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200-077
Originated: Delivered to:19-Feb-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1A-20 50-029-22112-00 909816966 Kuparuk River Leak Detect Log Field- Final 23-Jan-25 0 12 1A-20 50-029-22112-00 909816966 Kuparuk River Multi Finger Caliper Field & Processed 22-Jan-25 0 13 1A-20 50-029-22112-00 909816966 Kuparuk River Plug Setting Record Field- Final 22-Jan-25 0 14 1D-38 50-029-22961-00 909594223 Kuparuk River Multi Finger Caliper Field & Processed 16-Jan-25 0 15 1E-17 50-029-20793-00 909817737 Kuparuk River Plug Setting Record Field- Final 4-Feb-25 0 16 1E-22 50-029-20884-00 909817740 Kuparuk River Multi Finger Caliper Field & Processed 2-Feb-25 0 17 1E-22 50-029-20884-00 909817740 Kuparuk River Plug Setting Record Field- Final 3-Feb-25 0 18 1H-01 50-029-22330-00 909817089 Kuparuk River Multi Finger Caliper Field & Processed 7-Feb-25 0 19 1H-01 50-029-22330-00 909817089 Kuparuk River Plug Setting Record Field- Final 7-Feb-25 0 110 1H-110 50-029-23601-00 909817451 Kuparuk River Plug Setting Record Field- Final 24-Jan-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40111T40111T40111T40112T40113T40114T40114T40115T40115T40116190-162200-077182-116182-214193-006218-0312/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.02.20 11:39:57 -09'00'1D-3850-029-22961-00 909594223Kuparuk RiverMulti Finger CaliperField & Processed16-Jan-2501T40112200-077 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, August 30, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-38 KUPARUK RIV UNIT 1D-38 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2024 1D-38 50-029-22961-00-00 200-077-0 W SPT 6235 2000770 3000 2450 2467 2467 2465 233 523 520 518 REQVAR P Kam StJohn 7/24/2024 MITIA to maximum anticipated injection pressure per AIO 2C.010 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 1D-38 Inspection Date: Tubing OA Packer Depth 1220 3320 3290 3290IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240724183026 BBL Pumped:3.1 BBL Returned:3.1 Friday, August 30, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 99 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.30 15:32:27 -08'00' Originated: Delivered to:29ͲNovͲ23 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & PerforatingAttn.:Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska99501 Anchorage, Alaska 99518 Office: 907Ͳ275Ͳ2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concernstotheattention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # 11CͲ22 50Ͳ029Ͳ23127Ͳ00 908965028 Kuparuk River Multi Finger Caliper Field & Processed 20ͲNovͲ23 0 1 21DͲ38 50Ͳ029Ͳ22961Ͳ00 908965029 Kuparuk River Multi Finger Caliper Field & Processed 21ͲNovͲ23 0 1 31JͲ107 50Ͳ029Ͳ23366Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 9ͲOctͲ23 0 1 41LͲ03A 50Ͳ029Ͳ21182Ͳ01 908347301 Kuparuk River Multi Finger Caliper Field & Processed 7ͲJanͲ23 0 1 52LͲ313 50Ͳ103Ͳ20277Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 26ͲNovͲ23 0 1 62MͲ24 50Ͳ103Ͳ20171Ͳ00 n/a Kuparuk River Patch Setting Record FieldͲFinal 21ͲDecͲ22 0 1 72PͲ415A 50Ͳ103Ͳ20383Ͳ01 n/a Kuparuk River Plug Setting Record FieldͲFinal 7ͲOctͲ23 0 1 82PͲ417 50Ͳ103Ͳ20375Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 6ͲOctͲ23 0 1 92PͲ420 50Ͳ103Ͳ20391Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 5ͲOctͲ23 0 1 10 2VͲ05 50Ͳ029Ͳ21051Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 19ͲJulͲ23 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 1. 1C-22 PTD:202-222 T38179 2.1D-38 PTD: 200-077 T38180 3. 1J-107 PTD: 207-107 T38181 4. 1L-03A PTD: 199-037 T38182 5. 2L-313 PTD: 198-219 T38183 6. 2M-24 PTD: 192-050 T38184 7. 2P-415A PTD: 201-226 T38185 8. 2P-417 PTD: 201-069 T38186 9. 2P-420 PTD: 201-182 T38187 10. 2V-05 PTD: 183-176 T38188 12/1/2023 21DͲ38 50Ͳ029Ͳ22961Ͳ00 908965029 Kuparuk River Multi Finger Caliper Field &Processed 21ͲNovͲ23 0 1 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 12:25:47 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 18, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-38 KUPARUK RIV UNIT 1D-38 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/18/2022 1D-38 50-029-22961-00-00 200-077-0 W SPT 6235 2000770 3000 2075 2079 2076 2075 257 642 634 629 REQVAR P Austin McLeod 7/13/2022 Two year to MAIP. AIO 2C.010. 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 1D-38 Inspection Date: Tubing OA Packer Depth 580 3310 3260 3255IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220714083738 BBL Pumped:3.9 BBL Returned:3.2 Thursday, August 18, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.18 15:11:59 -08'00' Wallace, Chris D (CED) From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Friday, January 15, 2021 7:24 AM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler Subject: RE: Kuparuk injector 1 D-38 (PTD# 200-077) Update 1/15/2021 Attachments: 1 D-38 90 day TIO trend 1.15.21.pdf; MIT KRU 1 D-38 diagnostic MITIA 12-20-20.xlsx Chris, Since the previous correspondence KRU 1D-38 (PTD 200-077) passed a diagnostic MITIA and was left with an elevated IA pressure for a monitor period. During the monitor period the IA pressure has remained stable and shown no signs of fall off. I am returning this well to 'normal' at this time. A 90 day TIO trend and MIT form are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophi11ips.com> Sent: Wednesday, December 16, 2020 2:59 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Well Integrity Compliance Specialist CPF1 & 2 <n1617 @conocophillips.com> Subject: Kuparuk injector 1D-38 (PTD# 200-077) Report of IA pressure fall off. Chris- Kuparuk injector 1D-38 (PTD# 200-077) was reported with an unexplainable IA pressure fall off. DHD will be scheduled to perform an initial set of diagnostic testing. If the initial set of diagnostic tests all pass, the well will be left with an elevated IA pressure and monitored for 30 days to verify integrity. Depending on the results of the tests and monitor period, the proper paperwork for continued injection or repair will be submitted. Attached is a copy of the well bore schematic and 90 day TIO plot. Please let me know if you have any questions or disagree with the plan. Cheers, Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM S Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPH & 2 <n1617@conocophillips.com> Sent: Wednesday, December 16, 2020 2:59 PM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler; Well Integrity Compliance Specialist CPH & 2 Subject: Kuparuk injector 1 D-38 (PTD# 200-077) Report of IA pressure fall off. Attachments: 1 D-38.pdf; 1 D-38 90 day TIO plot.pdf Chris- Kuparuk injector 1D-38 (PTD# 200-077) was reported with an unexplainable IA pressure fall off. DHD will be scheduled to perform an initial set of diagnostic testing. If the initial set of diagnostic tests all pass, the well will be left with an elevated IA pressure and monitored for 30 days to verify integrity. Depending on the results of the tests and monitor period, the proper paperwork for continued injection or repair will be submitted. Attached is a copy of the well bore schematic and 90 day TIO plot. Please let me know if you have any questions or disagree with the plan. Cheers, Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 0 WELLS TEAM [oroc.;Mmips MEMORANDUM TO: Jim Regg - ,,c, , P.I. Supervisor FROM: Matt Herrera Petroleum Inspector Well Name KUPARUK RIV UNIT 1D-38 IInsp Num: mitMFH2O0730130407 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 3, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. ID -38 KUPARUKRIV UNIT 1D-38 Src: Inspector Reviewed By: P.I. Supry !�/L Comm API Well Number 50-029-22961-00-00 Inspector Name: Matt Herrera Permit Number: 200-077-0 Inspection Date: 7/30/2020 Packer -- -1 Well ID -38 ',Type inj w'ITVD PTD 2000770 Type Test SPT 'Nest psi BBL Pumped: 4-5 _IBBL Returned: Interval I REQVAR p/j, 1 - I --— Notes: MITIA performed to MAIP per A10 2C.010 ;/ Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 6235 Tubing 1611 - 1621 - 1614 1613 1612 3000 IA 430 3320 3290 - 3250 3250 ' 4.5 OA 243 644 633 622 613 P Monday, August 3, 2020 Page 1 of 1 VZq 1J-36 P-)' zea?7o Regg, James B (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Wednesday, July 15, 2020 8:39 AM To: Regg, James B (CED); Wallace, Chris D (CED); Brooks, Phoebe L (CED); DOA AOGCC Prudhoe Bay Subject: KRU Non Witnessed MITIAs 7/13/20 Attachments: MIT KRU 2F PAD SI TESTS 07-13-20.xlsx; MIT KRU 1D-38 SI TEST 07-13-20-.xlsx 03 Attached are Non Witnessed MITIA's performed in Kuparuk 7/13/20. Please let me know if you have any questions. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 WELLS TEAM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.reccla'�alaska.aov: AOGCC.Insoectorsfojalaskaoov: phoebe.brooks0alaska.aov OPERATOR: ConocoPhillips Alaska Inc, FIELD / UNIT / PAD: Kuparuk / KRU / 1 D Pad DATE: 07/13/20 OPERATOR REP: VanCamp / Weimer AOGCC REP: 60 Min. chns.wallacetAalaska gov Vefq 7((Z1Arz-0 Well 1D-38 INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 4=Four Year Cycle F=Fail PTD 2000770 Type Inj N Tubing 200 .225 225 225 - N = Not Injecting Type Test P Packer TVD 6235 BBL Pump 4.6 IA 295 3300 3250 - 3230 Interval V Test psi 3000 BBL Return 4.5 OA 170 590 585 - 580 Result P Netes: MITIA to maximum anticipated injection pressure per AIO 2C.010 Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type Test BBLPump IA Interval BBL Return OA Result J Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type Test Packer TVD BBI- Pump IA Interval - Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min, 45 Min, 60 Min. PTD Type InjTubing Type Test Packer TVD BBI -Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Cotles INTERVAL Codes Result Codes W=water P=Pressure Test 1=Initial Test P=Pass G=Gas O= Other (describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V= Required by Valiance I - Inconclusive I = Industrial Wastewater O = Other describe in notes) N = Not Injecting Form 10-426 (Revised 01/2017) MIT KRU 1636 SI TEST 07-13-20- • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Begg -77 DATE: Wednesday,August 10,2016 P.I.Supervisor ' P1 t '(10(1 lu SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-38 FROM: Jeff Jones KUPARUK RIV UNIT 1D-38 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry -TEE— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1D-38 API Well Number 50-029-22961-00-00 Inspector Name: Jeff Jones Permit Number: 200-077-0 Inspection Date: 8/7/2016 Insp Num: mitJJ160809071600 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ID-38 - Type Inj W' TVD r 6235 . Tubing 2160 2130 - 2130 , 2150 - 2170 - PTD 2000770 - Type Test SPT Test psi 3000 - IA 582 3300 - 3210 - 3250 . 