 27.28 E 6008033.42 N 529333.09 E 5.364 28.42 18,33 $ 48.02 E 6008023.39 N 529353.87 E 4.452 51.40 28.07 S 72.86 E 6008013.75 N 529378,75 E 2.820 78.08 38.81S 102.03 E 6008003.12 N 529407,96 E 3.042 109.17 51.04 S 134.65 E 6007991.02 N 529440.63 E 3.084 144.00 65.98 S 171.43 E 6007976.23 N 529477.47 E 3.801 183.68 83.12 S 211.70 E 6007959.24 N 529517.81 E 3.106 227.42 100.70 S 254.54E 6007941.83 N 529560.71 E 2.402 273.71 120.65 S 303.48 E 6007922.08 N 529609.73 E 1.011 326,54 140.70 S 351.77 E 6007902.21 N 529658,10 E 1.539 378.80 161.82 S 403.47 E 6007881.30 N 529709.88 E 1.808 434.63 182.75 S 455.50 E 6007860.57 N 529761.99 E 0.609 490.70 205.27 S 509.44E 6007838.26 N 529816.02 E 1.638 549.12 227.87 S 564.55 E 6007815.88 N 529871.22 E 2.130 608.67 249.68 S 622.61 E 6007794.30 N 529929.36 E 2.791 670.68 272.09 S 685.17 E 6007772.13 N 529992.01E 3.540 737.13 295.60 S 750.94E 6007748.88 N 530057.88 E 3.808 806.96 322.50 S 819.01E 6007722.25 N 530126.05 E 4.078 880.14 352.51S 890.34E 6007692.52 N 530197.50 E 3.451 957.49 382.13 S 962.71 E 6007663.18 N 530269.99 E 0.621 1035.66 411.20 S 1036.02 E 6007634.41N 530343,41 E 2.176 1114.51 440.43 S 1111.03 E 6007605.46 N 530418.53 E 1.720 1195.01 470.66 S 1187.81E 6007575.54N 530495.43 E 2.724 1277.52 499.62 S 1267.33 E 6007546.89 N 530575.06E 4.229 1362.14 Comment 24June, 1998-12:42 -2- Sperry-Sun Drilling Services Survey Report for 3K-34 Your Ref: API-5002g2287go0 Kuparuk Unit Measured Depth (ft) Incl. 2890.33 3079.16 3364.78 3552.17 3741.65 4022.29 43O8.88 4594.38 4878.28 5162.10 5353.22 5516.19 5729.11 6014.02 6206.16 6488.26 6771.43 7005.67 7337.89 7623.04 7906.59 8192.51 8476.44 8761.33 9046.10 9328.38 9608.74 9895.33 1O18O.59 10463.32 62.300 65.530 68.790 66,130 64.38O 64.890 64.100 64.390 65.800 64.160 65.390 63.850 63.310 62.5O0 65,510 65.330 64.880 64.810 65.890 66.390 66.410 66.120 66.680 62.620 64.140 65.240 65.320 64.440 66.110 65.330 Azim. 106.720 112.160 113.110 111.950 111.220 111.950 111.170 111.200 111.320 112.290 111.050 112.390 108.150 108.630 108.670 108.750 110.060 109.690 108.980 111.150 110.390 113.600 112.870 113.550 111.820 106.740 108.290 111.230 110.520 112.240 Sub-Sea Depth (ft) 2170.49 2253.56 2364.41 2436.24 2515.55 2635.77 2759.17 2883.23 3002.78 3122.82 3204.27 3274.12 3368.89 3498.66 3582.86 3700.21 3819.41 3918.98 4057.54 4172,90 4286.42 4401.53 4515.20 4637.15 4764.75 4885.49 50O2.74 5124.42 5243.73 5360.00 Vertical Depth (ft) 2238.04 2321.11 2431.96 2503.79 2583.10 2703.32 2826.72 2950.78 3070.33 3190.37 3271.82 3341.67 3436.44 3566.21 3650.41 3767.76 3886.96 3986.53 4125.09 424O.45 4353.97 4469.08 4582.75 4704.70 4832.3O 4953.04 5070.29 5191.97 5311.28 5427.55 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 550.72 S 1428.39 E 6007496.43 N 530736.33 E 1,547 1530.86 607,23 $ 1588.18 E 6007440.55 N 530896.33 E 3.101 1700,30 708.54 $ 1831.08 E 6007340.19 N 531139.63 E 1.182 1963.35 774.87 S 1990.93 E 6007274.49 N 531299,73 E 1.530 2136.32 838.18 S 2150.93 E 6007211.81 N 531459.99 E 0.988 2308.38 931.47 S 2386.73 E 6007119.45 N 531696.15 E 0.297 2561.93 1026.52 S 2627.28 E 6007025.34 N 531937.08 E 0.369 2820.56 1119.45 S 2867.04 E 6006933.35 N 532177.20 E 0.102 3077.70 1212.82 S 3107.01E 6006840.93 N 532417.53 E 0.498 3335.18 1308.33 S 3345.79 E 6006746.35 N 532656.69 E 0.656 3592.31 1372.16 S 3506.46 E 6006683.15 N 532817.61 E 0.871 3765.18 1426,64 S 3643.25 E 6006629.22 N 532954.60 E 1.202 3912,39 1492.69 S 3822.06 E 6006563.86 N 533133.67 E 1.801 4103.00 1572.71S 4062.74 E 6006484.80 N 533374.67 E 0.321 4356.42 1627.93 S 4226.36 E 6006430.22 N 533538.50 E 1.567 4528,99 1710.22 S 4469.34 E 6006348.88 N 533781.80 E 0.069 4785.36 1795.55 S 4711.60 E 6006264.50 N 534024.40 E 0.449 5042.13 1867.63 S 4910,99 E 6006193.20 N 534224.07 E 0.146 5254.13 1967.60 S 5195.90 E 6006094.36 N 534509.37 E 0.379 5555.97 2057.07 S 5440.83 E 6006005.85 N 534754.65 E 0.718 5816.71 2149.21S 5683.78 E 6005914.67 N 534997.96 E 0.246 6076.55 2247.21S 5926.43 E 6005817.62 N 535240.99 E 1.033 6338.18 2349.85 S 6165.50 E 6005715.92 N 535480.47 E 0.307 6598.12 2451.27 S 6402.08 E 6005615.43 N 535717.45 E 1.441 6855.28 2549.42 S 6636.96 E 6005518.20 N 535952.71 E 0.761 7109.71 2633.59 S 6877.74 E 6005434.98 N 536193.81 E 1.673 7364.68 2710.23 S 7120.59 E 6005359.29 N 536436.96 E 0.503 7618.93 2797.92 S 7364,77 E 6005272.56 N 536681.48 E 0.978 7878.33 2890.24 S 7606.86 E 6005181.20 N 536923.94E 0.628 8137.43 2984.17 S 7846.84E 6005088.21 N 537164.28 E 0.619 8395.12 Comment 24 June, 1998 - 12:42 - 3 - Sperry-Sun Drilling Services Survey Report for 3K-34 Your Ref: API-500292287900 Kuparuk Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°~'~OOft) (ft) 10749.48 64.630 111.240 5481.03 5548.58 11032.01 66.430 111.260 5598.05 5665.60 11319.78 64.320 112.200 5717.95 5785.50 11604,78 65.500 111.220 5838.80 5906.35 11887.74 63,760 110.230 5960.04 6027.59 12170.66 64.890 109.330 6082.62 6150.17 12455.69 63.860 109.150 6205.89 6273.44 12523.23 64.360 108.420 6235.38 6302.93 12549.62 63.330 107.940 6247.01 6314.56 12609.30 60.000 108.150 6275.33 6342.88 12735.61 57.830 107.4o0 6340.55 6408.10 12833.04 57.250 108.770 6392.84 6460.39 12927.68 56.590 108.430 6444.49 6512.04 13022.37 55.540 110.280 6497.36 6564.91 13111.88 54.880 110.230 6548.43 6615.98 13204.53 53.640 111.250 6602.55 6670.10 13298.58 52.490 112.980 6659.06 6726.61 13394.52 52.110 114.330 6717.73 6785.28 13477.03 51.870 115.380 6768.55 6836.10 13535.40 51.870 116.000 6804.59 6872.14 3080.22 S 8087.69 E 6004993.10 N 537405.51 E 0.400 8654.39 3173.42 S 8327.35 E 6004900.85 N 537645.53 E 0.637 8911.52 3270.25 S 8570.35 E 6004804.97 N 537888.91E 0.791 9173.06 3365.71S 8810.15 E 6004710.45 N 538129.08 E 0.518 9431.13 3456.20 S 9049.25 E 6004620.91 N 538368.54 E 0.691 9686.79 3542.48 S 9289.19 E 6004535.57 N 538608.82 E 0.492 9941.73 3627.17 S 9531.83 E 6004451.84 N 538851.78 E 0.366 10198.63 3646.73 S 9589.35 E 6004432.50 N 538909.39 E 1.222 10259.35 3654.12 S 9611.86 E 6004425.20 N 538931.92 E 4.231 10283.01 3670.39 $ 9661.80 E 6004409.13 N 538981.92 E 5.588 10335.48 3703.42 S 9764.80 E 6000376.50 N 539085.05 E 1.792 10043.49 3728.93 S 9842.94 E 6000351.29 N 539163.29 E 1.327 10525.61 3754.23 $ 9918.10 E 6004326.30 N 539238.55 E 0.760 10604.85 3780.26 S 9992.21E 6004300.56 N 539312.77 E 1.964 10683.38 3805.71S 10061.18 E 6004275.38 N 539381.83 E 0.739 10756.89 3832.33 S 10131.51 E 6004249.03 N 539452.26 E 1.609 10832.09 3860.62 S 10201.15 E 6004221.02 N 539522.02 E 1.912 10907.23 3891.07 S 10270.68 E 6004190.84 N 539591.67 E 1.182 10983.05 3918.40 S 10329.67 E 6004163.74 N 539650.76 E 1.044 11047.89 3938.30 S 10371.04E 6004144.00 N 539692.21 E 0.836 11093.63 All data is in feet unless otherwise stated. Directions and coordinates are relative to Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 110.770° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13535.40ft., The Bottom Hole Displacement is 11093.63ft., in the Direction of 110.794° (True). True North. Comment Projected Survey 24 June, 1998 - 12:42 .4 - Kuparuk Unit Kuparuk 3K 3K-34 SURVEY REPORT 24 June, 1998 Your Ref: API-500292287900 Last Survey 11.June-98 Job# AKMW80255 KBE- 67.55' Upper section drilled by Parker 245 with a KBE of 75.30'/lower section by Nordic 2 KBE of 67.55' eECEI\/ED ,JUN 2. 