3250 Interval IR&QVAR P/F P `/I OA 215 584 'j 573 564 559 - Notes: 2 year MIT to max anticipated injection pressure required by AA AIO 2C.010. 1 well inspected,no exceptions noted. SINNED MAY 02 17 Wednesday,August 10,2016 Page 1 of 1 • zoo-O-7-1 WELL LOG TRANSMITTAL DATA LOGGED /14/2015 K BENDER To: Alaska Oil and Gas Conservation Comm. July 15, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 AU Resubmit E-Set# 25970 RE: Multi Finger Caliper(MFC) : 1D-38 Run Date: 6/4/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1D-38 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22961-00 N 5 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LE TIER TO THE ATI ENTION OF: Halliburton Wireline& Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: D�✓a�� u�, ( ���. zoo - oTl • • 2 s�--1 WELL LOG TRANSMITTAL DATA LOGGED Z/ /2015 K. BENDER To: Alaska Oil and Gas Conservation Comm. June 17, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 r) JUN 19 2U1!, RE: Multi Finger Caliper(MFC): 1D-38 °O4G Run Date: 6/4/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1D-38 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22961-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: Pjvaizet.~...4) Imag~ 'roject Well History File Cover ~ ,;le XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 077 Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL(~~INDY [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~WINDY Scanning Preparation BY: BEVERLY ROBIN VINCENT SHERYL~~/INDY DATE '~~.~/¢3 /S/ ~ Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: BY: Stage 2 BY: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: _~ YES BEVERL'(~~ VINCENT SHERYL MARIA WINDY DATE: 4¢--f1--~/ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES __ NO BEVERL'~VINCENT SHERYL MARIA WINDY DATE: ~.0--/~-~S/' '~"~"~ RESCANNEDB~': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: IS/ Quality Checked 12/10/02Rev3NOTScanned.wpd STATE OF ALASKA ALADA OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Farforations r Farforate f" Other E Alter Casing r Pull Tubing '"" Stimulate - Frac r Waiver E Time Extension r Change Approved Rogram r Operat. Shutdow n r Stimulate - Other jam' ti RFD Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 200 - 077 3. Address: 6. API Number: Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 50 - 029 - 22961 - og 7. Property Designation (Lease Number): 8. Well Name and Number.. ADL 25661, 25650 1 D - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 14324 feet Plugs (measured) None true vertical 6533 feet Junk (measured) None Effective Depth measured 14251 feet Packer (measured) 13465 true vertical 6506 feet (true vertical) 6235 Casing Length Size MD TVD Burst Collapse CONDUCTOR 114 20 148 148 SURFACE 7176 9.625 7210 427,7.4r- PRODUCTION 13597 7 13628 6291 RECEIVED LINER 861 3.5 14319 6531 OCT 0 5 201 Perforation depth: Measured depth: 13941'- 13968', 13959' - 14000' rpHNED JAN 2 3 2013 A 0000 True Vertical Depth: 6396'- 6405', 6402' -6416' 1 � Tubing (size, grade, MD, and TVD) 3.5, L -80, 13522 MD, 6255 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER ZXP LINER TOP PACKER @ 13465 MD and 6235 TVD SSSV - CAMCO TMAXX - 5E SSSV @ 2060 MD acid 2027 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 1394V- 14000' MD Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 0 2850 Subsequent to operation 1960 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development f"" Service P' - Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX � ` GSTOR WINJ r WAG p GINJ r SUSP r SPLUG r 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: none Contact John Peirce cad 265 -6471 Printed Name John Peirce Title Wells Engineer Signature j )/� Phone: 265 -6471 Date �D�p--��2 OCT 0 8 2012 ,�P/ I d/QC/1.2._ Form 10 -404 Revised 11/2011 g , II-- 0R1GINAL Submit Original Only 1 D -38 Well Work Summary DATE SUMMARY • • 9G5/12 PUMP 720 BBLS OF SLICK SEAWATER DOWN TBG 3 BPM @ 3500 PSI. TURNED WELL BACK OVER TO DSO FOR INJECTION AND NOTIFIED TO WATCH IA PRESSURE AS WELL WARMS BACK UP. JOB COMPLETE. PUMP REPORT IN ATTACHMENTS. 9/10/12 BRUSHED & FLUSHED TBG TO D NIPPLE @ 13450' RKB. COMPLETE. I KUP • 1 D -38 Conoc di Well Attributes Max Ang & MD TD Alaska Inc. Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB( • e 500292296100 KUPARUK RIVER UNIT INJ 74.29 5,151.28 14,324.0 "" Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date Well conn9: - to -3a, 1°raz°1 10 49 AM SSSV: LOCKED OUT Last WO: 12/6/2006 37.83 7/21/2000 Schematic Actul Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 13,969.0 6/18/2010 Rev Reason: HPBD ninam 10/3/2012 vi,., Casing Strings Casing Description String 0... String ID ... Top )ftKB) Set Depth (f... Set Depth )TVD) ... String Wt... String ... String Top Thrd HANGER, 31 CONDUCTOR 20 18.000 34.0 148.0 148.0 91.50 X52 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.181 33.9 7,209.7 4,276.5 40.00 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd PRODUCTION 7 6276 30.9 13,627.6 6,291.4 26.00 L - 80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String .. String Top Thrd oil I I 4' LINER 31/2 2.992 13,458.1 14,319.0 6,531.2 9.30 L-80 8RD EUE Liner Details Top Depth - (ND) Top Intl Nonni... . Top (ftKB) (ftKB) (1 Item Description Comment ID (in) 13,458.1 6,233.0 69.89 PBR BAKER PBR 4.000 CONDUCTOR. 13,464.7 6,235.3 69.89 PACKER BAKER ZXP LINER TOP PACKER 4.408 34 13,469.4 6,236.9 69.89 HANGER BAKER HMC LINER HANGER 4.400 13,478.9 6,240.1 69.88 SBE BAKER SEAL BORE EXTENSION 4.000 SAFETY VLV, 14,251.5 6,505.8 67.94 COLLAR 2.930 2.060 14,284.4 6,518.2 67.90 COLLAR 2.930 Tubing Strings Tubing Description String 0... String ID ...Top (ftKB) Set Depth (f... Set Depth )TVD)... String Wt... String ... String Top Thrd q, TUBING 3 1/2 2.992 30.9 I 13,5220 I 6,255.0 9.30 L -80 1 8RD EUE Mod ;;I Completion Details GAS LIFT Top Depth 2.520 (TVD) Top Inc! Nonni... GAS LIFT, Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 30.9 30.9 -0.16 HANGER FMC GEN Vi TUBING HANGER 2.992 2,060.3 2,026.6 25.42 SAFETY VLV CAMCO TMAXX -5E SSSV (LOCKED OUT 2/9/2011) 2.812 13,405.4 6,215.2 70.25 SLEEVE -C CMU Sliding Sleeve w/ 2.812" BX Profile 2.810 13,450.8 6,230.5 70.00 NIPPLE Camco D Nipple 2.750 7,011 13,487.2 6,243.0 69.88 LOCATOR BAKER LOCATOR SUB 2.970 13,490.4 6,244.1 69.87 SEAL ASSY Baker GBH22 Seal Assembly 3.000 Perforations & Slots i. - Shot Top (ND) Btm (ND) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (ah••• Type Comment 13,941 13,968 6,396.0 6,404.9 C-4, 10-38 1/27/2007 6.0 RPERF 2" HSD Guns PJ 2006, 60 deg phase SURFACE, 13,959 13,990 6,402.0 6,412.5 C-4, 1D-38 1/27/2007 6.0 RPERF 2" HSD Guns PJ 2006, 60 deg phase 34 13,970 14,000 6,405.6 6,415.9 C-4, 1D -38 5/3/2001 4.0 IPERF 2.5" HSD, DP 31J UJ F- Stimulations & Treatments I t Bottom SLEEVE -C, j i Min Top Max Btm Top Depth Depth 13,405 i Depth Depth (ND) (ND) (ftKB) (ftKB) (ftKB) (5KB) Type Date Comment 13,941.0 14,000.0 6,396.0 6,415.9 HPBD 9/5/2012 Notes: General & Safety End Date Annotation NIPPLE, 13,451 III 3/29/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 a . :I I: ,......_ LOCATOR, 13,487 SEAL ASSY, _ 13,490 PRODUCTION, All 31- 13,828 RPERF, 13,941 - 13,988 Mandrel Details HPBD, 13,941 Top Depth Top Port RPERF. (ND) Intl OD Valve Latch Size TRO Run 13,959-13,990 ---- Stn Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Type (04 (psi) Run Date Com... 13,970 -1ERF, 4.000 r 1 2,520.5 2,425.6 34.53 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 12/5/2006 e,: 2 7,010.7 4,212.7 71.59 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 12/23/2006 LINER, 13,458- 14,319 70,14,324 • III WELL LOG S TRANSMITTAL PRoAclivE Di/twos-Tic SeRviCES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MIT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C�Rgil It 43 Anchorage, AK 99518 Fax: (907) 245 -8952 1) Caliper Report 20- Feb-11 1D-38 1 Report / EDE 50-029 - 22961 -00 2) Caliper Report 23-Feb-11 1A-24 1 Report / EDE 50- 029 - 2298400 Q - // j09 / ,X) - o - 4' �o ? RECEIVED Signed : Date : MAR a. 12 a) Print Name: Anchorage PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99618 PHONE: (907)245 -8951 FAX: (907)245 -88952 E-awL : gdsanchorage(aamemorvioq.com WEBSITE : WWw.memonfloo.com . C:1Documents and Settings\Disne Williams \Desktop1Tr isnnt_Conoco.docx I • • I 1116 Multi - Finger Caliper � • � Log Results Summary I Company: ConocoPhillips Alaska, Inc. Well: 1D-38 Log Date: February 20, 2011 Field: Kuparuk Log No.: 10258381 ZX70 State: Alaska I Run No.: 1 API No.: 50- 029 - 22961 -00 Pipet Desc.: 3.5" 9.3 lb. L -80 Top Log Intvl: Surface Pipet Use: Tubing Bot. Log Intvl: 13,504 Ft. (MD) I Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : I This caliper data is correlated to the Well Schematic. This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. I The caliper recordings indicate the majority of the 3.5" tubing logged appears to be in fair to poor condition. Wall penetrations ranging from 40% to 68% wall thickness are recorded in 139 of the 440 joints logged, and cross - sectional wall loss ranging from 15% to 17% wall thickness are recorded in 37 of the 440 joints logged. Recorded damage appears as apparent erosion from surface to —2,500', with a line of pits broadening into I line corrosion and general corrosion from —850' to 13,504' (end of log). No significant I.D. restrictions are recorded throughout the tubing logged. I This summary report is interpretation of data provided by Halliburton Well Services. MAXIMUM RECORDED WALL PENETRATIONS : Line of Pits / Apparent Erosion ( 68 %) Jt. 74 @ 2,385 Ft. (MD) I Line of Pits ( 65%) Jt. 81 @ 2,633 Ft. (MD) Line of Pits / Apparent Erosion ( 65%) Jt. 76 @ 2,440 Ft. (MD) Line of Pits / Apparent Erosion ( 65 %) Jt. 67 @ 2,151 Ft. (MD) I Line of Pits / Apparent Erosion ( 65 %) Jt. 64.1 @ 2,063 Ft. (MD) MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS Line of Pits / Apparent Erosion ( 17 %) Jt. 67 @ 2,160 Ft. (MD) I Line of Pits / Apparent Erosion ( 17%) Jt. 71 @ 2,293 Ft. (MD) Line of Pits / Apparent Erosion ( 17%) Jt. 74 @ 2,385 Ft. (MD) Line of Pits / Apparent Erosion ( 17 %) Jt. 59 @ 1,880 Ft. (MD) I Line of Pits / Apparent Erosion ( 17 %) Jt. 48 @ 1,547 Ft. (MD) MAXIMUM RECORDED ID RESTRICTIONS : I No significant I.D. restrictions are recorded throughout the tubing logged. I I II Field Engineer: J. Conrad Analyst: C. Lucasan Witness: B. Boehme ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX. 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS©memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 006 -0-9--'-+ g I • • Correlation of Recorded Damage to Borehole Profile I ■ Pipe 1 3.5 in (37.1' - 13504.2') Well: 1D-38 Field: Kuparuk I Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: February 20, 2011 I 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 ■ _ — 40 I _ 50 1590 GLM 1 I 100 3199 I 150 4755 0 I v 200 6316 ,i GLM2 -7 s ir- 250 �_ 7907 I 30O 9468 I 350 1 _ 400 12586 I ,_ 427.2 13504 I 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) I Bottom of Survey = 427.2 I I • • I dl PDS Report Overview - Body Region Analysis I Well: 1 D -38 Survey Date: February 20, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 10000428 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf L -80 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration(% wall) Da mage Profile (% wall) 300 — ^!+ . t ±s4 Penetration b ody Metal loss body 250 — 0 0 50 100 I 200 150 _ -- I 100 47 • S0= _- _ GLM 1 0 93 - I 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 440) 143 I 8 293 139 0 193 I Damage Configuration ( body) GLM 2 241 300 ____ I 200 _ 291 150 I 100 I 50 -- 341 ,,.- 0 I Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole 391 I Number of joints damaged (total = 439) 104 280 30 25 0 Bottom of Survey = 427.2 I I I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L-80 Well: 1 D -38 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: February 20, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 37 0.04 0.04 14 8 3.00 Pup Shallow Apparent Erosion. 1 40 0.06 0.05 20 11 2.99 Shallow Apparent Erosion. 1.1 71 0.04 0.04 17 11 2.98 Pup ., 1.2 75 0.05 0.04 16 10 2.96 Pup Shallow Apparent Erosion. c I 1.3 86 0 0.05 18 12 2.98 Pup Shallow Apparent Erosion. II- I 2 96 0.06 0.06 24 12 3.00 Apparent Erosion. E 3 127 0.05 0.06 22 11 2.99 Apparent Erosion. ti. 4 158 0.05 0.05 19 11 3.00 Shallow Apparent Erosion. r 5 189 0.06 0.06 23 12 2.98 Apparent Erosion. L I 6 220 0.05 0.05 21 11 2.99 Apparent Erosion. 7 251 0.06 0.05 20 10 2.98 Shallow Apparent Erosion. t. 8 283 0.04 0.05 20 8 2.99 Shallow Apparent Erosion. t. 9 314 0.04 0.06 23 10 2.99 Apparent Erosion. 4 I 10 344 0.05 0.06 22 11 3.00 Apparent Erosion. 11 375 0.05 0.05 21 10 2.99 Apparent Erosion. ti 12 407 0.05 0.06 22 12 2.99 Apparent Erosion. E- 13 438 0.05 0.05 19 9 2.98 Shallow Apparent Erosion. ET 14 469 0.04 0.05 19 10 2.99 Shallow Apparent Erosion. u I 15 500 0.04 0.05 20 9 3.00 Shallow Apparent Erosion. 16 531 0.04 0.06 24 8 2.98 Isolated Pitting. Apparent Erosion. c 17 563 0.04 0.04 17 10 2.98 Shallow Apparent Erosion. L 18 594 0.06 0.07 26 9 2.99 Isolated Pitting. Apparent Erosion. I 19 625 0.05 0.06 24 11 2.98 Isolated Pitting. Apparent Erosion. 20 656 0.04 0.05 20 10 3.00 Shallow Apparent Erosion. 21 687 0.04 0.07 26 9 3.00 Isolated Pitting. Apparent Erosion. 22 718 0.06 0.05 21 11 3.00 Apparent Erosion. iii I 23 749 0.05 0.10 39 9 3.00 Isolated Pitting. Apparent Erosion. 24 780 0.05 0.07 26 11 3.00 Isolated Pitting. Apparent Erosion. 25 811 0.04 0.07 30 10 2.99 Isolated Pitting. Apparent Erosion. 26 842 0.05 0.05 20 11 2.99 Shallow Apparent Erosion. 27 873 0.05 0.10 40 12 2.99 Apparent Erosion. I 28 904 0.05 0.06 25 13 2.97 Apparent Erosion. 29 936 0.06 0.07 28 13 3.00 A..arent Erosion. 30 967 0.08 0.11 43 14 3.00 Line of Pits. Apparent Erosion. 31 998 0.06 0.11 44 14 2.98 Line of Pits. Apparent Erosion. C I 32 1029 0.06 0.12 47 13 2.99 Line of Pits. Apparent Erosion. 33 1061 0.06 0.10 40 11 2.97 Line of Pits. Apparent Erosion. I '_ 34 1092 0.06 0.13 51 13 2.99 Line of Pits. Apparent Erosion. 35 1123 0.07 0.09 37 15 2.99 Line of Pits. Apparent Erosion. I 36 1154 0.07 0.08 33 12 2.99 Line of Pits. Apparent Erosion. 37 1186 0.05 0.10 40 10 2.98 Line of Pits. Apparent Erosion. 38 1217 0.07 0.11 44 13 3.01 Line of Pits. Apparent Erosion. 39 1248 0.07 0.11 42 15 3.00 Line of Pits. Apparent Erosion. I 40 1279 0.08 0.12 46 11 3.00 Line of Pits. Apparent Erosion. 41 1310 0.07 0.11 44 11 2.97 Line of Pits. Apparent Erosion. 42 1342 0.06 0.14 54 13 2.99 Line of Pits. Apparent Erosion. 43 1373 0.08 0.11 44 15 2.99 Line of Pits. Apparent Erosion. 44 1404 0.09 0.12 46 13 3.00 Line of Pits. Apparent Erosion. I 45 1436 0.06 0.16 61 16 3.00 Line of Pits. Apparent Erosion. 46 1467 0.06 0.12 47 13 3.00 Line of Pits. Apparent Erosion. I I Penetration Body I Metal Loss Body Page 1 I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L-80 Well: 1 D-38 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 20, 2011 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 47 1498 0.08 0.12 47 14 3.01 Line of Pits. Apparent Erosion. 48 1529 0.07 0.10 39 17 3.01 Line of Pits. Apparent Erosion. ■� ��' 49 1560 0.10 0.14 54 15 2.98 Line of Pits. Apparent Erosion. ■om 50 1590 0.07 0.15 60 15 3.00 Line of Pits. Apparent Erosion. nom I 51 1621 0.07 0.15 59 15 2.99 Line of Pits. Apparent Erosion. mom 52 1653 0.12 0.13 52 17 2.98 Line of Pits. Apparent Erosion. 53 1684 0.07 0.17 65 15 3.00 Line of Pits. Apparent Erosion. I' 54 1715 0.07 0.15 59 16 3.00 Line of Pits. Apparent Erosion. 55 1746 0.08 0.17 65 15 2.98 Line of Pits. Apparent Erosion. ill 56 1778 0.10 0.14 57 16 3.00 Line of Pits. Apparent Erosion. 57 1809 0.07 0.14 56 15 3.00 Line of Pits. Apparent Erosion. R.. 58 1840 0.07 0.13 52 15 2.96 Line of Pits. Apparent Erosion. 59 1871 0.07 0.15 59 17 3.00 Line of Pits. Apparent Erosion. E' I 60 1902 0.13 0.14 57 , 15 3.00 Line of Pits. Apparent Erosion. 61 1933 0.08 0.13 51 13 2.98 Line of Pits. Apparent Erosion. 62 1963 0.08 0.14 56 15 2.99 Line of Pits. Apparent Erosion. ii 63 1994 0.08 0.11 44 11 2.97 Line of Pits. Apparent Erosion. I 64 2026 0.10 0.13 50 15 3.00 Line of Pits. Apparent Erosion. 64.1 2057 0.13 0.17 65 11 2.98 Pup Line of Pits. Apparent Erosion. 64.2 2066 0 0 0 0 2.81 Camco TMAXX -5E SSSV 64.3 2070 0.05 0.12 47 13 2.98 Pup Line of Pits. Apparent Erosion. 65 2079 0.07 0.13 52 16 3.00 Line of Pits. Apparent Erosion. I 66 2110 0.07 0.13 50 16 2.99 Line of Pits. Apparent Erosion. 67 2141 0.07 0.17 65 17 2.99 Line of Pits. Apparent Erosion. 68 2173 0.14 0.16 63 15 2.99 Line of Pits. Apparent Erosion. I . 69 2204 0.10 0.13 52 10 2.98 Line of Pits. Apparent Erosion. ®' I 70 2235 0.04 0.15 58 17 3.00 Line of Pits. Apparent Erosion. 71 2267 0.06 0.16 63 17 3.00 Line of Pits. Apparent Erosion. 72 2298 0.08 0.16 63 17 2.97 Line of Pits. Apparent Erosion. 73 2329 0.12 0.16 63 15 2.99 Line of Pits. Apparent Erosion. I 74 2360 0.05 0.17 69 17 3.00 Line of Pits. Apparent Erosion. 75 2392 0.09 0.14 55 15 3.00 Line of Pits. Apparent Erosion. 76 2423 0.09 0.17 65 15 2.99 Line of Pits. Apparent Erosion. 77 2453 0.05 0.14 54 14 2.99 Line of Pits. Apparent Erosion. 78 2485 0.09 0.14 56 13 2.99 Line of Pits. Apparent Erosion. I 78.1 2516 0.03 0.13 51 12 2.98 Pup Line of Pits. Apparent Erosion. 78.2 2526 0 0 0 0 2.90 GLM 1 (Latch @ 6:00) 78.3 2533 0.12 0.12 47 9 2.97 Pup Line of Pits. 79 2544 0.10 0.14 56 12 2.96 Line of Pits. I 80 2575 0.08 0.13 49 14 2.99 Line of Pits. 81 2606 0.11 0.17 65 15 2.99 Line of Pits. 82 2636 0.10 0.16 63 14 2.99 Line of Pits. 83 2667 0.09 0.13 52 13 3.00 Line of Pits. tom I 84 2699 0.06 0.14 55 15 3.00 Line of Pits. �� 85 2730 0.10 0.15 59 13 2.97 Line of Pits. 86 2761 0.06 0.13 51 13 3.00 Line of Pits. NI 87 2792 0.08 0.13 50 13 2.97 Line of Pits. Is 1 88 2823 0.11 0.14 54 12 2.98 Line of Pits. I 89 2855 0.13 0.11 44 12 2.98 Line of Pits. kw 3 90 2886 0.05 0.14 55 13 2.97 Line of Pits. 1 Body Metal Penetration Loss Body Page 2 1 I I • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L-80 Well: 1 D-38 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: February 20, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (' wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 91 2917 0.05 0.12 47 12 2.98 Line of Pits. 92 2948 0.09 0.14 56 12 3.00 Line of Pits. 93 2980 0.12 0.12 47 13 2.99 Line of Pits. v 94 3011 0.10 0.13 49 12 2.99 Line of Pits. F 95 3042 0.08 0.12 48 12 2.98 Line of Pits. F 1 96 3074 0.10 0.12 46 12 2.96 Line of Pits. 97 3105 0.04 0.13 50 12 2.96 Line of Pits. v 98 3136 0.08 0.13 51 13 3.00 Line of Pits. 0 99 3168 0.06 0.13 50 13 2.97 Line of Pits. K _ I 100 3199 0.08 0.11 42 13 2.97 Line of Pits. 101 3230 0.08 0.15 58 12 2.97 Line of Pits. 102 3262 0.09 0.12 48 12 2.97 Line of Pits. 103 3293 0.06 0.11 43 13 2.99 Line of Pits. I 104 3324 0.08 0.10 39 11 2.96 Line of Pits. 105 3356 0.10 0.14 54 13 2.99 Line of Pits. 106 3387 0.12 0.12 48 11 2.98 Line of Pits. 0 107 3418 0.08 0.10 40 10 2.98 Line of Pits. (It 108 3447 0.07 0.12 46 12 2.99 Line of Pits. 0 I 109 3478 0.07 0.09 36 13 2.99 Line of Pits. 110 3510 0.04 0.13 52 13 2.99 Line of Pits. 111 3541 0.10 0.13 53 15 2.99 Line of Pits. 112 3572 0.07 0.10 40 13 2.99 Line of Pits. I 113 3603 0.07 0.12 47 12 2.97 Line of Pits. 114 3634 0.11 0.10 40 13 2.99 Line of Pits. 115 3666 0.09 0.13 52 14 2.99 Line of Pits. 116 3697 0.07 0.13 49 ; . 2.96 Line of Pits. I 117 3728 0.10 0.12 47 13 2.96 Line of Pits. 118 3759 0.08 0.14 54 14 2.99 Line of Pits. 119 3790 0.06 0.08 33 14 2.99 Line Corrosion. 120 3822 0.11 0.13 51 13 2.97 Line Corrosion. I 121 3853 0.10 0.14 56 15 3.00 Line Corrosion. 122 3884 0.07 0.11 44 12 2.98 Line Corrosion. 123 3915 0.09 0.11 42 14 2.98 Line Corrosion. 124 3945 0.07 0.09 37 13 2.99 Line Corrosion. 125 3977 0.08 0.09 37 11 2.98 Line Corrosion. I 126 4008 0.07 0.10 40 13 3.00 Line Corrosion. 127 4039 0.09 0.14 55 13 2.99 Line Corrosion. 128 4070 0.10 0.11 43 12 2.98 Line Corrosion. 129 4102 0.10 0.10 39 14 3.00 Line Corrosion. I 130 4133 0.09 0.12 47 12 2.97 Line Corrosion. 131 4163 0.07 0.14 55 14 2.99 Line Corrosion. 132 4195 0.11 0.15 59 12 2.98 Line Corrosion. 133 4226 0.10 0.11 44 14 2.99 Line Corrosion. I 134 4258 0.09 0.11 42 10 2.97 Line Corrosion. 135 4289 0.09 0.11 44 14 2.97 Line Corrosion. 136 4320 0.08 0.12 47 12 2.97 Line Corrosion. °s' 137 4351 0.10 0.12 47 13 2.98 Line Corrosion. j 111M111 138 4383 0.11 0.14 54 11 2.96 Line Corrosion. NM I 139 4413 0.05 0.11 43 14 3.00 Line Corrosion. 140 4443 0.09 0.14 54 13 2.96 Line Corrosion. 