5 ,~Jas~a Off & Gas Cons.' A'~Chorage DRILLING SERVICES .~ ol~lslo~ oF ~ I ,'~m,~l'tt I~,. mc. Survey Ref: svyl8 Sperry-Sun Drilling Services Survey Report for 3K-34 Your Ref: AP1-500292287900 Kuparuk Unit Measured Depth (ft) 0.00 113.25 174.25 260.25 350.25 437.25 546.88 639.79 728.75 819.48 909.37 1 OOO.5O 1091 .O9 1180.17 1277.77 1371.42 1467.56 1561.50 1657.39 1752.23 1846.95 1942.88 2037.88 2132.62 2228.66 2323.47 2417.76 2512.14 2606.83 2701.55 Incl. 0.000 0.000 0.500 1.250 3.500 6.750 12.570 16.260 18.660 21.420 24.180 27.490 30.300 32,350 33.220 34.660 36.37O 36.940 38.190 39.640 42.170 45.540 49.140 52.070 55.340 55.790 57.73O 59.350 61.92O 64.770 0.000 0.000 23.OOO 26.000 86.000 115,000 120.270 112.700 110.260 110.190 110.860 113.210 112.920 111.740 112.600 112.500 111.960 111.87O 113.430 111.190 110.020 109.420 109.900 113.160 112.490 112.030 111.23O 111.360 111.610 108.460 Sub-Sea Depth (ft) -67.55 45.70 106.70 192.69 282.62 369.27 477.30 567.28 652.13 737.36 820.22 902.23 981.54 1057.63 1139.68 1217.37 1295.63 1370.99 1447.00 1520.79 1592.38 1661.54 1725.91 1786.04 1842.88 1896.49 1948.18 1997.43 2043.86 2086.36 Vertical Depth (ft) 0.00 113.25 174.25 260.24 350.17 436.82 544.85 634.83 719.68 804.91 887.77 969.78 1049.09 1125.18 1207.23 1284.92 1363.18 1438.54 1514.55 1588.34 1659.93 1729.09 1793.46 1853.59 1910.43 1964.04 2015.73 2064.98 2111.41 2153.91 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 0.00 N 0.00 E 6008041.53 N 529305.78 E 0.00 0.00 N 0.00 E 6008041.53 N 529305.78 E 0.000 0.00 0.25 N 0.10 E 6008041.78 N 529305.88 E 0.820 0.01 1.43 N 0.66 E 6008042.97 N 529306.44 E 0.873 0.11 2.51 N 3.83 E 6008044.05 N 529309,60 E 3.413 2.70 0.53 N 11.12 E 6008042.11 N 529316.90 E 4.665 10.21 8.21S 27.28 E 6008033.42 N 529333.09 E 5.364 28.42 18.33 S 48.02 E 6008023.39 N 529353.87 E 4.452 51.40 28.07 S 72,86 E 6008013.75 N 529378.75 E 2.820 78.08 38.81S 102.03 E 6008003.12 N 529407.96 E 3.042 109.17 51.04 S 134.65 E 6007991.02 N 529440.63 E 3.084 144.00 65.98 S 171.43 E 6007976.23 N 529477.47 E 3.801 183.68 83.12 S 211.70 E 6007959.24 N 529517.81 E 3.106 227.42 100,70 S 254.54 E 6007941.83 N 529560.71 E 2.402 273.71 120.65 S 303.48 E 6007922,08 N 529609.73 E 1.011 326.54 140.70 S 351.77 E 6007902.21 N 529658,10 E 1.539 378.80 161.82 S 403.47 E 6007881,30 N 529709.88 E 1.808 434.63 182.75 S 455.50 E 6007860.57 N 529761.99 E 0.609 490.70 205.27 S 509.44E 6007838.26 N 529816.02 E 1.638 549.12 227.87 S 564.55 E 6007815.88 N 529871.22 E 2.130 608,67 249.68 S 622.61 E 6007794.30 N 529929.36 E 2.791 670.68 272.09 S 685.17 E 6007772.13 N 529992.01 E 3.540 737.13 ' 295.60 S 750.94 E 6007748.88 N 530057.88 E 3.808 806.96 322.50 S 819.01 E 6007722.25 N 530126.05 E 4.078 880.14 352.51S 890.34E 6007692.52 N 530197.50 E 3.451 957.49 382.13 S 962.71 E 6007663.18 N 530269.99 E 0.621 1035,66 411.20 S 1036.02 E 6007634.41 N 530343.41 E 2.176 1114.51 440.43 S 1111.03 E 6007605.46 N 530418.53 E 1.720 1195.01 470.66 S 1187.81 E 6007575.54N 530495.43 E 2.724 1277.52 499.62 S 1267.33 E 6007546.89 N 530575.06 E 4.229 1362.14 Comment Kuparuk 3K Continued... 24 June, 1998 - 12:42 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 3K-34 Your Ref: AP1.500292287900 Kuparuk Unit Measured Depth (ft) 2890.33 3079.16 3364.78 3552.17 3741.65 4O22.29 4308.88 4594.38 4878.28 5162.10 5353.22 5516.19 5729.11 6014.02 6206.16 6488.26 6771.43 7005.67 7337.89 7623.04 7906.59 8192,51 8476,44 8761,33 9046,10 9328.38 9608.74 9895.33 10180.59 10463.32 62.300 65.530 68.790 66.130 64.380 64.890 64.100 64.390 65.800 64.160 65.390 63.850 63.310 62.500 65.510 65.330 64.880 64.810 65.890 66.390 66.410 66.120 66.680 62.620 64.140 65.240 65.320 64.440 66.110 65.330 Azim. 106.720 112.160 113.11o 111.950 111.220 111.950 111.170 111.200 111.320 112.290 111.050 112.390 108.150 lO8.630 108,670 108.750 110.060 109.690 108.980 111.15o 110.390 113.600 112,870 113.550 111.820 106.740 108.290 111,230 110,520 112.240 Sub-Sea Depth (ft) 2170.49 2253.56 2364.41 2436.24 2515.55 2635.77 2759.17 2883.23 3002.78 3122.82 3204.27 3274.12 3368.89 3498.66 3582.86 3700.21 3819.41 3918.98 4057.54 4172.90 4286.42 4401.53 4515.20 4637.15 4764.75 4885.49 5002.74 5124.42 5243.73 5360.00 Vertical Depth (ft) 2238,04 2321,11 2431.96 2503.79 2583,10 2703.32 2826.72 2950.78 3070.33 3190.37 3271.82 3341.67 3436.44 3566.21 3650.41 3767.76 3886.96 3986.53 4125.09 4240.45 4353.97 4469.08 4582.75 4704.70 4832.30 4953.04 5070.29 5191.97 5311.28 5427.55 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 550.72 S 1428.39 E 6007496.43 N 530736.33 E 1,547 1530.86 607.23 S 1588.18 E 6007440.55 N 530896.33 E 3.101 1700.30 708.54 S 1831.08 E 6007340.19 N 531139.63 E 1.182 1963.35 774.87 S 1990.93 E 6007274.49 N 531299.73 E 1.530 2136.32 838.18 S 2150.93 E 6007211.81 N 531459.99 E 0.988 2308.38 931.47 S 2386.73 E 6007119.45 N 531696.15 E 0.297 2561.93 1026.52 S 2627.28 E 6007025.34 N 531937.08 E 0.369 2820.56 1119.45 S 2867.04 E 6006933.35 N 532177.20 E 0.102 3077.70 1212.82 S 3107.01 E 6006840.93 N 532417.53 E 0.498 3335.18 1308.33 $ 3345.79 E 6006746.35 N 532656.69 E 0.656 3592.31 1372.16 $ 3506.46 E 6006683.15 N 532817.61E 0.871 3765.18 1426.64 $ 3643.25 E 6006629.22 N 532954.60 E 1.202 3912.39 1492.69 S 3822.06 E 6006563.86 N 533133.67 E 1.801 4103.00 1572.71S 4062.74 E 6006484.80 N 533374.67 E 0.321 4356.42 1627.93 S 4226.36 E 6006430.22 N 533538.50 E 1.567 4528.99 1710.22 S 4469.34 E 6006348.88 N 533781.80 E 0.069 4785.36 1795.55 S 4711,60 E 6006264.50 N 534024.40 E 0.449 5042.13 1867.63 S 4910.99 E 6006193.20 N 534224.07 E 0.146 5254.13 1967.60 S 5195.90 E 6006094.36 N 534509.37 E 0.379 5555.97 2057.07 S 5440.83 E 6006005.85 N 534754.65 E 0.718 5816.71 2149.21S 5683.78 E 6005914.67 N 534997.96 E 0.246 6076.55 2247.21 S 5926.43 E 6005817.62 N 535240.99 E 1.033 6338.18 2349.85 S 6165.50 E 6005715.92 N 535480.47 E 0.307 6598.12 2451.27 S 6402.08 E 6005615.43 N 535717.45 E 1.441 6855.28 2549.42 S 6636.96 E 6005518.20 N 535952.71E 0.761 7109.71 2633.59 S 6877,74 E 6005434.98 N 536193.81 E 1.673 7364.68 2710.23 S 7120.59 E 6005359.29 N 536436.96 E 0.503 7618.93 2797.92 S 7364.77 E 6005272.56 N 536681.48 E 0.978 7878.33 2890.24 S 7606.86 E 6005181,20 N 536923.94E 0.628 8137.43 2984.17 S 7846.84E 6005088.21 N 537164.28 E 0.619 8395.12 Comment Kuparuk 3K Continued... 