1 MIMI tion II Metal Loss Body Page 3 Penetra 1 I I • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 1 D -38 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 20, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % I cuss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 141 4474 0.07 0.12 46 12 2.97 Line Corrosion. ■■ 142 4506 0.08 0.12 46 13 2.97 Line Corrosion. woo 143 4537 0.07 0.12 46 13 2.98 Line Corrosion. ■■ 144 4568 0.11 0.13 52 12 2.97 Line Corrosion. ■■ 145 4599 0.09 0.12 46 13 2.96 Line Corrosion. ■■ I 146 4630 0.11 0.12 47 13 2.99 Line Corrosion. ■■ 147 4662 0.10 0.15 58 13 3.00 Line Corrosion. ■■ 148 4693 0.11 0.11 42 13 3.00 Line Corrosion. ■■ 149 4724 0.11 0.12 45 12 2.96 Corrosion. ■■ ' 150 4755 0.12 0.11 43 12 2.97 Corrosion. ■■ 151 4786 0.10 0.12 46 13 2.97 Corrosion. ■■ 152 4817 0.09 0.13 51 14 2.99 Corrosion. ■■ 153 4848 0.11 0.12 47 15 2.99 Corrosion. ■■ I 154 4879 0.08 0.13 50 12 3.00 Corrosion. ■■ 155 4910 0.08 0.14 56 13 2.96 Corrosion. woo 156 4942 0.10 0.10 39 15 3.00 Corrosion. ■■ 157 4973 0.10 0.10 39 13 3.00 Corrosion. ■M I 158 5004 0.08 0.11 44 12 2.98 Corrosion. ■■ 159 5035 0.10 0.12 47 14 3.00 Corrosion. ■■ 160 5066 0.09 0.10 39 13 2.97 Corrosion. ■■ 161 5097 0.11 0.09 37 12 2.99 Corrosion. ■■ 162 5129 0.08 0.09 35 12 2.98 Corrosion. ■■ I 163 5160 0.08 , 0.10 39 10 2.97 Corrosion. Nom 5191 0.07 0.09 35 13 2.98 Corrosion. ■■ 165 5223 0.08 0.09 37 13 2.97 Corrosion. ■■ 166 5254 0.07 0.09 37 13 2.95 Corrosion. ■■ I 167 5285 0.06 0.10 39 13 2.99 Corrosion. ism 168 5316 0.07 0.11 42 10 2.98 Corrosion. ■■ 169 5347 0.06 0.09 35 14 2.98 Corrosion. ■■ 170 5378 0.08 0.10 39 15 2.97 Corrosion. ■■ I 171 5410 0.09 0.11 42 12 2.99 Corrosion. moo 5441 0.09 0.11 42 14 2.99 Corrosion. ■■ 173 5472 0.06 0.10 39 12 2.96 Corrosion. ■■ 174 5504 0.07 0.09 36 13 2.98 Corrosion. ■■ 175 5535 0.08 0.11 42 14 2.97 Corrosion. ■■ I 176 5566 0.08 0.11 43 12 2.97 Corrosion. moo 177 5597 0.08 0.08 31 13 2.99 Corrosion. ■■ 178 5628 0.08 0.09 35 11 2.97 Corrosion. ■■ 179 5659 0.07 0.12 48 12 2.96 Corrosion. ■■ I 180 5691 0.08 0.09 35 13 2.98 Corrosion. woo 5722 0.08 0.09 37 12 2.98 Corrosion. ■■ 182 5753 0.06 0.09 37 13 2.97 Corrosion. ■■ 183 5785 0.07 0.09 35 13 2.96 Corrosion. ■■ I 184 5816 0.06 0.09 35 9 2.95 Corrosion. ■ 185 5847 0.06 0.08 30 11 2.97 Corrosion. ■� 186 5879 0.07 0.08 31 11 2.97 Corrosion. ■■ 187 5910 0.08 0.09 37 12 2.95 Corrosion. ■■ I 188 5941 0.08 0.08 31 12 2.95 Corrosion. moo 189 5972 0.07 0.09 35 13 2.98 Corrosion. ■■ 190 6003 0.06 0.10 39 11 2.98 Corrosion. I Penetration Body I Metal Loss Body Page 4 1 I I • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 1D-38 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 20, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 191 6034 0.08 0.09 35 14 2.98 Corrosion. 6066 0.08 0.09 35 12 2.97 Corrosion. mo 193 6097 0.07 0.09 35 12 2.95 Corrosion. mil 194 6128 0.07 0.09 35 12 2.96 Corrosion. 195 6159 0.07 0.09 35 12 2.94 Corrosion. I 196 6191 0.06 0.08 33 13 2.98 Corrosion. 197 6222 0.06 0.07 30 13 3.00 Corrosion. i. 198 6253 0.05 0.07 29 10 2.95 Corrosion. 199 6284 0.07 _ 0.08 33 13 2.99 Corrosion. 1 200 6316 0.07 0.08 33 12 2.97 Corrosion. 201 6347 0.07 0.10 38 13 2.98 Corrosion. 202 6378 0.06 0.08 33 11 2.98 Corrosion. 203 6409 0.07 0.10 39 11 2.96 Corrosion. I 204 6441 0.07 0.09 35 13 2.97 Corrosion. 205 6472 0.08 0.08 33 12 2.98 Corrosion. 206 6503 0.07 0.07 26 11 2.96 Corrosion. i 207 6535 0.07 0.08 31 11 2.96 Corrosion. 208 6566 0.07 0.08 31 11 2.97 Corrosion. I 209 6597 0.07 0.08 31 10 2.98 Corrosion. 210 6629 0.06 0.09 37 12 2.98 Corrosion. A i 211 6660 0.07 0.08 33 13 2.97 Corrosion. 212 6692 0.05 0.08 33 11 2.98 Corrosion. I 213 6722 0.06 0.10 39 12 2.98 Corrosion. 214 6753 0.06 0.08 33 12 2.96 Corrosion. 215 6785 0.07 0.09 35 11 2.97 Corrosion. . 216 6816 0.06 0.07 30 10 2.97 Corrosion. t I 217 6847 0.06 0.09 37 11 2.99 Corrosion. 218 6879 0.05 0.10 39 11 2.97 Corrosion. �� 219 6910 0.07 0.08 31 10 2.95 Corrosion. 220 6941 0.07 0.08 33 11 2.95 Corrosion. I I 221 6973 0.05 0.07 30 10 2.96 Corrosion. 221.1 7004 0.06 0.08 33 11 2.98 Pup Corrosion. di 221.2 7014 0 0 0 0 2.91 GLM 2 (Latch @ 8:30) I 221.3 7021 0.07 0.08 31 9 2.97 Pup Corrosion. I 222 7031 0.06 0.09 35 12 2.98 Corrosion. IN 223 7061 0.06 0.08 33 12 2.96 Corrosion. 224 7094 0.08 0.07 30 13 2.97 Corrosion. r 225 7124 0.06 0.10 39 12 2.97 Corrosion. a 226 7156 0.07 0.11 42 12 2.98 Corrosion. I 227 7186 0.07 0.09 37 13 2.98 Corrosion. 228 7219 0.06 0.11 44 13 2.98 Corrosion. 229 7250 0.06 0.12. 47 13 2.99 Corrosion. i 230 7281 0.07 0.08 31 11 2.98 Corrosion. I 231 7312 0.06 0.07 30 12 2.98 Corrosion. 232 7344 0.07 0.08 33 11 2.98 Corrosion. NE 233 7375 0.10 0.10 39 11 2.97 Corrosion. NE 234 7407 0.07 0.11 42 12 2.98 Corrosion. no 235 7437 0.05 0.07 30 11 2.98 Corrosion. MN I 236 7469 0.06 0.08 31 11 2.97 Corrosion. MI 237 7500 0.06 0.09 35 11 2.99 Corrosion. I Metal Loss Body Page 5 Penetration 1 I I • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 1 D -38 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 20, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 238 7531 0.07 0.09 37 11 2.96 Corrosion. �� 239 7563 0.05 0.09 35 12 2.98 Corrosion. E: 240 7594 0.04 0.08 30 11 2.95 Corrosion. 241 7626 0.06 0.08 31 11 2.98 Corrosion. ow 242 7657 0.06 0.08 33 12 2.99 Corrosion. EN 1 243 7688 0.05 , 0.07 30 13 2.97 Corrosion. E1E 244 7719 0.07 0.08 33 12 2.98 Corrosion. Imo 245 7751 0.06 0.10 39 12 2.95 Corrosion. EN 246 7782 0.06 0.10 40 11 2.97 Corrosion. NE I 247 7813 0.07 0.08 33 11 2.97 Corrosion. �� 248 7844 0.07 0.08 31 11 2.96 Corrosion. En 249 7876 0.06 0.09 35 12 2.97 Corrosion. N 250 7907 0.07 0.08 33 12 2.98 Corrosion. MN I 251 7938 0.07 0.08 31 11 2.97 Corrosion. �� 252 7970 0.05 0.07 30 9 2.96 Corrosion. No 8000 0.04 0.08 31 11 2.95 Corrosion. EN 254 8032 0.07 0.09 36 11 2.97 Corrosion. INN I 255 8063 0.06 0.09 35 9 2.96 Corrosion. IN . 256 8094 0.06 0.08 30 9 2.96 Corrosion. 257 8125 0.05 0.07 28 9 2.96 Corrosion. EI: 258 8156 0.05 0.09 36 11 2.98 Corrosion. No 259 8188 0.06 0.11 42 13 2.96 Corrosion. EN I 260 8220 0.07 0.08 31 10 2.97 Corrosion. EN 261 8250 0.05 0.08 31 11 2.99 Corrosion. EN 262 8282 0.07 0.08 33 8 2.96 Corrosion. Nu 263 8313 0.00 0.09 35 10 2.98 Corrosion. NM I 264 8344 0.06 0.09 35 10 2.98 Corrosion. �� 265 8376 0.06 0.07 30 10 2.96 Corrosion. 266 8407 0.05 0.08 31 10 2.94 Corrosion. NIE 267 8438 0.06 0.08 31 10 2.97 Corrosion. am I 268 8469 0.05 0.07 30 8 2.96 Corrosion. ENE 8500 0.05 0.08 31 10 2.97 Corrosion. -- 270 8532 0.07 0.08 31 9 2.94 Corrosion. En 271 8563 0.06 0.08 33 10 2.98 Corrosion. ma I 272 8593 0.04 0.08 33 11 2.97 Corrosion. NI 273 8625 0.05 0.07 30 9 2.97 Corrosion. 274 8656 0.07 0.07 26 10 2.97 Corrosion. � 275 8687 0.0.5 0.07 26 10 2.98 Corrosion. on 276 8718 0.05 0.07 30 8 2.97 Corrosion. ma I 277 8750 0.06 0.08 33 9 2.98 Corrosion. 278 8781 0.05 0.07 28 8 2.97 Corrosion. in Ei 279 8812 0.04 0.07 30 7 2.96 Corrosion. � 280 8843 0.05 0.07 30 9 2.98 Corrosion. so I 281 8875 0.05 0.07 28 9 2.94 Corrosion. IN 282 8905 0.05 0.07 26 9 2.96 Corrosion. 283 8937 0.06 0.07 26 9 2.98 Corrosion. N 284 8968 0.06 0.07 28 9 2.97 Corrosion. I 285 8999 0.04 0.06 24 8 2.96 Corrosion. IN 286 9030 0.05 0.07 26 lU 2.96 Corrosion. 287 9061 0.05 0.07 28 0 2.96 Corrosion. el I Metal Loss Body I Page 6 Penetration I I 0 . PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 1 D -38 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: February 20, 2011 I Joint it. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 288 9092 0.06 0.07 28 10 2.97 Corrosion. 289 9124 0.06 0.07 28 9 2.97 Corrosion. ■ IN 290 9155 0.06 0.07 30 11 2.98 Corrosion. in 9186 0.06 0.07 26 7 2.96 Corrosion. in 292 9218 0.05 0.07 30 9 2.96 Corrosion. NI I 293 9249 0.08 0.07 26 10 2.98 Corrosion. IN 294 9280 0.05 0.07 28 8 2.95 Corrosion. �IN 295 9311 0.04 0.08 31 9 2.93 Corrosion. Lt. Deposits. IN 296 9343 0.05 0.08 33 10 2.95 Corrosion. Is I 297 9374 0.06 0.07 26 7 2.97 Corrosion. �� 298 9405 0.05 0.07 28 10 2.96 Corrosion. N 299 9437 0.06 0.07 28 8 2.96 Corrosion. mu 300 9468 0.06 0.07 30 9 2.93 Corrosion. a I 301 9500 0.06 0.07 28 8 2.96 Corrosion. i� 302 9531 0.05 0.08 31 9 2.96 Corrosion. NI 303 9562 0.06 0.07 30 10 2.98 Corrosion. a 304 9592 0.06 0.08 31 9 2.92 Corrosion. Lt. Deposits. oi I 305 9623 0.06 0.08 33 9 2.95 Corrosion. im 306 9654 0.06 0.08 31 10 2.98 Corrosion. NI 307 9686 0.06 0.08 31 9 2.96 Corrosion. 308 9717 0.06 0.06 24 8 2.97 Corrosion. imi 309 9748 0.04 0.07 28 9 2.96 Corrosion. NI ' 310 9780 0.07 0.07 28 10 2.95 Corrosion. 311 9811 0.05 0.08 31 9 2.97 Corrosion. m 312 9842 0.06 0.07 30 9 2.95 Corrosion. lo 313 9873 0.04 0.07 28 10 2.96 Corrosion. ■ I 314 9905 0.06 0.07 28 7 2.97 Corrosion. r. 315 9935 0.05 0.07 30 9 2.96 Corrosion. in 316 9967 0.05 0.07 28 10 2.95 Corrosion. iim 317 9998 0.07 0.07 26 9 2.96 Corrosion. NI I 318 10029 0.07 0.07 30 9 2.96 Corrosion. 319 10060 0.06 0.07 30 10 2.95 Corrosion. is 320 10092 0.07 0.07 26 10 2.97 Corrosion. IN ill 321 10123 0.06 0.06 24 7 2.96 Corrosion. no 322 10154 0.05 0.07 26 6 2.94 Corrosion. IN I 323 10185 0.05 0.07 26 7 2.97 Corrosion. IN 324 10217 0.05 0.08 33 10 2.97 Corrosion. N 325 10248 0.05 0.07 28 9 2.96 Corrosion. mi 326 10279 0.05 0.07 28 8 2.98 Corrosion. ini 1 327 10310 0.05 0.06 24 9 2.93 Corrosion. 328 10342 0.05 0.06 24 7 2.94 Corrosion. IN IN 329 10373 0.04 0.07 26 8 2.96 Corrosion. �IN 330 10404 0.04 0.06 25 9 2.95 Corrosion. IN I 331 10436 0.04 0.07 26 9 2.95 , Corrosion. ow 10467 0.05 0.07 30 8 2.96 Corrosion. um 333 10498 0.04 0.07 26 6 2.94 Corrosion. no 334 10528 0.06 0.07 30 9 2.97 Corrosion. a 335 10558 0.04 0.07 30 9 2.96 Corrosion. IN I 336 10590 0.05 0.07 28 8 2.96 Corrosion. imi 337 10621 0.04 0.06 24 7 2.94 Corrosion. I Penet1t0n ' Metal at ss Body Page 7 I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 1D-38 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 20, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 338 10651 0.07 0.07 30 6 2.94 Corrosion. u■ 339 10683 0.04 0.09 36 9 2.96 Corrosion. IN 340 10714 0.07 0.08 31 8 2.96 Corrosion. i■ 341 10745 0.06 0.07 28 9 2.94 Corrosion. i■ I 342 10776 0.05 0.06 24 9 2.95 Corrosion. ■ 343 10807 0.04 0.08 33 8 2.96 Corrosion. i■ 344 10838 0.06 0.11 42 10 2.97 Corrosion. IN 345 10869 0.06 0.10 38 8 2.96 Corrosion. i■ 346 10901 0.05 0.09 36 8 2.97 Corrosion. in 347 10931 0.07 0.08 33 8 2.96 Corrosion. is 348 10963 0.05 0.07 28 8 2.94 Corrosion. i■ 349 10995 0.07 0.07 30 9 2.96 Corrosion. IN 350 11026 0.07 0.07 30 8 2.92 Corrosion. Lt. Deposits. I■ I 351 11057 0.06 0.09 35 8 2.96 Corrosion. �■ 352 11088 0.07 0.09 34 8 2.95 Corrosion. I■ 353 11119 0.04 0.07 26 7 2.96 Corrosion. H■ 354 11151 0.05 0.08 31 8 2.96 Corrosion. 1■ I 355 11182 0.06 0.08 31 7 2.96 Corrosion. r■ 356 11213 0.05 0.08 33 7 2.95 Corrosion. I■ 357 11245 0.06 0.08 33 8 2.96 Corrosion. I■ 358 11276 0.04 0.06 25 9 2.96 Corrosion. • 359 11307 0.05 0.07 28 7 2.94 Corrosion. 11111 I 360 11338 0.05 0.07 28 6 2.92 Corrosion. im 361 11369 0.06 0.07 28 6 2.95 Corrosion. i■ 362 11400 0.05 0.09 36 7 2.97 Corrosion. r■ 363 11431 0.07 0.08 31 7 2.96 Corrosion. IN I 364 11462 0.05 0.09 35 7 2.95 Corrosion. �■ 365 11493 0.05 0.07 30 8 2.96 Corrosion. IN 366 11524 0.06 0.07 28 7 2.97 Corrosion. I. 367 11555 0.04 0.08 31 7 2.96 Corrosion. mii I 368 11586 0.07 0.07 26 7 2.95 Corrosion. �■ 369 11618 0.05 0.07 26 8 2.96 Corrosion. in 11649 0.07 0.08 31 7 2.96 Corrosion. IN 371 11680 0.06 0.05 21 6 2.95 Corrosion. a■ 372 11712 0.05 0.07 28 7 2.96 Corrosion. r■ 1 373 11743 0.07 0.07 28 6 2.95 Corrosion. MI 374 11773 0.07 0.07 30 9 2.93 Corrosion. i■ 375 11805 0.06 0.07 30 6 2.95 Corrosion. IN 376 11836 0.06 0.08 31 7 2.95 Corrosion. ino ' 377 11867 0.05 0.07 30 8 2.95 Corrosion. i■ 378 11899 0.04 0.06 24 7 2.96 Corrosion. �■ 379 11930 0.05 0.07 28 7 2.96 Corrosion. I■ 380 11961 0.07 0.06 24 6 2.94 Corrosion. N■ I 381 11993 0.04 0.07 28 6 2.94 Corrosion. �■ 382 12023 0.05 0.07 26 6 2.96 Corrosion. E■ 383 12055 0.04 0.07 28 7 2.92 Corrosion. li■ 384 12086 0.05 0.07 26 5 2.94 Corrosion. ■■ I 385 12117 0.04 0.07 30 7 2.93 Corrosion. no 386 12148 0.05 0.08 33 6 2.94 Corrosion. IN 387 12180 0.06 0.05 21 4 2.94 Corrosion. I Penetration Body I Metal Loss Body Page 8 I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 1D-38 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: February 20, 2011 I Joint Jt. Depth I'en. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % loss I.D. Comments ( % wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 388 12211 0.07 0.07 30 6 2.95 Corrosion. gm 389 12242 0.06 0.07 30 6 2.96 Corrosion. am 390 12274 0.06 0.07 30 6 2.96 Corrosion. um 391 12304 0.04 0.07 26 6 2.94 Corrosion. In I 392 12336 0.06 0.07 30 9 2.93 Corrosion. iio 393 12367 0.07 0.07 28 5 2.95 Corrosion. BM 394 12398 0.06 0.07 30 4 2.92 Corrosion. ■M 395 12429 0.05 0.07 26 7 2.96 Corrosion. In 396 12461 0.07 0.08 31 7 2.93 Corrosion. in 397 12492 0.04 0.09 35 5 2.95 Corrosion. um 398 12524 0.06 0.07 28 6 2.96 Corrosion. um 399 12555 0.00 0.07 28 4 2.96 Corrosion. urn 400 12586 0.06 0.06 23 5 2.95 Corrosion. MI I 401 12617 0.05 0.07 28 6 2.94 Corrosion. �rn 402 12648 0.04 0.07 28 5 2.94 Corrosion. ON 403 12680 0.06 0.07 30 6 2.96 Corrosion. III 404 12711 0.04 0.07 28 6 2.93 Corrosion. ■I I 405 12742 0.04 0.07 28 7 2.95 Corrosion. im 406 12773 0.05 0.07 30 7 2.96 Corrosion. Irn 407 12805 0.05 0.07 28 6 2.95 Corrosion. im 408 12836 0.04 0.07 30 6 2.96 Corrosion. ea 409 12867 0.05 0.07 30 5 2.93 Corrosion. ow I 410 12898 0.07 0.10 39 7 2.95 Corrosion. I. 411 12929 0.05 0.08 31 5 2.96 Corrosion. IN 412 12960 0.05 0.08 33 6 2.95 Corrosion. on 1 413 12992 0.05 0.07 26 5 2.94 Corrosion. no I 414 13023 0.05 0.08 31 6 2.92 Corrosion. 415 13054 0.06 0.08 33 6 2.95 Corrosion. IM BEI 416 13085 , 0.04 0.07 30 5 2.92 Corrosion. BE 417 13116 0.06 0.08 31 6 2.94 Corrosion. on I 418 13148 0.05 0.08 33 6 2.95 Corrosion. ow 419 13179 0.04 0.09 35 7 2.93 Corrosion. IN 420 13210 0.06 0.08 31 7 2.93 Corrosion. in 421 13241 0.05 0.08 31 6 2.95 Corrosion. srn 422 13272 0.04 0.08 33 6 2.95 Corrosion. MI I 423 13302 0.04 0.08 31 4 2.93 Corrosion. urn 424 13334 0.04 0.10 40 6 2.94 Corrosion. imi 425 13365 0.06 0.07 30 6 2.93 Corrosion. EN 425.1 13396 0 0.07 26 2 2.92 Pup Corrosion. Lt. Deposits. �' ' 425.2 13407 0 0 0 0 2.81 CMU Sliding Sleeve with 2.812" BX Profile 425.3 13411 0 0.07 26 3 2.91 Pup Isolated Pitting. Lt. Deposits. ■i 426 13420 0.05 0.08 31 5 2.92 Line of Pits. Lt. Deposits. ill 13452 0 0 0 0 2.75 Camco D Nipple 427 13453 0.05 0.10 40 7 2.94 Line of Pits. �� 4 27.1 13485 0.05 0.06 24 4 2.93 Pup Line of Pits. 427.2 13490 0 0 0 0 3.00 Baker Seal Assembly I 11 Pration Body Metal Loss Body I Page 9 I I • • I PDS Report Cross Sections I Well: 1 D -38 Kuparuk Survey Date: February 20, 2011 Field: Tool Type: UW MFC 24 No. 10000428 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf L -80 Analyst: C. Lucasan I Cross Section for Joint 74 at depth 2385.381 ft Tool speed = 47 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 84% � Tool deviation = 31° / \ I / \ I \ / / amoilla I Finger = 18 Penetration = 0.173 ins Line of Pits / Apparent Erosion 0.17 ins = 68% Wall Pen HIGH SIDE = UP I I I I I I • • I PDS Report Cross Sections I Well: 1 D -38 Survey Date: February 20, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 10000428 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf L -80 Analyst: C. Lucasan I I Cross Section for Joint 81 at depth 2632.721 ft Tool speed = 47 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 85% ` Tool deviation = 37° I / \ 1 / \ I 1 I i I Finger = 17 Penetration = 0.164 ins Line of Pits 0.17 ins = 65% Wall Penetration HIGH SIDE = UP I I I 1 1 I • • I PDS Report Cross Sections I Well: 1 D -38 Survey Date: Tool Type: February 20, 2011 Field: Kuparuk UW MFC 24 No. 10000428 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf L -80 Analyst: C. Lucasan I I Cross Section for Joint 67 at depth 2159.978 ft Tool speed = 44 Nominal ID = 2.992 I Nominal OD = 3.5 ... ------mm.....„..... Remaining wall area = 83% Tool deviation = 27° I 7 . I / \ I I / N le 1 NINI I Finger = 7 Penetration = 0.135 ins Line of Pits / Apparent Erosion 17% Cross-sectional Wall Loss HIHG SIDE = UP I I I I I I 0 • I PDS Report Cross Sections U Well: 1D-38 Kuparuk Survey Date: February 20, 2011 Field: Tool Type: UW MFC 24 No. 10000428 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf L -80 Analyst: C. Lucasan I I Cross Section for Joint 71 at depth 2292.581 ft Tool speed = 47 Nominal ID = 2.992 I Nominal OD = 3.5 „�_�.�` Remaining wall area = 83% /� Tool deviation = 28° / I / \ 1 i \ I I \ , / I I I Finger = 17 Penetration = 0.160 ins Line of Pits / Apparent Erosion 17% Cross - sectional Wall Loss HIHG SIDE = UP I I I I I KUP ConocOPhillips � h IA = tt ributes butes Angle & MD TD Well Status Ina 1 ° I Alaska Ins' Wd W W Plead API Plead Name ND (MB) 1 D -38 Act Etna (MUD � - yP , 500292296100 KUPARUK RIVER UNIT INJ 74.29 5,151.28 14,324.0 "' Comment H25 (ppm) Date Annotation End Date KB 1 Rig Release Dale I VVar Confia. - 1030 6/19/2010 1 16 PM SSSV: TRDP Last WO: 12/6/2006 37.83 7/21/2000 Schematic - Actual Amotatian Depth pUB) End Date Annotation Last Mod ... End Dale moor Last Tag: SLM 13,969.0 6/18/2010 Rev Reason: TAG, FORMAT UPDATE Imosbor 6/19/2010 Casing Strings HANGER, 31 Casing Description Suing 0... String ID... Top (RKB) Set Depth p... Set Depth (TVD)... Sting Wt... Sting... String Top Thrd CONDUCTOR 20 18.000 34.0 148.0 148.0 91.50 X52 WELDED I Casing Description Strang 0... String Kt... Top (RKB) Set Depth (L.. Set Depth into) ••• Sting Wt... Sting ... Sting Top mnl ......m 11111 - SURFACE 95/8 8.181 33.9 7,209.7 4,276.5 40.00 L-80 BTC Casing Description String 0... Stag ID ... Top (RKB) Set Depth (L.. Set Depth (TVD)... Sting Wt... String ... String Top Thrd PRODUCTION 7 6.151 30.9 13,6276 6,2914 26.00 L - 80 BTCM Casing Description String 0... Strang ID ... Top pnL61 Set Depth p... Set Depth (TVD) ... String Wt... Sting ._ String Top Thrtl LINER 3 1/2 2.992 13,458.1 14,319.0 6,531.2 9.30 L-80 8RD EUE s Liner Details k. Top Depth CONDUCTOR. (TVD) Top Ind Noel... 34 -148 Top (RKB) (aK6) (') Item Description Comment ID (In) 13,458.1 6,233.0 69.89 PBR BAKER PBR 4.000 13,4647 6,235.3 69.89 PACKER BAKER ZXP LINER TOP PACKER 4.408 SFFETYVLV, z.oso °i 13,469.4 6,236.9 69.89 HANGER BAKER HMC LINER HANGER 4.400 13,478.9 6,240.1 69.88 SBE BAKER SEAL BORE EXTENSION 4000 . 14,251.5 6,505.8 67.94 COLLAR 2.930 - 14,284.4 6,518.2 67.90 COLLAR 2.930 1 C.AS u FT .',,:e �: ' °' Tubing Strings TUBING Description 1St 901 I�2.9 ID ,,, Top 9 1 13 D 622. (... I De6,2551.0 1 ). - ISti9 0...I O ..I 8RD EUE Mod U _' Completion Details Top Depth (TVD) Top net Noel... • G LIFT Top (nKB) MKB) 19 Item Description Comment p(Irn) I MI / 30.9 30.9 -0.16 HANGER FMC GEN V TUBING HANGER 2.992 II 2,060.3 2,026.6 25.42 SAFETY VLV CAMCO TMAXX -5E SSSV, Ran 69 SS bands on control Fine. R U 13,405.4 6,215.2 70.25 SLEEVE-C CMU Sliding Sleeve w/ 2.812" BX Profile 2.810 13,450.8 6,230.5 70.00 NIPPLE Camco D Nipple 2.750 • I SURFACE. 34 -7,210 13,487.2 6,243.0 69.88 LOCATOR BAKER LOCATOR SUB 2.970 13,490.4 6,244.1 69.87 SEAL ASSY Baker GBH22 Seal Assembly 3.000 Other In Hole 'reline retrievable plugs, valves, pumps, fish, etc.) Top Depth SLEEVES. ' ll (TVD) Top Ind 13405 Top 011(B) IRKB) P) Description Comment Run Dale ID(in) ' 13,458 6,233.0 69.89 Tie Back/ PBR LINER ; BAKER MODEL PBR & TOP OF LINER TIE -BACK 7/18/2006 4.000 ill 13,465 6,235.4 69.89 PACKER LINER - BAKER ZXP LINER TOP PACKER 7/18/2006 4.408 NIPPLE, 13651 311 13,469 6,236.7 69.89 HANGER LINER -BAKER MODE HMC LINER HANGER 7/18/2006 4.400 13,479 6,240.2 69.88 SBE LINER - BAKER SEAL BORE EXTENSION 7/18/2006 4.000 i Tie Back/ PBR, I 14,251 6,505.8 67.95 COLLAR LINER - BAKER LANDING COLLAR 7/18/2006 2.930 13 458 14,284 6,518.0 67.90 COLLAR LINER -BAKER FLOAT COLLAR 7/18/2006 2.930 14,317 6,530.5 67.90 SHOE LINER -BAKER FLOAT SHOE 7/18/2006 2.930 PACKER, ons Perforati & Slots find Top(TVD) Elm(TVD) Dens Top (MB) Ban (M03) (RKB) PLKB) Zone Date (St Type Comment HANGER. 13.468 13,941 13,968 6,396.0 6404.9 C -4, 10-38 1/27/2007 6.0 RPERF Y HSD Guts PJ 2006, 60 deg phase 13,959 13,990 6,402.0 6,412.5 Cam, 1 D-38 1/27/2007 6.0 RPERF Y HSD Guns PJ 2006, 60 deg phase 13,970 14,000 6,4056 6,4159 C -4, 1 D -38 5/3/2001 4.0 IPERF 2.5" HSD, DP 3(J UJ SBE, 13,479 Stimulations & Treatments i Bottom Mn Top Max Ban Top Depth Depth Depth Depth (TOO) (TVD) LOCATOR. (RKB) (RKB) (1KB) (1KB) type Date Comment 13407 ._ 13,970.0 14,000.0 6,405.6 6,415.9 HPBD 5/12/2001 SEAL ASSY, �1' Notes: General & Safety 13,480 End Dale Am otation 3/29/2010 I NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 I PRODUCTION, 31- 13,628 RPERF, 13,961- 13,988 RPERF, 13,970. 14.0 N IPERF, 13973 - 14,0000 H PBD, 13,970 Mandrel Details COLLOR Top Depth Top Port 14,257 (TVD) Ind OD Valve Latch Size TRO Ran Sin Top (1(B) ME) 11 Make Model (in) Sena 119e type )In) (Psi) Run Dale Com... 1 2,520.5 2,425.6 34.53 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 12/5/2006 2 7,010.7 4,212.7 71.59 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 12/23/2006 COLLAR, I i 4.284 I ' SHOE, 14,317 • LINER, 13 14,324 19 TO, TD. 14,324 • MEMORANDUM Tai Jim Regg l P.1. Supervisor (( ~1 Z~(l C FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-38 KUPARUK RIV UNIT 1D-38 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ' Comm Well Name: KUPARUK RIV UNIT 1D-38 Insp Num: mitRCN100718160748 Rel Insp Num: API Well Number: 50-029-22961-00-00 Permit Number: 200-077-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ID"3a' Type Inj. N ~ TVD 6235 IA 345 1725 1693 1685 ~ P.T.D 2000790 TypeTest SPT Test psi 1725 OA ~ 203 393 387 383 Interval4YRTST p~F P ~ Tubing 340 340 300 300 Notes: ~1~~r, ~Q~i~ -1~~~" l`~5u ~'; Thursday, July 22, 2010 Page 1 of 1 - __ -- ~ f • • i I~~~ ~ ~.~~~ ~~~~ ~ STATE OF ALASKA ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~Maska Oil ~ Gas OOn~. ~OmfrIISSiOfk ~D~ REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^~ WI to WAG Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Conversion Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 200-077 3. Address: ~ Stratigraphic ^ Service Q 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-22961-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 105' 1 D-38 8. Property Designation: 10. Field/Pool(s): ADL 25661, 25650 Kuparuk River Field ! Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 14324' feet true vertical 6533' feet Plugs (measured) Effective Depth measured 13996 feet Junk (measured) true vertical 6415 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 148' 20" ~4e' 148' SURFACE 7104' 9-5/8" 7209' 4276' PRODUCTION 13522' 7" 13627' 6291' LINER 866' 3-1/2" 14324' 6533' Perforation depth: Measured depth: 13941' - 14000' a^~L..'tC ~e ~-' ~ ~ ~ '~~ ~' ~ ~ ~ ~' true vertical depth: 6396' - 6416' Tubing (size, grade, and measured depth) 3-1/2", L-80, 13522' MD. Packers & SSSV (type & measured depth) Baker ZXP Liner Top Packer 13465' ~ ~~ e' i ~ ~ Camco TMAXX-5E 2060' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13• Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Castn Pressure Tubin Pressure Prior to well operation 1075 627 2133 Subsequent to operation 1307 191 3415 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations X 16. Well Status after proposed work: Oil^ Gas^ WAGQ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A ff C.O. Exempt: N/A Contact g. Christensen/ D. Humphrey Printed Name Ra ert .Chris nsen Title Production Engineering Specialist Signature Phone: 659-7535 Date ~~~ Form 10-404 Revised 04/2004 3 Submit Original Ony __ _ _ _- - - - -- - - -• -- - 1 D-38 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/05/09 Commenced WAG EORX Gas Injection - CvnocoPhillips i4lastca, tnc. ~~ KRU 1 D-38 'fi API: 500292296100 Well T e: INJ An le TS: 70 de 13951 TUBING 1a13szz, SSSV Type: TRDP Orig 7/21/2000 Angle @ TD: 68 deg @ 14324 oD:3.soo, Com letion: ID2.992) Annular Fluid: Last W/O: 12/5/2006 Rev Reason: PERF suRFACE Reference La : Ref Lo Date: Last U date: 1/29/2007 ta7zo9, oo:s.sa5, Last Ta :13996' TD: 14324 ftKB wc4o.oo> Last Ta Date: 1/23/2007 Max Hole An le: 74 de 5151 S Descrl lion Size To Bottom ND Wt Grade Thread CONDUCTOR 20.000 0 148 148 91.50 X52 WELDED PRODUCTION SURFACE 9.625 0 7209 4276 40.00 L-80 BTC (at3sz7, OD:7 000 PRODUCTION 7.000 0 13627 6291 26.00 L-80 BTCM . , wt:26.o0) LINER 3.500 13458 14324 14324 9.30 L-80 EUE-8RD n ~ 31ze To Bottom ND Wt Grade Thread 3.500 0 13522 6255 9.30 L-80 EUE 8RD 0 8, Interval ND Zone Status Ft SPF Date T e Comment 13941 -13959 6396 - 6402 C-4 18 6 1/27/2007 RPERF 2" HSD Guns PJ 2006, 60 de hase 1$959 -13968 6402 - 6405 C-4 9 12 1/27/2007 RPERF 2" HSD Guns PJ 2006, 60 de hase ~ 13968 -13970 6405 - 6406 C-4 2 6 1/27/2007 RPERF 2" HSD Guns PJ 2006, 60 SLEEVE de hase ;13405-13406, 13970 - 13990 6406 - 6413 C-4 20 10 1/27/2007 RPERF 2" HSD Guns PJ 2006, 60 oo:a.5oo) de hase 13990 -14000 6413 - 6416 C-4 10 4 5/3/2001 (PERF 2.5" HSD, DP 31J UJ Stl , u alto n Interval Date T e Comme nt 13970 -14000 5/12/2001 HPBD ;13451-13452, ~~5 _ a . tir e s oD:a.52o) St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv Cmnt 1 2521 2426 CAMCO KBMG DMY 1.0 BK-5 0.000 0 12/5/2006 2 70 11 42 13 CAMCO KBMG DMY 1.0 BK 0.000 0 2/23/200 6 Oher u s_ ~_~ a _ _ _.; O~ P Tie aackJ L>e TVD T e Descrl lion ID PBR 31 31 HANGER FMC GEN V TUBING HANGER 3.500 ;13458-13459, oD:s ooo) 2060 2026 SSSV CAMCO TMAXX-5E SSSV 2.812 . 13405 6215 SLEEVE BAKER CMU 2.812'6X' PROFILE 2.810 13451 6231 NIP CAMCO'D' NIPPLE 2.750 13488 6243 LOCATOR BAKER LOCATOR SUB 2.990 13490 6244 SEAL BAKER GBH-22 SEAL ASSEMBLY 3.000 LINER ;13458-14324, ~ ~ ~ ,, C D ~ ER OD:3.SD0, De h TVD a Descrl lion ID wt:s.3o> 13458 6233 Tie Back/ BAKER MODEL PBR & TOP OF LINER TIE-BACK 4.000 PBR 13465 6235 PACKER BAKER ZXP LINER TOP PACKER 4.408 13469 6237 HANGER BAKER MODE HMC LINER HANGER 4.400 13479 6240 SBE BAKER SEAL BORE EXTENSION 4.000 14251 6506 COLLAR BAKER LANDING COLLAR 2.930 sBE 14284 6518 COLLAR BAKER FLOAT COLLAR 2.930 ;13479-1348D, - 14317 6530 SHOE BAKER FLOAT SHOE 2.930 OD:s.550) SEAL ;13490-13491, OD:4.000) Pert ;13959-13990) HPBD ;13970-14000) Pert 13970-14000) . . ConocJ>'hillips Alaska RECEIVED AUG 1 3 2007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. Commission Anchorage August 9, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED AUG 1 42007 ;200- 077 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibiter, RG2401, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped August 8, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, ~~ ConocoPhillips Well Integrity Projects Supervisor -~ . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/9/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft gal 1 0-32 200-173 10" n/a n/a n/a 6.8 8/8/2007 1 0-36 200-130 20" n/a n/a n/a 4.2 8/8/2007 1 0-37 200-204 20" n/a n/a n/a 4.2 8/812007 1 0-38 200-077 24" nIa n/a n/a 4.2 8/812007 1 0-39 200-216 27" n/a n/a n/a 7.6 8/8/2007 1 0-40 200-190 13" n/a n/a n/a 3.4 8/8/2007 1 0-41 205-188 12" n/a n/a n/a 1.7 8/8/2007 1 0-42 200-164 16" n/a n/a n/a 3.4 8/8/2007 10-131 198-110 6" n/a n/a n/a 2 8/8/2007 . RECEIVED . STATE OF ALASKA ~ MAR 0 1 20UI ALASKA Oil AND GAS CONSERVATION COMMISSION fç REPORT OF SUNDRY WELL OPERA TIONs"'aska Oil & Gas Cons. Commission . 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 , Other U - Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 200-077 1 3. Address: Stratigraphic 0 Service 0 . 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22961-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 31' 1 D-38 8. Property Designatio~: 10. Field/Pool(s): ADL 25661, 25650 Kuparuk River Field 1 Kuparuk Oil Pool ~ 11. Present Well Condition Summary: Total Depth measured 14324' feet true vertical 6533' . feet Plugs (measured) Effective Depth measured 13996' feet Junk (measured) true vertical 6415' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 117' 20" 148' 148' SURFACE 7178' 9-5/8" 7209' 4276' PRODUCTION 13596' 7" 13627' 6291' LINER 866' 3-1/2" 14324' 6533' Perforation depth: Measured depth: 13941'-14000' ~tANNEO MAR 0 6 Z007 true vertical depth: 6396'-6416' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 13522' MD. Packers & SSSV (type & measured depth) Baker ZXP liner top packer @ 13465' Cameo TMAXX-5E SSSV @ 2060' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 13941 '-14000' Treatment descriptions including volumes used and final pressure: high pressure breakdown - refer to summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure Prior to well operation 574 -- Subsequent to operation 373 -- 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilO GasO WAG 0 GINJO WINJ 0 . WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Guy Schwartz @ 265-6958 Printed Name GU~Chwa::;:l 0 Title Wells Group Engineer Signature 1~'-'~'~ 'Phone Date ..2-~-ö 7- Pren,qred hv Sharon Alfsuo-Drake 263-4612 \/ '-......-J Form 10-404 Revised 04/2004 0 RIG I N A L RBDMS BfL, MAR 0 6 ZOD7/ .,u/--. ßM.'7 Submit Original Only v' ~v.;41> 3.'Z, '07 . 1 D-38 Well Events Summary . DATE Summary 1/23/07 DRIFTED TO 13976' SLM WITH 2.64" CENT AND SAMPLE BAILER.BRUSHED TBG TO 13996' RKB.EST 4' FILL 1/24/07 DRIFT TO 13996' RKB WITH 2.5" DUMMY GUNS AND SAMPLE BAILER (OAL=24') 1/27/07 1D-38 WAS PERFORATED USING 2" HSD GUNS LOADED WITH POWERJET OMEGA CHARGES. GUN #1 WAS SHOT FROM 13959-13990'. GUN #2 WAS SHOT FROM 13941'-13968'. ALL SHOTS FIRED. TAGGED TD @ 13990'. WELL LEFT ON INJECTION DURING PROCEDURE. 2/5/07 START HPBD USING 700 BBL OF COLD SEAWATER PUMPING 8.7 BBUMIN @ 3950 PSI PUMP PRESSURE. PUMPED 200 BBL, SHUT DOWN, 15 MIN. READINGS INDICATED A 150 PSI DROP ON TUBING PRESSURE (2300-2150). SECOND STAGE, 15 MIN. TUBING PRESSURE DROP OF 200 PSI (2350-2150). THIRD STAGE, SHUT DOWN, 15 MIN TP DROP OF 200 PSI (2400-2200). DURING FINAL STAGE HIGH PRESSURE TREATING IRON FAILED ON ONE PUMP, SHUT DOWN AND ISOLATE PUMP. COMPLETE FINAL STAGE WITH SINGLE PUMP @ 4 BBUMIN. 45 MIN. SHUT IN PERIOD. INDICATED A TUBING PRESSURE DROP OF 375 PSI (2350-1975). START INJECTION RATE USING 60/40 METHANOL @ 1 BBUMIN. 2000 PSI, PUMP 20 BBLS, FREEZE PROTECT AND SECURE WELL. RIG DOWN, REMOVE FUSABLE CAP AND HAND WELL OVER TO DSO FOR INJECTION. TUBING (0-13522, 00:3.500, 102.992) SURFACE (0-7209, 00:9.625, Wt:40.OO) , ROOUCTION (0-13627, 00:7000, Wt:26.OO) SLEEVE 13405-13406, 00:4.500) NIP 13451-13452, 00:4.520) Tie Back! PBR 13458-13459, 006.000) LINER '13458-14324, 00:3.500, Wt:9.30) SBE '13479-13480, 00:6.550) SEAL 13490-13491, 00:4.000) Perf 13959-13990) HPBO 13970-14000) Perf 13970-14000) . ConocoPhillips Alaska, Inc. - [ ill i ~ ..J L. 1'1II ~ JI - API: 500292296100 SSSVType: TRDP Annular Fluid: Reference Loq: LastTaq: 13996' Last T aq Date: 1/23/2007 DescriDtion CONDUCTOR SURFACE PRODUCTION LINER I I Size 3.500 I I Interval TVD 13941 - 13959 6396 - 6402 13959 - 13968 6402 - 6405 13968 - 13970 6405 - 6406 13970 - 13990 6406- 6413 13990 -14000 6413- 6416 _iIIãÎlrtIW~¡I". Interval Date 13970 - 14000 5/12/2001 1!i2~I)à,,·¡¡_li¡ .... St MD TVD Man Mfr 1 2521 2426 CAMCO 2 7011 4213 CAMCO a.BII.lìfldlltilOl Death TVD Tvoe 31 31 HANGER 2060 2026 SSSV 13405 6215 SLEEVE 13451 6231 NIP 13488 6243 LOCATOR 13490 6244 SEAL 1ll1Ii''''·''''' "" "¡'% DeDth TVD 13458 6233 II 13465 13469 13479 14251 14284 14317 TVDe Tie Back! PBR PACKER HANGER SBE COLLAR COLLAR SHOE 6235 6237 6240 6506 6518 6530 . KRU 1 D-38 Well Tvpe: INJ Orig 7/21/2000 Completion: Last W/O: 12/5/2006 Ref Loq Date: TD: 14324ftKB Max Hole Anqle: 74deq@5151 Anqle@TS: 70 deq @ 13951 Angle@ TD: 68 deg @ 14324 Rev Reason: PERF Last Update: 1/29/2007 Too o Size TOD 20.000 0 9.625 0 7.000 0 3.500 13458 I BDttom I I 13522 I TVD WI I Grade I Thread 6255 9.30 I L-80 I EUE 8RD Ft I!M Date Tvoe Comment 18 6 1/27/2007 RPERF 2" HSD Guns PJ 2006,60 deq phase 9 12 1/27/2007 RPERF 2" HSD Guns PJ 2006, 60 deq phase 2 6 1/27/2007 RPERF 2" HSD Guns PJ 2006, 60 deq phase 20 10 1/27/2007 RPERF 2" HSD Guns PJ 2006, 60 deq phase 10 4 5/3/2001 IPERF 2,5" HSD. DP 31J UJ @ TVD 148 4276 6291 14324 WI 91.50 40.00 26.00 9.30 Grade X52 L-80 L-80 L-80 Thread WELDED BTC BTCM Bottom 148 7209 13627 14324 Zone C-4 C-4 Status C-4 C-4 C-4 TVDe HPBD I Comment I VMfr V Type VOD Latch pon DMY 1.0 BK-5 0.000 DMY 1.0 BK 0.000 I I Date Run VIv Cmnt 0 12/5/2006 0 12/23/200 ID 3.500 2.812 2.810 2.750 2.990 3.000 ID 4.000 4.408 4.400 4.000 2.930 2.930 2.930 Man Type KBMG KBMG ,~; FMC GEN V TUBING HANGER CAMCO TMAXX-5E SSSV BAKER CMU 2.812 'BX' PROFILE CAMCO 'D' NIPPLE BAKER LOCATOR SUB BAKER GBH-22 SEAL ASSEMBLY DescriDtion BAKER MODEL PBR & TOP OF LINER TIE-BACK BAKER ZXP LINER TOP PACKER BAKER MODE HMC LINER HANGER BAKER SEAL BORE EXTENSION BAKER LANDING COLLAR BAKER FLOAT COLLAR BAKER FLOAT SHOE 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 31' -- . REC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 2 REPORT OF SUNDRY WELL OPERATIONS " .