24 June, 1998 - 12:42 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 3K-34 Your Ref: AP1-500292287900 Kuparuk Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 10749.48 64.630 111.240 5481.03 5548.58 11032.01 66.430 111.260 5598.05 5665.60 11319.78 64.320 112.200 5717.95 5785.50 11604.78 65.500 111.220 5838.80 5906.35 11887.74 63.760 110.230 5960.04 6027.59 12170.66 64.890 109.330 6082.62 6150.17 12455.69 63.860 109.150 6205.89 6273.44 12523.23 64.360 108.420 6235.38 6302.93 12549.62 63.330 107.940 6247.01 6314.56 12609.30 60.000 108.150 6275.33 6342.88 12735.61 57.830 107.400 6340.55 6408.10 12833,04 57.250 108.770 6392,84 6460,39 12927,68 56,590 108.430 64~,'!.49 6512.04 13022,37 55.540 110.280 6497.36 6564,91 13111,88 54.880 110,230 6548,43 6615,98 13204.53 53.640 111.250 6602.55 6670,10 13298,58 52.490 112,980 6659.06 6726,61 13394,52 52,110 114,330 6717.73 6785.28 1 3477.03 51.870 115,380 6768.55 6836,10 13535.40 51.870 116,000 6804.59 6872,14 3080.22 S 8087.69 E 6004993.10 N 537405.51 E 0,400 8654.39 3173.42 S 8327.35 E 6004900,85 N 537645.53 E 0.637 8911,52 3270.25 S 8570,35 E 6004804,97 N 537888.91 E 0,791 9173.06 3365,71 S 8810,15 E 6004710.45 N 538129,08 E 0.518 9431,13 3456.20 S 9049,25 E 6004620.91 N 538368,54 E 0,691 9686,79 3542,48 S 9289,19 E 6004535,57 N 538608.82 E 0,492 9941,73 3627,17 S 9531.83 E 6004451,84 N 538851,78 E 0.366 10198.63 3646,73 S 9589,35 E 6004432,50 N 538909.39 E 1,222 10259,35 3654,12 S 9611,86 E 6004425,20 N 538931,92 E 4.231 10283,01 3670,39 S 9661,80 E 6004409,13 N 538981,92 E 5,588 10335,48 3703,42 S 9764,80 E 6004376,50 N 539085.05 E . 1.792 10443,49 3728.93 S 9842.94 E 6004351.29 N 539163,29 E 1.327 10525,61 3754,23 S 9918,10 E 6004326.30 N 539238,55 E 0,760 10604.85 3780,26 S 9992.21 E 6004300,56 N 539312.77 E 1,964 10683,38 3805.71 S 10061.18 E 6004275.38 N 539381.83 E 0,739 10756,89 3832,33 S 10131,51 E 6004249.03 N 539452.26 E 1.609 10832.09 3860,62 S 10201,15 E 6004221.02 N 539522,02 E 1.912 10907.23 3891,07 S 10270,68 E 6004190,84 N 539591.67 E 1,182 10983,05 3918,40 S 10329,67 E 6004163,74 N 539650,76 E 1,044 11047.89 3938,30 S 10371.04 E 6004144.00 N 539692,21 E 0,836 11093.63 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, The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 110.770° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13535.40ft., The Bottom Hole Displacement is 11093.63ft., in the Direction of 110.794° (True). Comment Projected Survey Kuparuk 3K Continued,.. 24 June, 1998 - 12:42 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 3K-34 Your Ref: AP1.500292287900 Kuparuk Unit Kuparuk 3K Comments ,~ Measured Depth (ft) 0.00 13535.40 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 6872.14 3938.30 S 10371.04 E Comment Tie-on Survey .at surface Projected Survey 24 June, 1998 - 12:42 - 5 - DrillQuest [:l F! I L-I-- I I~ 13 S~I~/I C: ~ S WELL LOG TRANSMITTAL To: State of Alaska July 1, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Lori Tavlor 3001 Porcupine Dr. Anchorage, Alaska 99501 REz MWD Formation Evaluation Logs 3K-34, AK-MM-80255 1 LDWG formatted Disc with verification listing. APl#: 50-029-22879-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITr~ LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 995. _!..8 ~c --,*~ ...~:o~. ~:-,~ .. : Date: 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser. Industries, Inc. . , WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Tavlor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 3K-34, AK-MM-80255 July 1, 1998 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchor~e, AK 99518 3K-34: 2" x 5" MD Resistiv/tv & Gamma Ray Logs: 50-029-22879-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22879-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I=! I I_1_ I I~ CS S ~ I=IU'I C; E c: 25-Jun-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3K-34 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 13,535.40' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 18, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3K-34 Sundry Notice Dear Mr. Commissioner: Enclosed please find a sundry request for annular disposal in the Kuparuk Well 3K-34. This form is to satisfy AOGCC's request for information on this well prior to ARCO beginning annular disposal operations. Also enclosed are LOT plots, cement details and the casing detail sheets. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Team Leader Kupamk Drill Site Development ORIGINAL GCA/skad cc: Blair Wondzell r~--: '~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well _ Change approved program _ Operation Shutdown __ Re-enter suspended well _ Plugging __ Time extension _ Stimulate_ Pull tubing_ Variance_ Perforate_ Other X Annular injection 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service -- 4. Location of well at surface 1047' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 2507' FSL, 701' FEL, Sec. 6, T12N, R10E, UM At effective depth At total depth 2643' FNL, 522' FEL, Sec. 6, T12N, R10E, UM (intermediate casing depth) 6. Datum elevation (DF or KB) 41' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-34 9. Permit number 98-077 10. APl number 50-029-20879 11. Field/Pool Kuparuk River feet 12. Present well condition summary Total Depth: measured 12690 ** (approx) true vertical 6387 Effective depth: measured 12606' (approx) true vertical 6345' Casing Length Size Structural Conductor 80' 16" Surface 7035' 7.625" Intermediate 12649' 5.5" Production feet feet feet feet Plugs (measured) None Junk (measured) Cemented Measured depth True vertical depth 135 sxAS I 121' 121' 570 sx AS III 7076' 4020' & 240 sx Class G & 60 sx AS I 225 sx Class G 12690' 6387' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) ** intermediate casing depth is TD at this point in time. 13. Attachments Description summary of proposal __ Contact Tom Brockway at 263-4135 with any questions_. Detailed operation program BOP sketch _ 14. Estimated date for commencing operation May 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas _ Service X Suspended_ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ L/ ~ Title Area Drilling Engineer - FOR COMMISSION USE ONLY Date Plug integrity _ BOP Test _ Location clearance __ I Mechanical Integrity Test_ Subsequent form require 10-/4~? Approved by the order of the Commission0aVid ~]V ',.,,~,)st0n ¢..:..¢B~ Commissioner Date~~~~ Form 10-403 Rev 06/15/88 ~~~ SUBMIT IN TRIPLICATE ARCO Calculations Chart Subject Sheet number File I By Date I : ' : . ; ....... ~. ,. ~ ........ ' .... ~ ~.- ,. -. . ..... : ..... ~.,.,.~___.._, ~..-: ~ . .._ .. .~~ ~ - . _ . = _ - . : _ . ' . _ - _ .. ~. ~ _ · . - _ ~ - . ~. _ _ _ . . . I · I , ~ I , _ . ARCO ~I~ · --...alculath:. ns Char~ i ARCO ! '1' J i i .0 t i -- CASING I TUBING / LINER DETAIL 7'-5/8" Surface Casinq ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL: 3K-34 KRU DATE: 5/1198 1 OF 1 PAGES # ITEMS 48 Jts Joint 'B' Joint 'A' 118 Jts 1 Jt 2 Jts Ja COMPLETE DESCRIPTION OF EQUIPMENT RUN RKB to Landing Ring - Parker Rig #245 FMC Fluted Mandrel Casing Hanger 7-5/8", 29.7#, L-80, ABM-BTC Casing (Jts #122 thru #169) 7-5/8", 29.7#, L-80, ABM-BTC Casing - Baker Locked Gemoco '754' Stage Cementing Tool 7-5/8", 29.7#, L-80, ABM-BTC Casing - Baker Locked 7-5/8", 29.7#, L-80, ABM-BTC Casing (Jts ~ thru #121) Gemoco Insert Shut-Off Baffle 7-5/8", 29.7#, L-80, ABM-BTC Casing Gemoco Float Collar (Jt#3) 7-5/8", 29.7#, L-80, ABM-BTC Casing Gemoco Float Shoe (Jts#1 &#2) LENGTH 40.98 1.82 2003.26 35.71 2.86 DEPTH TOPS 40.98 42.80 2046.06 2081.77 38.68 2084.63 4829.66 2123.31 6952.97 36.33 1.32 83.51 1.48 Bottom of Shoe ==>> TD = 7090' MD (~15' Rathole ker Lock thru Insert Shut-Off Baffle, plus Stage Collar to Joints 'A' & 'B' Install Insert Shut-Off Baffle in Connection on Top of Jt Run Stage Collar & Baker Locked Jts 'A' & 'B' on Top of Jt #121 Run FMC Hanger on Top of Joint #t69 65 Bow Sprinq Centralizers: One on each of first 13joints (first two on stop rings), Then one on every 3rd joint to surface, Plus one on a stop ring on Baker Locked Jts ~A' & 'B' Leave OUT3 Joints: #170 thru #172 6952.97 6989.30 6990.62 7074.13 7075.61 Remarks: String Wei~lhts with Blocks: 250K~ Up, 110K# Dn, 75K~ Blocks. Ran 171 joints of casing. Drifted casing with 6.750" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections (National = BOL 2000). Torqued to the base of the triangle stamp. Parker Rig #245 Drilling Supervisor: Don E. Breeden & Pat Reilly ARCO Alaska, Inc. ' .... Cementing Details Well#: 3K-34 Field: Kuparuk River Unit Date: 5/1/98 Casing Size Hole Diameter KOP & AngleI Shoe Depth Baffle Depth I Stage Tool Depth 7-5/8" 9-7/8" 300' - 65* 7076' 6953' 2082' Centralizers State type used, intervals covered and spacing 65 Gemoco Bow Spring Centralizers: One on each of first 13 joints, first 2 on stop rings in middle of float joints; One on coupling of every third joint to surface, with one on stop ring in middle of joint on each side of Gemoco stage collar. Mud Weight PV(prior cond) PV(after cond) IYP(prior cond) YP(after cond) 9.7 ppg 27 32147 42 Gels before Gels after Total Volume Circulated 11 / 32 10 / 30 Stage 1:1067 Bbls / Stage 2:668 Bbls Spacer Type Volume Weight Water 50 Bbls/40 Bbls 8.34 ppg Lead Type I Mix water temp No. of sacks Weight Yield Cement AS III LWI --65* F 305 sx/265 sx 10.5 ppg 4.42 cfs Additives: Class G + 3.5% D44 + 0.4% D46 + 30% D53 + 1.5% D79 + 50% D124 + 1.5% S1 Cement Class G & AS 1I I I 1-'65' F 240 sx/60 sx 15.8 ppg/15.7 ppg 1.17 cfs/0.93 cfs Additives: Stage 1: Class G + 0.2% D46 + 0.3% D65 + 1.0% S1 Stage 2: Arctic Set 1 Displacement Rate(before tail at shoe) Rate(tail around shoe) Str. Wt. Up 6.8 BPM 6.6 BPM 250K~ Reciprocation length Reciprocation speed Str. Wt. Down ~15' -20 FPM 11 OK# (75K~ Blocks) Theoretical Displacement Actual Displacement Str. Wt. in mud 319.3 Bbls / 95.6 Bbls 320.7 Bbls / 96.4 Bbls 179K~ Calculated t°P °f cement I CIP Bumped plug I Floats held Cemented to Surface 1400 hrs, 5/1/98 Yes Yes Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. Stage #1: Prime & test lines to 3800 psi. Pump 50 Bbl water spacer, 6 BPM, 400 psi. Mix & pump 240 Bbls, 305 sx, 10.5 ppg AS III LW Lead Cement, 6.1 BPM, 350 psi. Load & drop bypass plug. Mix & pump 40 Bbls, 192 sx, 15.8 ppg Class G Tail Cement (with 1% CaCI & additives), 3.5 BPM, 200 psi to 100 psi. Load & drop shut-off plug. Chase plug with 10 Bbls, 48 sx, 15.8 ppg Tail slurry & 20 Bbls wash-up water, 6 BPM, 100 psi. Switch to rig pump & displace with mud, 6.8 BPM, 250 psi to 800 psi, slowed to 4.6 BPM last 5 Bbls. Bumped plug at 290.7 Bbls mud. Bumped up to 1300 psi & held 2 minutes, OK. Floats held. Full returns. Reciprocated 3ipe until 70 Bbls Lead Cement had rounded the shoe. Pipe got sticky at that time, so landed the hanger. 1st Stage ClP @ 1100 hrs, 5/1/98. Stage #2: Opened Gemoco Stage Tool at 2082' with 2350 psi. Circulated out 106 Bbls water spacer, cement, & cement contaminated mud. Had just started getting contaminated mud & water spacer at surface when 1st stage plug bumped. Circulated hole clean above stage collar and reconditioned mud for 2nd stage cementing. Pump 40 Bbls water spacer, 6 BPM, 200 psi. Mix & pump 10.5 ppg AS III LW Lead Cement until getting good 10.5 ppg returns, 6.3 BPM, 200 psi. Water spacer returns at 155 Bbls Lead Slurry pumped, 10.4+ ppg cement returns at 196 Bbls pumped, 10.5 ppg cement returns at 200 Bbls, switched to Tail at 209 Bbls, 265 sx of Lead Slurry pumped. Mix & pump 10 Bbls, 60 sx, 15.7 ppg Arctic Set I Tail Cement, 2.7 BPM, 200 psi. Drop closing plug & chase with 20 Bbls wash-up water, 6.3 BPM, 220 psi. Switch to rig pump & displace with mud, 6.5 BPM, 300 psi to 550 psi, slowed rate to 4 BPM last 4 Bbls. Bumped plug at 76.4 Bbls mud. Pressured up & stage tool closed at 1500 psi. Held 2000 psi for 2 minutes, OK. Bled off pressure & checked floats, OK. Had clean break-overs from mud to water spacer to cement, with minimal thick, cement contaminated mud. Had full returns throughout. Got good 10.5 ppg cement returns to surface. 2nd Stage CIP @ 1400 hrs, 5/1/98. Cement Company I Rig Contractor I Signature Dowell I Parker Rig #245 I Don E. Breeden & Pat Reilly I M NDUM , TO:. , David Jc, h~ Chairman State of Alaska Alaska Oil and- Gas C0nse?~_~__~8 _.Commission THRU' FROM' Blair Wondzell, P. I. Supervisor Larry Wade, ~ Petroleum Inspector FILE NO: .DOC SUBJECT: BOP Test Parker 245 KRU 3K-34 PTD 98-077 May 1,1998: I traveled to Kuparuk to witness a BOP test on Parker 245. i arrived at 6 PM and the BOP test started at 10 PM. The test went smooth even though we tested across towers. SUMMARY: BOP test on Parker 245. 0 failures 3.5 hours Attachments: acxgeafe.xls cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Parker Rig No. Operator: ARCO Well Name: KRU 3K-34 Casing Size: 7 5/8 Set @ 7,074 Test: Initial X Weekly Other DATE: May 1,1 998 245 PTD # 98-077 Rig Ph.# 659-7670 Rep.: Don Breedon Rig Rep.: Fred Herbert Location: Sec. 35 T. 13N R. RgE Meddian Urniat MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location X Standing Order Posted X Well Sign X Drl. Rig ok Hazard Sec. X FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 250/5,000 P 'I 250/5,000 P 1 250/5,000 P 1 250/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. 250/2500 250/5,000 250/5,000 250/5,000 f 250/5,000 f 250/5,000 2 250/5,000 250/5,000 MUD SYSTEM: Visual Trip Tank X Pit Level Indicators X Flow Indicator X Meth Gas Detector X H2S Gas Detector X P/F P P P P P P Alarm X X X X X CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 16 250/5,000 P 38 250/5,000 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3000 i 1650 minutes 30 2 minutes 34 X Remote: 2000-2200-2200 2200-2200-2000 Psig. sec. sec. X ,, , Number of Failures: 0 ,Test Time: 3.5 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I REMARKS: Distribution: ofig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES NO 24 HOUR NOTICE GIVEN YES NO Waived By: Witnessed By: Larry Wade F1-021L (Rev. 12_/94) acxgeafe.xls TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 20. 