~.'i Repair Well D Pull Tubing D Operat. ShutdownD Stimulate D Waiver D Plug Perforations D Perforate New Pool D Perforate 0 4. Current Well Status: Development D Stratigraphic D Other Time Extension Re-enter Suspended Well D 5. Permit to Drill Number: 200-077 1 , 6. API Number: 50-029-22961-00 Exploratory D Service 0 9. Well Name and Number: 1 D-38 B. Property Designation: ADL 25661, '25650 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION LINER Perforation depth: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 14324' . feet true vertical 6533' , feet measured 13996' feet true vertical 6415' feet Length Size MD 117' 20" 148' 7178' 9-5/8" 7209' 13596' 7" 13627' 866' 3-1/2" 14324' Plugs (measured) Junk (measured) TVD Burst Collapse 148' 4276' 6291' 6533' Measured depth: 13941'-14000' true vertical depth: 6396'-6416' SCANNED fEB 0 7 2007 Tubing (size, grade, and measured depth) 3-1/2" . L-BO, 13522' MD. Packers & SSSV (type & measured depth) Baker ZXP liner top packer @ 13465' Cameo TMAXX-5E SSSV @ 2060' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none 13. Treatment descriptions including volumes used and final pressure: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl SI 530 Tubin Pressure Casin Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X 15. Well Class after proposed work: Exploratory D Development D Service 0 16. Well Status after proposed work: oilD GasD WAGD GINJD WINJ 0 WDSPL D Contact 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Form 10-404 Revised 04/2004 Printed Name Signature Guy Schwartz @ 265-6958 Guy Sc " ) Title Phone Wells Group Engineer Date ;¿ -(- ð?- Pre ared b Sharon AlIsu -Dr k 263-4612 hJ(s ~ z-..;: (,) '7 ~~::;. -- 1 D-38 Well Events Summary . DATE Summary 1/23/07 DRIFTED TO 13976' SLM WITH 2.64" CENT AND SAMPLE BAILER.BRUSHED TBG TO 13996' RKB.EST 4' FILL 1/24/07 DRIFT TO 13996' RKB WITH 2.5" DUMMY GUNS AND SAMPLE BAILER (OAL=24') 1/27/07 1D-38 WAS PERFORATED USING 2" HSD GUNS LOADED WITH POWERJET OMEGA "" CHARGES. GUN #1 WAS SHOT FROM 13959-13990'. GUN #2 WAS SHOT FROM 13941'-13968'. ALL SHOTS FIRED. TAGGED TD @ 13990'. WELL LEFT ON INJECTION DURING PROCEDURE. It . ConocoPhillips Alaska, Inc. KRU 1 D-38 TUBING (0-13522, 00:3.500, 10:2.992) SURFACE (0-7209, 00:9.625, Wt:40.00) API: 500292296100 SSSV Type: TRDP Well TVDe: INJ Orig 7/21/2000 ComDletion: Last W/O: 12/5/2006 Ref Loa Date: TD: 14324ftKB Max Hole Anale: 74 dea (â) 5151 Anale (â) TS: 70 dea (â) 13951 Angle @ TD: 68 deg @ 14324 'ROOUCTION (0-13627, 00:7.000, Wt:26.00) Annular Fluid: Reference Loa: LastTaa: 13996' _Date: 1/23/2007 Descrietion CONDUCTOR SURFACE PRODUCTION LINER Rev Reason: PERF Last UDdate: 1/29/2007 Size Toe 20,000 0 9.625 0 7.000 0 3.500 13458 Bottom TVD Wt Grade Thread 148 148 91.50 X52 WELDED 7209 4276 40.00 L-80 BTC 13627 6291 26.00 L-80 BTCM 14324 14324 9.30 L-80 EUE-8RD TVD I Wt I Grade I Thread I 6255 I 9.30 I L-80 I EUE 8RD I I Size I Top I Bottom I 3.500 I 0 I 13522 Interval TVD Zone 13941 - 13959 6396 - 6402 C-4 13959 - 13968 6402 - 6405 C-4 13968 - 13970 6405 - 6406 C-4 SLEEVE '13405-13406, 13970 - 13990 6406 - 6413 C-4 00:4.500) 13990 - 14000 6413 - 6416 C-4 I I / Ft SPF Date 18 6 1/27/2007 9 12 1/27/2007 2 6 1/27/2007 20 10 1/27/2007 10 4 5/3/2001 Type Comment RPERF 2" HSD Guns PJ 2006, 60 deg phase RPERF 2" HSD Guns PJ 2006, 60 deg phase RPERF 2" HSD Guns PJ 2006, 60 dea Dhase RPERF 2" HSD Guns PJ 2006, 60 dea Dhase IPERF 2.5"ÏÎi DP 31J UJ Comment Status /' Interval Date Tvee I 13970 - 14000 5/12/2001 I HPBD I NIP 13451-13452, 00:4.520) St MD TVD Man Mfr Man Type VMfr V Type 1 2521 2426 CAMCO KBMG DMY 2 7011 4213 CAMCO KBMG DMY I V OD Latch Port TRO Date Run Vlv Cmnt 1.0 BK-5 0.000 0 12/5/2006 1.0 BK 0.000 0 12/23/200 lie Back! ~. Depth TVD fvpe ID PBR 31 31 HANGER FMC GEN V TUBING HANGER 3.500 : 13458-13459, 2060 2026 SSSV CAMCO TMAXX-5E SSSV 2.812 00:6.000) 13405 6215 SLEEVE BAKER CMU 2.812 'BX' PROFILE 2.810 13451 6231 NIP CAMCO 'D' NIPPLE 2.750 13488 6243 LOCATOR BAKER LOCATOR SUB 2.990 ::: 13490 6244 SEAL BAKER GBH-22 SEAL ASSEMBLY 3.000 LINER 13458-14324, Depth TVD Tvpe Description ID 00:3.500, Wt:9.30) 13458 6233 Tie Back! BAKER MODEL PBR & TOP OF LINER TIE-BACK 4.000 PBR 11IIII II' 13465 6235 PACKER BAKER ZXP LINER TOP PACKER 4.408 13469 6237 HANGER BAKER MODE HMC LINER HANGER 4.400 13479 6240 SBE BAKER SEAL BORE EXTENSION 4.000 14251 6506 COLLAR BAKER LANDING COLLAR 2.930 14284 6518 COLLAR BAKER FLOAT COLLAR 2.930 SBE 14317 6530 SHOE BAKER FLOAT SHOE 2.930 13479-13480, 00:6.550) SEAL '13490-13491, 00:4.000) Perf '13959-13990) HPBO 13970-14000) Perf 13970-14000) I I I I ...J L. MEMORANDUM . TO: Jim Regg? Z (z·lò7 P.I. Superviso) \ e.r,1 FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UNIT ID-38 Insp Num: mitCS070122151318 Rei Insp Num Packer State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, January 29,2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 10-38 KUPARUK RIV UNIT 10-38 Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-22961-00-00 Permit Number: 200-077-0 Well 1D-38 P.T. 2000770 Depth Pretest IA 1425 OA 320 Tubing 2250 Initial 2500 460 15 Min. 30 Min. 45 Min. 60 Min. 2490 2490 460 460 2250 2250 I.ºt~_r:!_ªL~~~V:R___ _ __rLE___ .._ Notes Pretest pressure observed and found stable. Monday, January 29,2007 SCANNED fES 07 2007 . Reviewed B)': P.I. Sup..$12- Comm Inspector Name: Chuck Scheve Inspection Date: 1/21/2007 Page I of I '~ RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 1 9 2006 REPORT OF SUNDRY WELL OPERA TIONSk 0'1 o. G C C .. 1\las a I a 3S 8· E. ommtSSlon 1. Operations Performed: Abandon D Repair Well 0 Plug Perforations D Stimulate D OtherA h nc 0 e Alter Casing 0 Pull Tubing 0· Perforate New Pool 0 Waiver 0 Time Extension Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 200-077 1 306-358 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22961-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 31' 10-38 8. Property Designatio~: ADL 25661, 25650 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION LINER Perforation depth: measured 14324' , feet true vertical 6533' . feet measured 13546' feet true vertical 6263' feet Length Size MD 117' 20" 148' 7178' 9-5/8" 7209' 13596' 7" 13627' 866' 3-1/2" 14324' Plugs (measured) Junk (measured) TVD Burst Collapse 148' 4276' 6291' 6533' Measured depth: 13970'-14000' SCANNED DEC 2. 1 2.006 true vertical depth: 6406'-6416' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 13458' MD. Packers & SSSV (type & measured depth) Baker ZXP pkr @ 13465' Cameo DS nipple @ 536' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none 13. Treatment descriptions including volumes used and final pressure: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl SI SI . CasinQ Pressure TubinQ Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: OilD GasD WAG 0 GINJD WINJ 0' WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ø'7,...,.) Nt; ~-c:SO'tSl>fjlVr;ft; Contact J ill Long @ 265-1102 Printed Name Jill Long Title Wells Group Engineer ~ d)õYIfJ PhoneqV7_ ¡/PEHIOZ, Form 10404 Revised 0412004 0 RIG I N A L Daily Report of Well Operations _X Signature Date ìl/1 ~ ¡Vip Prepared by Sharon AI/sup-Drake 263-4612 ,41> /2· t?'.0(0 1 \) . ¡.:J,- b \ Submi!, Origin.al Only ~ 1?~/o:G ',-" '..... Conocd>hillips We/Mew Web Reporting Time Log Summary Well Name: 1 D-38 Job Type: RECOMPLETION 12/03/2006 05:00 09:00 4.00 MIRU MOVE MOB P Spot T-matts over well 1 D-38. Prepare pad for move while replacing one drive motor on moving system. 09:00 11:00 2.00 MIRU MOVE MOB P Warm up moving system. Roll tires. PJSM. Move rig off well 1 D-40A. Hang new tree in rig cellar. 11:00 12:00 1.00 MIRU MOVE MOB P Spot rig over 1 D-38. Rig up & berm up. Accept rig ~ 1200 hrs, 12/3/06. 12:00 13:00 1.00 COMPZ~ WELCl NUND P Spot cuttings box. Bleed off IA from 500 psi to zero. Hook up circulating hoses. 13:00 14:00 1.00 COMPZ~ WELCl OTHR P PU & RU lubricator. Pull BPV. No pressure on tubing. 14:00 14:30 0.50 COMPZ~ WELCl OTHR P Load pits with 9.6 ppg brine. Test circulating lines. 14:30 16:00 1.50 COMPZ~ WELCl CIRC P PJSM. Displace diesel cap from well, pump 30 Bbls 9.6 ppg brine down lA, 3 BPM, 500 psi, taking diesel returns from tubing to cuttings box. Switch lines and pump 80 Bbls 9.6 ppg brine down tubing taking brine and diesel returns from lA, 3 BPM, 300 psi. 16:00 17:30 1.50 COMPZ~ WELCl OTHR P Set BPV. ND tree. Tubing hanger and lift threads in good condition. 17:30 19:00 1.50 COMPZ~ WELCl NUND P Prepare to NU BOP stack. Received new blanking plug from machine shop and installed same in hanger. Start loading tubing into pipe shed. 19:00 23:00 4.00 COMPZ~ WELCl NUND P NU BOPE. 23:00 00:00 1.00 COMPZ~ WELCl BOPE P Jeff Jones with AOGCC waived BOP test. Start Testing BOP's. 12/04/2006 00: 00 05:30 5.50 COMPZ~ WELCl BOPE P Finish testing BOP's. Test pipe rams and blinds 250/3000 psi. Test annular preventer 250/2500 psi 05:30 06:30 1.00 COMPZ~ WELCl BOPE P LD blanking plug. Monitor IA. Pull BPV. 06:30 07:30 1.00 COMPZ~ RPCOI\. PULD P MU landing joint. PJSM. BOLDS. PU and pull tubing hanger to rig floor, 115K# PU Wt, 70K# SO Wt, 34K# Blocks, 125K# Max PU Wt. 12/04/2006 07:30 10:30 3.00 COMPZr- RPCO~ CIRC P Break circulation at 2 BPM, 120 psi. Switch lines and start reverse circulating to clean hole. Reversed 1-1/2 tubing volumes, 5 BPM, 850 psi, small amount of very fine black silt at bottoms up. Pump 30 Bbl Hi-Visc pill down IA and reverse circulate around to surface, 7 BPM, 1730 psi - 1350 psi. No significant amount of solids from hole, only small amount of very fine black silty material. 10:30 11:00 0.50 COMPZr- RPCO~ OWFF P Monitor well. Pump 20 Bbls of 10 ppg brine for slug. 11:00 11:30 0.50 COMPZr- RPCO~ PULD P RD circulating lines. LD LJ. LD tubing hanger. 11:30 18:00 6.50 COMPZr- RPCO~ PULD P POH LD 3-1/2" tubing. Looked closely at first 45 joints pulled, no / holes found, but see deep pits in a band about 1-2" wide on one side of pipe bore. 18:00 00:00 6.00 COMPZr- RPCO~ PULD P Finish pulling 3-1/2" tubing. No holes I' found in tubing, but pin ends of tubing showed signs of corrosion with metal loss. 12/05/2006 00:00 05:30 5.50 COMPZr- RPCO~ OTHR P Finish loading tubing in pipe shed. Clean rig floor, prep to run 3-1/2" completion. 05:30 16:30 11.00 COMPZr- RPCO~ RCST P Hold PJSM. Run 3-1/2" completion. / D nipple drifted to 2.735", tubing drifted to 2.867". MU head pin & hose on top of joint #430. Left SSSV out of string to check for good stab-into SBR. 125K# PUW, 70K# SOW, 34K# Blocks. 