1998 Michael Zanghi Drilling Superintendent ARCO Alaska, Inc. P O Box 100360 Anchorage, AK. 99510-0360 Re: Kuparuk River Unit 3K-34 ARCO Alaska, Inc. Permit No. 98-77 Sur. Loc. 1047'FSL, 316'FWL, Sec. 35, T13N, R9E, UM Btmnhole Loc. 2414'FSL. 455'FEL. Sec. 06, TI2N. RIOE. UM Dear Mr. Zanghi: Encloscd is thc approvcd application for permit to drill thc above referenced xvcll. The permit to drill docs not exempt you from obtaining additional pcrmits required by law from othcr governmental agcncics, and docs not authorize conducting drilling opcrations until all other required pcrmitting determinations arc made. Annular disposal of drilling xvastc will not be approved until sufficient data is submittcd to ensure that thc requirements of 20 AAC 25.080 arc met. Annular disposal of drilling wastes v,'ill be contingent on obtaining a well cemented surface casing confirmcd by a valid Formation Integrity Test (FIT) - cementing rccords. FIT data. and an,,' CQLs nmst bc submitted to thc Commission prior to thc start of disposal operations. Thc blowout prcvcntion cquipmcnt (BOPE) must bc tcstcd in accordance with 20 AAC 25.035: and thc mechanical integrity (MI) of thc injection ~vclls must bc dcmonstratcd under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of thc MI tcst before operation, and of thc BOPE tcst pcrformcd bcforc drilling below thc surface casing shoe, must be given so that a representative of the Commission ma,,' witness thc tcsts. Noticc may be givcn bv r on the North Slope pager at 659-3607. David W. Jo~lnston ~ -"" Chaim~an ~ BY ORDER OF THE COMMISSION dlf/Enclosttre I)cpartmcnt of Fish & (}amc? t Iabitat Section w/o encl. I)eparlmcnt of F, nvironmcntal Conservation w/o cncl. ~; .... ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Drill X Redrill F' lb TypeofWell Exploratory ~, StratigraphicTest ['- Development Oil Re~Entry F~ Deepen F service X Development Gas E~; single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 34' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25628,--ALK 2561 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1047' FSL, 316' FWL, Sec. 35, T13N, RDE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 2507' FSL, 701' FEL, Sec. 6, T12N, R10E, UM 3K-34 #U-630610 At total depth 9. Approximate spud date Amount 2414' FSL, 455' FEL, Sec. 6, T12N, R10E, UM 4/20/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3K-14 13544' MD 2414' @ TD feet 12.8' @ 200' feet 2560 6895' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 64.86° Maximum surface 2370 psig At total depth (TVD) 2812 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 9.875" 7.625" 29.7# L-80 LTC 7101' 41' 41' 7142' 4017' 610 Sx Arcticset III & HF-ERW 480 Sx Class G & 60 sx ASI 6.75" 5.5" 15.5# L-80 LTC MOD 12629' 41' 41' 12670' 6372' 170 Sx Class G HF-ERW 6.75" 4.5" 12.8# L-80 EUE 874' 12670' 6372' 13544' 6895' 8rdM 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vedical feet u (J~ t~"~, Vertical depth Casing Structural Length Size Cemented~-~-~' ~-~ LD~'Ctv~a~'~"~PU True Conductor Surface Intermediate /! r..~ O ~ ~ 'in q (t Production ~,i i~ i -~- ~,~,O Liner Perforation depth: measured J~a$~-~ Oil & Gas Cons. Com..missio~. true vertical Anchorage 20. Attachments Filing fee X Property plat F.~ BOP Sketch X DiverterSketch X Drilling program X Ddlling fluid program X Timevs depth plot [~ Refraction analysis [~ Seabed report [~ 20AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Dig ne,~~___ ~ " 4F°r questions, please call Tom Brockway 263-135 Title: Drilling Superintendent Date Commission Use Only PermitN~_~bcr I AP, number I Appr°va'date~'~ ~[~.'¢~Ye I Seec°ver'etterf°r - q) 7-2 50- l:~°t - ,~, ~ ~0 7c~ other requirements Conditions of approval Samples required [~ Yes [~ No Mud Icg required . s ~ No Hydrogen sulfidemeasures ~ Yes E No Directional surveyrequired [~ Yes [~ No Required working pressure for BOPE ~' 2M [~ 3M E 5M [~ 10M r-~ 15M Other: Original by order of Approved by David ~'~/. Job ~s ~01 Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate GENERAL DRILL AND COMPLETE PROCEDURE KUPARUK RIVER FIELD - INJECTOR KRU 3K-34 1. Move in and rig up Parker #245. 2. Install diverter system. 3. Drill 9-7/8" hole to 7-5/8" surface casing point (+/- 7142') according to directional plan. 4. Run and cement 7~5/8" casing, using stage collar placed at least 200' TVD below the base of the permafrost, and light weight lead cement. 5. Install and test BOPE to 3000 psi. Test casing to 2000 psi. 6. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 7. Drill 6-3/4" hole to well total depth (+/- 13544') according to directional plan, running LWD logging equipment as needed. 8. Rig up and run E-line logs if needed. 9. Run and cement 5-1/2" x 4-1/2" tapered casing string with polished seal bore as part of XO. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job has been completed. 10. Pressure test 5-1/2" x 4-1/2" casing string to 3500 psi. 11. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. 12. Nipple down BOPE. Install tubinghead, master valve, and upper tree assembly. 13. Shut in and secure well. 14. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. Note: As a dedicated injector, cased hole cement bond logs (SLT-J or CBT) will be run to establish isolation after the cleanout is completed, but prior to perforating. 3K-34 TAB,04/08/98, v.1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Well KRU 3K-34 Drilling Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +/-10% Drill out to Weight Up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drill out to TD 11.0-11.5 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2,370 psi. Therefore, ARCO Alaska, Inc. will test BOP equipment to 3,000 psi. MASP = (4017 ft)(0.70 - 0.11)psi/ft - 2370 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of 1D pad are expected to be 3700 psi (0.58 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 11.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 6423'. Well Proximity Risks: The nearest exiSting well to 3K-34 is 3K-14. As designed, the minimum distance between the two wells would be 13' at 200' MD. Drillin.q Area Risks: Risks in the 3K-34 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. If lost circulation cannot be controlled with LCM and a reduction of circulatiing pressure, 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #2 or a coiled tubing unit will drill out 4-3/4" hole and run a 3-1/2" liner to TD. Careful analysis of pressure data from offset wells shows that a mud weight of 11.5 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing permitted 3K Pad 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 3K-34 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3K-34 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please 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 shoes will be set _+200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 4007 psi The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85%of Burst 85%of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 7.625 29.7 L-80 3 BTC 4790 4071 6890 5856 5.500 15.5 L-80 3 LTC-M 4990 4241 7000 5950 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 ~¢~' (1). 3K-34 TAB, 3/05/1998, v.1 5OO 500 - - 1000 - 1500 - -+- 2000 2500 -I-- ~ 5000 5500 ,-- >. 4000 4500 I 5000 5500 6OOO 65O0 7000 Created by finch For: BROCKWAY Date plotted : 8-Apr-98 Plot Reference is .34- Version ~/3. Coord;notes are ;n feet reference slot ~134. ARCO Alaska, inc. Structure : Pad 5K Well : .34 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 700 0 700 1400 2100 2800 3500 4200 4900 5600 6500 7000 7700 8400 9100 9800 10500 S~RF;CE LOCZT,O& 1 KOP TVD=800 TMD=a00 DEP=0 [ 1047' FSL ~16' FWL 9.00 ~Base Permafrost J TARGET LOCATION: .21.00 ~ 97 nn ~Top Ugnu Sands TARGET ~ ..... ~ TVD=6674 X~ aa ~ T~D=~ a2o~ x ' ~ DEP=10772 ~ 59.00 _ _ ~Top West Sak Sands SOUTH 5820 ~45.00 B/ PERMAFROSTWD=1631 TMD=1773 DEP=540 % =.cT ~ c. ~ % Dose west bOK ~ a 3~.~% ~ ~ 7 5/8 Casing 3500 MAXIMUM ANGLE ID - Casing Pt 64.86 DEG T/ W SAK SNDS WD=3483 TMO:5885 DEP=4197 4200 B/ W SAK SNDS ~D=5817 TMD=667~ DEP=4909 7 5/8" CSG PT ~D=4017 TMD=7142 DEP=5555 TD LOCATION: 2414' FSL, 455' FEL SEC. 6, T~ 2N, R10E 700 2100 2800 I V 110.77 AZIMUTH 10772' (TO TARGET) TARGET ANGLE 50 DEG CAMP TURB SNDS TVD=5885 TMD=11539 OEP=g316 B/ HRZ TVD=6194 TMD=12267 DEP=9974 BEGIN ANGLE DROP TVD=6275 TMD=12457 DEP=10147 K-1 MARKER TVD=6297 TMD=12508 DEP=10195 T/ D. TVD=6423 TMD=12770 DEP=10422 DLS: 2.00 de9 per 100 ft T/ C TVD=6519 TMD=12946 DEP=10569 64.00 TVD=6561 TMD=13018 DEP=10628 T/ BT/ A TVD=6655 TMD=15171 DEP=10749 58.00 54.00 TARGET A3 (EOD) TVD=6674 TMD=13EOI DEP B/ KUP TVD=6766 TM0=1.3344 DEP=10881 TD - CSG PT TVD=6895 TMD=13544 DEP=l1035 ~ J- i [ i J ] i '[I '--'T---I-- II i i I i ] i I i I i i I i I I II I I i t t I I [ I I I I i I I [ I 500 0 500 1000 1500 2000 2500 3000 .'5500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 VedicaJ Section (feet) -> Azimuth 110.77 with reference 0.00 N, 0.00 E from slot #34 8O 4O 8O 120 -i.- ~ 160 -+- 200 0 24O I 280 Creoted by finch For: BROCKWAY Dote plotted : 8-Apr-98 Plot Reference is 34 Vets;an #3. Coordlnotes ore in feet reference slot ~34. ARCO Alaska, Inc. Structure: Pod 3K Well : 34 Field : Kuporuk River Unit Location : North Slope, Alaska East (feet) -> 80 40 0 40 80 120 160 200 240 280 320 360 400 440 480 520 560 600 640 680 720 760 800 I I I I I I I I I I I I I I I I I I I I I I I I f I I I I I I I I t I 80 ~'---~ 1800 900 "'""- 1900 1100 4O 3200 1200 '"'"-....~ 2000 1600 1300 '-..... t~.~ 1700 1400 '"'-~ 2100 0 --.. 800 1800 1500 '"'"'-~.~200 1900 1600 '""-~ 2300 -. 1100 1700 "'"'"- 2400 5O0 700 200 3500 1300 1800 2500 )00 1400 2100 1400 2600 1 1200 5600 2700 800 100 1500 2000 1300 9OO 1600 1200 28OO 290O 1700 3000 2100 1400 I100 3100 1300 380( 1800 1200 1500 120 0 160 200 '-~ 240 V 28O 320 3900 1300 32O 25OO 360 400 4000 t400 360 400 26O0 440 1500 4-40 4100 4-80 i ~ '--'T-'--r'-- ~ 80 40 0 40 1 i i i i i i i i I i i i i i i i i ~ i i i i i i [ T i i 480 0 120 160 200 240 280 320 360 400 440 480 520 560 600 64-0 680 720 760 800 East (feel) -> ICreeted by finch For: BROCKWAY] Date platted : 8-Apr-g8 Pict Reference ia 34 Vere{cn #3. At, CO Alaska, Inc. Structure: Pod 3K Well : 34 Field : Kuporuk River UnH LocoHon : North Slope, Alosko East (feet) -> 500 600 700 800 900 1000 1100 1200 1500 1400 1500 1600 1700 1800 1900 2000 2100 2200 2500 2400 2500 2600 2700 ~ ~2..ZO0 2900 1 oo 31 O0 o q~ 1 oo 2700 2900 20o 17O0 21 O0 500 25OO 33O 2300 ~ 400 .+_ ~-~ 500 0 600 2700 I V 700 800 900 1000 1100 1200 2500 29OO 5100 3900 33OO 4100 2500 ::tttt~ 4300 '""~50"~0~ 2700 4700 2500 490; .... ....... 51~ .... ,.' ......... ~..~0 5500 '"-. "'-~ 2500 55~-... "'"'..... 5700 '".. ' ..... 59;; ....... ' ............. .... 2700 5500 610~'"'-..... '"'"-...... 630~""-.... 3100 3700 390O 6500 '""~ t i .... i- i I i -[ [ i ---I---"-'-T----'-I t i [ i i I I I i I i t I i ] i i I i i i i I i i i - i [ i I 500 600 700 800 900 1000 1100 1200 1500 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 Eosf (feet) -> 1 O0 ,,f lOO 2OO 300 400 0 500 600 --.4- 700 V ~,. 8O0 1200 11oo 1 ooo 9oo 4OO 4O0 80O 1200 1600 · 20O0 -+- 2400 0 2800 I V 3200 3600 4000 4400 4800 5200 - Created by finch For: BROCKWAY1 Dote plotted : 8-Apr-98 Plot Reference is 34- Vets;on #,.3. Coordinates ore in feet reference slot ~34. ARCO Alaska, Inc. Structure : Pad 3K Well : 34 Field : Kuparuk River Unit Locaflon : NoH'h Slope, Alaska Eest (feet) -> 2000 2400 2800 3200 5600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 9200 9600 10000 10400 3100 3300 5500 3700 3900 4100 4300 4500 4700 4900 5100 5300 5700 6100 6700 ~2900 "~,~4700 ....... ~vnn -~'-..~4700 ----~90q.__ '"~L~ % 49oo '"""-- 4900 "' ....~.5100 00 O0 4300 ', 5oo ~N,~700 4900 %k~10o "~300 "~500 5700 5900 '~100 '"~,,6300 "~500 5300 '" .... '--~ 5500 '"'""--.. 5700 "'--~ 5900 '"'--~.6100 .......... 6300 ....... 95oo '---. 6700 i --"i~---"l T T---' I i T- I I -'T- I i 1' '1 i i i i i i i i i i I i r i T---F--' i i r i i i i -'--T i i i 1 2000 2400 2800 .5200 .5600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 9200 9600 10000 10400 400 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 52OO Fr,.f {f¢¢+/ --'~ ARCO Alaska, Inc. Pad 3K 34 slot #34 Kuparuk River Unit North Slope, Alaska 3-D M I N I M U M D I S T A N C E C L E A R A N C E Baker Hughes INTEQ REPORT Your ref : 34 Version Our ref : prop1803 License : Date printed : 8-Apr-98 Date created : 27-Aug-96 Last revised = 30-Mar-98 Field is centred on n?0 16 18.576,w150 5 56.536 Structure is centred on nT0 25 48.667,w149 45 49.2 Slot locatlon is n?O 25 58.964,w149 45 39.928 Slot Grid coordinates are N 6008040.722, E 529307.776 Slot local coordinates are 1047.00 N 316.00 E Projection type; alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object we11path PGMS <O-9960'>,,2,Pad 3K PG~S <0-10944~>,,32,Pad 3K PG~S <0-9150'>,,1,Pad 3K P~MS <0-8900~>,,3,Pad 3K PGMS <0-8980~>,,4,Pad 3K PGMS <O-8140~>,,5,Pad 3K PGMS <O-8100t>,,6,Pad 3K PGMS <0-8500~>,,7,Pad 3K PG~S <O-8500~>,,8,Pad 3K PGMS <0-7580~>,,gA, Pad 3K PMSS <5275 - 7443'>,,9,Pad 3K PG~S <0-7300'>,,10,Pad 3K PGMS <O-7853'>,,11,Pad 3K PG~S <O-7770'>,,12,Pad 3K PGMS <0-8580 >,,13,Pad 3K PG~IS <0-8960 >,,14,Pad 3K PG~S <0-9275 >,,IS,Pad 3K PGMS <0-9843 >,,18,Pad 3K PGMS <0-9584 >,,17,Pad 3K PGMS <0-9038 >,,16,Pad 3K PMSS (SS) <648-11180'>,,22,Pad 3K PMSS <834 - 11690~>,,26,Pad 3K PMSS <121 - 10462'>,,23,Pad 3K PMSS <10187 - 10456'>,,27,Pad 3K PMSS <463-10375~>,,30,Pad 3K Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 10-0ct-96 362.1 0.0 0.0 18-Jun-97 49.6 325.0 325.0 10-0ct-96 387.1 0.0 0.0 10-0ct-96 337.1 0.0 0.0 10-0c~-96 312.1 0.0 0.0 10-0ct-96 286.4 350.0 350.0 10-0ct-95 262.1 0.0 325.0 10-0ct-96 237.1 0.0 0.0 10-0ct-96 212.0 100.0 100.0 10-0ct-96 187.1 0.0 0.0 10-0ct-96 187.1 0.0 0.0 10-0ct-96 111.4 350.0 9840.0 10-0ct-96 87.7 200.0 200.0 10-0ct-96 62.1 100.0 100.0 10-0ct-96 34.6 350.0 350.0 10-0ct-96 12.8 200.0 200.0 10-0ct-96 14.1 100.0 100.0 10-0ct-96 88.2 0.0 0.0 10-0ct-96 62.3 0.0 450.0 10-0ct-96 38.5 0.0 450.0 15-May-97 323.1 375.0 375.0 5-Jun-97 225.0 100.0 100.0 16-Jun-97 300.0 100.0 100.0 16-Jul-97 200.0 0.0 375.0 30-Jun-97 100.0 100.0 100.0 P~MS <0-9000t>,,35,Pa~3K 31 Version #2,,31,Pad 3K 25 Version #2,,25,Pad 3K 6-Apr-98 30-Mar-98 8-Apr-98 20.1 75.0 250.0 300.0 300.0 525.0 300.0 300.0 1 J~/3/971DCS BGM PER~I(~'-~ K--~61~ /'~ OUKTOK PT. . ,, I , o 4 2~ · ~CIN! TY MAP o 5 o 6 ~CALE: 1"= 2 MILES 25 · o 7 , I 26 ~ , 8 2F · o ~ LEGEND o EXIS~NG CONDUCTORS o 10 ~ ~0 · · NE~ CONDUCTOR LOCA ~ON 0 11 12 , ~2 ~ ~ o ~ · ~ ~T I 0 14 ' o 15 ~ o 16 i J6 · 0 ~ i I ! NO ~L~ ~ ~ ~5 T. 1~ N. 2~ T. 12 N. SEE SHE~ ~ 2 FOR NOTES ~D LO~TION INFORMATION LOUNSBURY & ASSOCIATES, INC. E~~ P~NERS S~YO~ , , AREA' 3K M~ULE ~ UNIT' D3 ARCO Alaska, Inc. ~LL CONDUCTORS ~22-27, 30-36 LOCA~ON AS-BUILT LK6311Og 03/01/97 CEA-D3KX-6311D9 1 OF 2 1 i D£$CRIPTION PER"~"'SB# K96140ACS NOTES 1. COORDINATES SHOWN ARE A.S,P. ZONE 4, N,A.D. 27, ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. 2. BASIS OF LOCATIONS AND ELEVATIONS ARE D.S. 3-K MONUMENTS PER LHD AND ASSOCIATES. 5. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 55. TOI4/NSHIP 15 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 4. SEE DRAWING NSK 86-51 (CEA-DSKX-8651), FOR INFORMA T/ON ON CONDUCTORS //I - //18. 5. DATE OF SURVEY: 02/26-27/97, FB: 97-04, PG 54-62, 05/01/97, FB: 97-04, PG 71-73. 6. DRILL SITE 5-K GRID NORTH IS ROTATED 179' 55' 50" WEST FROM A.S.P. ZONE 4 GRID NORTH Sec. 35, T. U.M. A.S.P.s 'Y' 'X' 6, 008, 566. 54 6,008,541.52 6, 008, 316. 51 6, 008, 291.50 6, 008, 266. 25 6, 008, 241.56 6,008,141.37 6,008,116.57 6,008,091.62 6, 0O8, 066. 76 6, 008, 04 I. 51 6, 008, 016. 48 6,007,991. J8 529, 306. 21 529, 306.10 529,306..1J 529, 306. lJ 529, 305. 78 529, 305. 97 529, 306. 04 529, 305. 88 529, 505. 51 529, JO5. 49 529, 305. 79 529, 505. 79 529,505. 46 15 N., R. 9 E. LA T/ TUD E L ONGI TUDE 70' 26' 02.169" 70' 26' 01.92J~ 70' 26' 01.675" 70' 26' 01,431" 70' 26' 01.182" 70' 26' 00.9J9" 70' 25' 59. 954" 70' 25' 59. 708" 70' 25' 59.465" 70' 25' 59.220" 70' 25' 58.972" 70' 25' 58. 726" 70' 25' 58. 4 79" 149' 45' J9.9J6" I49' 45' J9. 942" 149' 45' J9.944" I49' 45' J9.947" 149' 45' J9.960" 149' 45' J9,957" 149' 45' J9.967" 149' 45' J9.974" 149' 45' J9.988" 149' 45' J9.992" 149' 45' J9. 986" 149' 45' J9.989" 149' 45' 40. 001" DESCRIPTION OUKTOK PT. VIC/N/TY MAP SCALE: 1" = 2 MILES SURVEYOR'S CERTIFICATE I HERE8Y CERTIFY THAT I AM PROPERLY REGISTEREO AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT TH I S PLA T REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH 2. 1997. . LOUNSBURY & ASSOCIATES, INC. EERS PLANNERS SURVEYORS ARCO Alaska, Inc. LK6311D9 05/01/97 AREA' 3K YODULE' XX UNIT' D3 DRILL SITE 5-K WELL CONDUCTORS #22-27, ,30-56 LOCATION AS-BUILT CEA-D3KX-6511D9 { SHEET:2 OF 2 IREV: KUPAFIUK FIlV R ,IT' 20" DIVERTER SCHE ATiC 6 3 DO NOT SHUT IN DIVERTER -.AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE ~ OPERA'ri'ON UPON INITIAL INS'TAU..AT[ON: · CLOSE VALVE AND FILL J=REVENTER wri'H WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERA'FION AND THATTHE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE ~'I'HAT AN INFLUX OFWF I PORE FLUIDS OR ~ OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA. INC.. REQUEST~ APPROVAL QFTHI,e OIVERTER SYSTEM AS A VARIANCE FROM 20AAC2~.035~) 1. 16' CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY Wrl'H 0NE2-1116'- 2000 PSi BALL VALVE. 4. 20' - 2000 P.ei DRILLING ,ePOOL WITH ONE 16' OUTLET. 5. ONE ! 6' HCR KNIFE VALVE WITH 16' DIVERTER MNE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL ~]E PLACED FOR OPTIMUM DISPERSION IN PREVAIUNG WINO CONDITIONS. 6. 20' - 2000 PS! ANNULAR PREVENTER. 7 6 13 5/8" 5000 PSi BOP STACK ACCUMUt.~,TOIq CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYORAUMC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSi WITH tS00_P~SIDOWNSTi;IEAMOETH ER EGIJ LATDR ...... 3. OBSERVE TIME. THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNIT~ ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER EMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 4 2 I. 16' - 2000 PS! STARTING HEAD 1 I' - 3000 PSI CASING HEAD 11=-3000PS1X 13-5/8'-5000 PSI SPACER SPOOL 4. 13-5/8' - 5000 PS! VARIABLE PIPE RAMS 13-5A]' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6.' 13-5/8' - 5000 PS1 DOUBLE RAM W/ PIPE RAMS ON TOP. BUND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR 1. FILL 8DP STACK AND MANIFOLD WITH WATER. 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENT~ TO 250 PSI AND HOLD FOR 3 MINUTE~ INCREASE PRESSURE TO 5000 PS! AND HOLD FOR 3 MINUTE~ BLEED TO ZERO PSI. TESTANNULAR PREVENTOR TO 3000 ~ ONLY. [ OPEN ANNULAR PREVENTORAND MANUAL KILL AND CHOK~ENE VALVE& ~ CLC~E TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOK~ LINE~. 7. TEb'TTO 250 PSI AND 5000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES. LINES. AND CHOKES'WlTI4 A 2S0 PSI LOW AND 5000 PSI HIGH. TEST AS IN STEP 4. DO NOT P~ TEar ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. & OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAM& TEb'T BO3'I~M RAMS TO 250 PSI AND 5000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OLrF OF HOLE. CLOSE BUND RAMS AND TESTTO 5000 PSI FOR 3 MINUTE~ BI ~ TO ZERO PSI. 10. OPEN BUND RAMS AND RECOVER TEST PLU~ MAKE SURE MANIFOLD AND ENES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SETIN THE DRILMNG POSITION. ! 1.TEST STANDPIPE VALVES TO 5000 PSI FOR 3 MINUTES. 17_ TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. ]4. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE ALL FLANGES AND SEALS BROKEN BETWEEN THIS TESTAND THE PRIOR 'ONE WILL BE TESTED TO 250 PSI LOW AND 50(30 PSI HIGH · WELL PERMIT CHECKLIST COMPANY ,(~¢..~(.....~ WELt. NAME FIELD&POOL ADMINISTRATION 1 I'~lri~il leu atlached 2 I eas~:, ~unlhel appropliale 3 Unique well name and i~umbe~. 4 Well Iocaled in a defined pool .......... 5 Well Iocaled prope~ dislance from drilling unit boundary. 6 Well Iocaled proper distance from other wells.. 7 Sufficienl acreage available in drilling unit . . . 8 If devlaled, is wellbore plal included 90peralor only affected pady. 10 Ope~alor has appropriate bond in force. 11 [.-'ernHI can be issued withoul conservation order 12 Permit can be issued wilhoul administralive approval 1:~ ('.a,~ pe~n,t be approved before 15-day wail ENGINEERING GEOLOGY GEOL AREA 17 CMI vol adequale to lie-irt long string Io surf csg -' . . 18 (;MI will cover all known produclive horizons.. 19 Ca¢ing designs adequate for C, 'f. B'& permafrost 20 Adeqt~ate tankage or reserve pit ........... 21 Il a r¢:.dlill, has a 10-403 for abandonrnenl been approved. 22 Adeqtlate wellbore sepa~alion proposed . 23 If diveder required, does it meel regulations 24 Drilling fhd¢t program schemalic & ecit,p list adequale 25 -Bf.)PEr;. do ll~ey rneet regulatio~ 26 BOPE p~ess rating appropriate: lesl lo. 27 Choke manifold complies w/APl RP-53 (May 84) . 28 Work will occur without operation shutdown. 2fi I,~; F, eserl(:e of tI.,S gas probable PROGRAM: exp [] dev [] redrll [] serv,,~wellbore seg [, )osal para req ~ ' . UN,~'~__ / / / 4~ 0 ON/OF~ SHOR~___~.~ ..... REMARKS · N ~N_, 14 C(.)rKJuclor st~mg provided N 15 Stuface casing protects all known USDWs ................................................................................................................... 16 CMT vol adequate Io circulate on conductor & surf csg.. N t~ .................................................................... pslg N , N 30 F)ermit car:~'L~e.j.~ssued w/o hydrogen sulfide m._.~e, ast-~es- ................ 31 Data presented o"~R'po.l, eLqJi~.al ~Jr_p-ressrli~'-,~ones 32 Sels~i~.~c; analysis ~alto¢:;~-zones ...... 33 Seab(~-~Su~vey (if off.-shore) . '--~-'~-': ....... ~ . 3,1 ~J f~a~e/pho~m for we~klyprogress rej)qrls ...... lexploraloty onfy] _G_ E _0_ .L: ~_}_t.G_ '~1 _E NGI N~_R LN_G'' COMMISSION Comments/Instructions: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Tue Jun 23 16:03:49 1998 Reel Header Service name ............. LISTPE Date ..................... 98/06/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Tape Header Service name ............. LISTPE Date ..................... 98/06/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 3 AK-MM-80255 S. BURKHARDT D. BREEDEN 3K-34 500292287900 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 23-JTJN-98 MWD RUN 6 AK-MM-80255 D. LONG DON WESTER 35 13N 9E 1047 316 67.60 ' m - R. ECe ,vED JUL 0 1 !998 Alaska ¢i & Gas Cms, ~mmi~ion DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 62.00 34.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 7.625 7066.0 6.750 5.500 12673.0 4.750 13539.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL DEPTHS ARE DRILLER'S DEPTHS. DEPTH SHIFTING OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN MIKE WARNER AND A. TURKER ON 06/16/98. MWD IS PDC. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND NOT PRESENTED. 4. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PFIASE-4 (EWR4). 5. MWD RUN 4 DID NOT MAKE ANY FOOTAGE DUE TO LOSS IN CIRCULATION, NOT PRESENTED. 6. MWD RUN 5 IS DIRECTIONAL ONLY AND NOT PRESENTED. THIS RUN WAS LOGGED UTILIZING THE NORDIC II RIG. 7. MWD RUN 6 IS DIRECTIONAL WITH NATURAL GAMMA R_AY PROBE (NGP). THIS RUN WAS LOGGED UTILIZING THE NORDIC II RIG. 8. THERE ARE GAPS IN DATA BECAUSE TWO RIGS WERE UTILIZED ON THIS WELL. 9. MWD RUNS 1 THROUGH 6 REPRESENT WELL 3K-34 WITH API# 50-029-22879-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13539'MD, 6872'TVD. SROP= SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC= SMOOTHED GAMMA RAY COMBINED. SGRD= SMOOTHED GAMMA RAY. SEXP= SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP= SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP= SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP= SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE= SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 7078.5 13477.0 RPD 7085.0 12634.0 RPS 7085.0 12634.0 RPX 7085.0 12634.0 RPM 7086.0 12634.0 FET 7132.0 ROP 7140.0 13539.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 7140.0 12681.5 6 12705.5 13539.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPM MWD OHMM 4 1 68 4 2 RPS MWD OHMM 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPD MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 ROP MWD FT/H 4 1 68 24 7 GR MWD API 4 1 68 28 Name Min Max DEPT 7078.5 13539 RPM 1.1113 20.2896 RPS 1.0955 10.2092 RPX 0.8939 8.7184 RPD 1.1992 20.0796 FET 0.1202 13.8332 ROP 6.96 680.86 GR 42.19 591.586 Mean Nsam 10308.8 12922 3.68554 11097 3.50416 11099 3.37978 11099 3.77764 11099 0.654232 11005 222.325 12752 123.523 12769 First Reading 7078.5 7086 7085 7085 7085 7132 7140 7078.5 Last Reading 13539 12634 12634 12634 12634 12634 13539 13477 First Reading For Entire File .......... 7078.5 Last Reading For Entire File ........... 13539 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 7078.5 RPD 7085.0 RPS 7085.0 RPX 7085.0 RPM 7086.0 STOP DEPTH 12627.0 12634.0 12634.0 12634.0 12634.0 FET 7132.0 ROP 7140.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERS ION: 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 $ 12634.0 12681.5 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 PM: 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 Lo99in9 Direction ................. Down Optical lo9 depth units ........... Feet 06-MAY-98 MSC 1.32 PCD 3.01 MEMORY 12681.5 7140.0 12681.5 60.0 66.7 TOOL NUMBER P0921SP4 P0921SP4 6.750 6.8 LSND 9.00 53.0 11.1 500 7.6 3.400 1.670 3.300 3.100 .0 /SPC 5.74 51.7 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 DEPT ROP GR RPX RPS RPM RPD FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD 3 FT/H 4 1 68 MWD 3 API 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max DEPT 7078.5 12681.5 ROP 11.2893 574.892 GR 49.4858 591.586 RPX 0.8939 8.7184 RPS 1.0955 10.2092 RPM 1.1113 20.2896 RPD 1.1992 20.0796 FET 0.1202 13.8332 Mean Nsam 9880 11207 242.805 11084 123.745 11098 3.37978 11099 3.50416 11099 3.68554 11097 3.77764 11099 0.654232 11005 First Reading 7078.5 7140 7078.5 7085 7085 7086 7085 7132 Last Reading 12681.5 12681.5 12627 12634 12634 12634 12634 12634 First Reading For Entire File .......... 7078.5 Last Reading For Entire File ........... 12681.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/23 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 ....... 98/06/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SI/MMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12642.0 13477.0 ROP 12705.5 13539.0 $ LOG HEADER DATA DATE LOGGED: 12-JUN-98 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 Ai~GLE: 51.9 MAXIMI/M ANGLE: 57.8 MSC 1.32 PCD 3.01 /SPC 5.74 MEMORY 13539.0 12705.5 13539.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 102 BOREHOLE A_ND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 4.750 4.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPER3tTURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Invert 10.40 50.0 9.6 1300 4.5 .000 .000 .000 .000 13.4 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .3 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 6 FT/H 4 1 68 4 2 GR MWD 6 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12642 13539 13090.5 1795 12642 ROP 6.96 680.86 86.2327 1668 12705.5 GR 42.19 199.26 122.048 1671 12642 Last Reading 13539 13539 13477 First Reading For Entire File .......... 12642 Last Reading For Entire File ........... 13539 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/06/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Reel Trailer Service name ............. LISTPE Date ..................... 98/06/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Scientific Physical EOF Physical EOF End Of LIS File