16:30 17:30 1.00 COMPZr- RPCO~ DHEQ P Circulate slow, 1 BPM, 60 psi. Slack off & stab seals into SBR, shut off pump when seal entry observed, bled off pressure and left tubing open. Continued slacking off and stabbed seals fully into SBR, locator bumped on No Go at proper position. Picked up about 2' above No Go and tested seals to 500 psi for 5 minutes, OK. 17:30 18:30 1.00 COMPZr- RPCO~ RCST P LD 1 joint. POH 22 stands to install SSSV. 18:30 20:00 1.50 COMPZr- RPCO~ PULD P MU SSSV assembly on top of Jt #363. RU control line spool and hang sheave. MU SS control line to SSSV and test to 5500 psi for 10 minutes, OK. PJSM. 20:00 22:00 2.00 COMPZr- RPCO~ RCST P RIH with stands from derrick, and SS control line for SSSV. Total of 69 control line bands ran. 12/05/2006 22:00 00:00 2.00 COMPZf' RPCOI\ RCST P Get pick up weight 125K up / 70K down. Lay down single 429, rig-up circulating equipment, establish rate @ 1 bpm 60 psi, tag top seal assembly @ 13,502' MO, pressure up to 500 psi, bleed pressure off, fully engaged @ 13,522'MD. Space out, 24.83' needed in pups. 12/06/2006 00:00 01:00 1.00 COMPZf' RPCOI\ RCST P Lay down two singles. Make up three space out pups totaling 24.26', one single, tubing hanger, landing joint and circulating equipment. Note: Ran 69 SS bands on SSSV control line. 01:00 04:00 3.00 COMPZf' RPCOI\ CIRC P Circulate out 9.6 ppg brine with seawater. Spot a full IA with corrosion inhibited seawater 1 % Baker Petrolite CRW-132. 04:00 07:30 3.50 COMPZf' RPCOI\ RCST P Reduce rate to min. rate @ 70 psi. Engage seal assembly, pressure to 500 psi, bleed off pressure, land hanger while holding 5000 psi on control line, RILOS. Rig up chart recorder on tubing and IA. Pressure test tubing to 2500 psi for 15 mins. Bleed tubing to 1500 psi. Pressure test IA to 2500 psi for 30 mins. Bleed tubing down to shear SOV, bleed well pressure to 0 psi. 07:30 08:30 1.00 COMPZf' RPCOI\ OTHR P RU & wash out BOP stack. 08:30 09:00 0.50 COMPZf' RPCOI\ NUND P Set TWC. 09:00 15:00 6.00 COMPZf' RPCOI\ NUNO P NO BOPE. Break flanges and doors on 11" 5 Ksi Shaffer stack before setting back on stump. Plan to swap this stack for the 11" 5 Ksi Hydril BOP stack on rig move. 15:00 17:00 2.00 COMPZf' RPCOI\ NUND P NU FMC tubing head adapter & 3-1/8" 5 Ksi tree. Test void space and tree to 5000 psi. 17:00 18:30 1.50 COMPZf' RPCOI\ FRZP P RU Little Red hot oil unit and lines. Test lines to 2500 psi. Reverse circulate 90 Bbls of diesel at 2 BPM, 100 F into lA, take SeaWater returns to cuttings box. 0 psi Tbg / 600 psi IA / 290 psi OA final pressures after shut down. 18:30 20:00 1.50 COMPZf' RPCOI\ FRZP P Connect tubing and IA and let diesel U-tube until equalized for freeze protection, about 2550' MD in tubing and IA. 20:00 22:00 2.00 COMPZf' RPCOI\ OTHR P Blow down lines. Set BPV. Release rig @ 22:00 hours, 12/6/06. TUBING (0-13458, OD:3.500, ID:2.992) SURFACE (0-7209, OD:9.625, Wt:40.QO) ) RODUCTION (0-13627, OD:7.QOO, Wt: 26. 00) Tie Backl PBR (13458-13459, LINER (13458-14324, OD:3.500, Wt:9.30) SBE (13479-13480, OD:6.550) NIP (13481-13482, OD:3.500) LOCATOR (13489-13490, OD:4.500) SEAL (13490-13491, OD:4.500) Perf (13970-14000) HPBD (13970-14000) "-- ~ KRU 1 D-38 ConocoPhillips Alaska, Inc.. 1e·ss I I I I L-L.. API: 500292296100 SSSV Type: NIPPLE Annular Fluid: Well Type: INJ Orig Completion: 7/21/2000 Last W/O: Angle @ TS: 70 deg @ 13951 Angle @ TO: 68 deg @ 14324 Rev Reason: ADD LINER JEWELRY Last Update: 11/5/2006 Ref Log Date: TO: 14324 ftKB Max Hole Angle: 74 deg @ 5151 Size 20.000 9.625 7.000 3.500 Top o o o 13458 Bottom 148 7209 13627 14324 TVD Wt 148 91.50 4276 40.00 6291 26.00 14324 9.30 Grade Thread X52 WELDED L-80 BTC L-80 BTCM L-80 EUE-8RD Grade I L-80 Bottom 13458 TVD Wt 6233 9.30 Thread EUE 8RD Zone C-4 I Status 1Ft I SPF I Date I Type j Comment 30 4 5/3/2001 IPERF. 2$' HSD, DP 31J UJ Comment V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt DMY 1.5 RK 0.000 0 5/10/2001 13465 6235 13469 6237 13479 6240 14251 6506 14284 6518 Description BAKER MODEL PBR & TOP OF LINER TIE-BACK BAKER ZXP LINER TOP PACKER BAKER MODE HMC LINER HANGER BAKER SEAL BORE EXTENSION BAKER LANDING COLLAR BAKER FLOAT COLLAR 4.408 4.400 4.000 2.930 2.930 2.930 ID 4.000 Description FMC GEN V TUBING HANGER CAMCO DS NIPPLE NO GO PROFILE CAMCO DS NIPPLE NO GO PROFILE LOCATOR SUB BAKER GBH-22 SEAL ASSY ID 3.500 2.875 2.812 3.500 3.500 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: ¡¡m reQQ@¿admín.state.ak.us aOQcc prudhoe bav(Çifadm;n.sta!e.ak.lis bot; f;eckenste;n@¿admín.state.ak.us Contractor: Nordic Rig No.: 3 DATE: 12/5/2005 Rig Rep.: Ron Rice/Ben Wedin Rig Phone: 659-7438 Rig Fax: 659-7566 Operator: Conoco/Phillips Alaska Op. Phone: 659-7446 Op. Fax: 659-7566 Rep.: Don Breeden/Brad Gathé Field/Unit & Well No.: 1D-38 11 /09/04 Operation: Test: Test Pressure: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve PTD # 200-077 ( 4 Drlg: Workover: X ¡~Ç~~~~ff.¿) Initial: X Weekly: Bi-Weekly Rams: 250/3000 si Annular: 250/2500 s Valves: 250/3000 si TEST DATA Well Sign Dr!. Rig Hazard Sec. Size 11" 27/8" x 5" 31/2" 11" 3 1/8" 3 1/8" 3 1/8" MUD SYSTEM: Visual Test Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P BOP STACK: Quantity 1 1 1 1 1 1 1 1 Alarm Test P P P P P Test Result P P P Test Result P P P P P P P NA FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 12 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure TestResult System Pressure 2950 Pressure After Closure 1950 200 psi Attained 15 sec. Full Pressure Attained 75 sec Blind Switch Covers: All stations P Nitgn. Bottles (avg): 2000 psi Test Results Number of Failures: º Test Time: 6.5 Hours Components tested Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ¡¡m reQQ«D.admín.state.ak.us Remarks: FMC BlankinQ pluQ was cut down to facilitate the testinQ of the lower pipe rams. BOP Test (for rigs) BFL 11/09/04 24 HOUR NOTICE GIVEN YES X NO Date Test start 12/02/06 10:30pm Time Finish Waived By Jeff Jones 8:00AM Witness Brad Gatham/Ben Wedin 5:00am BOP Test-Nordic 3 12-04-06.xls Re: BOP configuration for ID-38 Workover . . Jill, You have answered my questions. Issues with plug height have been encountered before and I agree they are likely to be encountered on future wells. Good move looking in to the proper spacer spool. Tom Maunder, PE AOGCC Jëx)-a ~ '\ Long, Jill W wrote, On 11/3012006 3 :05 PM: Tom- Thanks for getting back to me on this. To answer your questions, yes- if we cannot secure a satisfactory BOP test with the blanking plug and need to test with a test plug we will test the lower rams. Also, we have looked into inserting a spacer spool but at this time we do not have one that will meet our needs. However, seeing as how this could be an issue on future wells we will be trying to secure a spacer spool that can be used for this application. Again, thanks for the help and if you have any questions please call me on my cell. Jill W. Long ConocoPhillips Alaska, Inc. Office: (907) 265-1102 Cell: (907) 240-6574 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, November 30, 2006 1:11 PM To: Long, Jill W Subject: Re: BOP configuration for 1D-38 Workover Jill, The regulations as I understand them require 1 set of pipe rams, 1 set of blind rams and an annular for operations with MASPs less than 3000 psi. According to your calculations, ID-38 meets the less than 3000 psi. Employing 3 sets of preventers as you describe will meet the regulations. Your plan presumes that you will be able to satisfactorily get a BOP test testing against the blanking plug and tubing hanger. If it is necessary to test with a test plug, will you then test the lower rams? Has employing a spacer spool under the lower pipe rams been investigated to eliminate conflicts with the long blanking plugs? Call or message with any questions. Tom Maunder, PE AOGCC Long, Jill W wrote, On 11/30/2006 11: 18 AM: lof2 12/4/20061:18 PM Re: BOP configuration for ID-38 Workover Tom- . . This email is in regards to the BOP configuration for the upcoming workover on 10-38 ( Sundry # 306-358) which I spoke with you about on the phone earlier today. The current BOP configuration consists of 4 preventers: a set of lower pipe rams, blind rams, upper pipe rams, and the annular. However, the blanking plug available for testing is too long in order to test the lower set of pipe rams. Because of the anticipated reservoir pressures, we would like to maintain the current BOP configuration but only test the blind rams, upper pipe rams, and annular prior to pulling the current completion. A composite plug has been set in this well and passed both positive and negative pressure tests. Also, the well has been loaded with 9.6 ppg brine. The anticipated maximum possible surface pressure in this area assuming a 0.1 psi/ft gradient is 2,800 psi. This pressure is based on the last SBHP measurement of 2,875 psi taken on 12/1/05 at 10,630' MO (5,356' TVO). At mid-perf depth the pressure would be 3,441 psi. Will you approve completing this workover only testing the upper 3 preventers? If you have questions please give me a call on my cell phone at 907-240-6574. I can also be reached at 659-7446 for the next few hours. Thank you, Jill W. Long ConocoPhillips Alaska, Inc. Office: (907) 265-1102 Cell: (907) 240-6574 20f2 12/4/20061:18 PM . . FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jill Long Wells Group Engineer ConocoPhíllips Alaska, Inc. 700 G Street Anchorage, Alaska 99501 Re: Kuparuk River Field, Kuparuk Oil Pool, Well Name ID-38 Sundry Number: 306-358 Dear Ms. Long: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. n K. Norman Ch' n DATED this4 of November, 2006 Encl. :Job -ol'q- . . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3,2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1 0-38 (PTD# 200-077). Injecting well 10-38 was drilled in June 2000 and completèd in May 2001. The well failed an MITIA in April 2005 and was reported to the AOGCC. A caliper log ran in April 2006 confirmed that the tubing has considerable corrosion with multiple wall penetrations greater than 96%, .Y including two joints with wall penetrations of 100% (possible holes). In order to repair this well and return it to injection a rig workover must be completed. This well is a poor patch candidate because of the multiple locations with wall loss exceeding 96%, pitting (as indicated by the caliper log), and the probability that additional leaks will develop if the current tubing string remains in the hole. The purpose of the proposed workover will be to pull the existing tubing string and replace it with a new one. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265-1102. Sincerely, (:=1; n (! õOr d)¿1WL Ji~;-::rc::; , U Wells Engineer CPAI Drilling and Wells ÞJ-s i. It (ß}-/f- ð pûh ~ STATE OF ALASKA ~\\ 1"6 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 1. Type of Request: Abandon D Suspend D Operational Shutdown D Alter casing D Repair well 0 Plug Perforations D Change approved program D Pull Tubing 0 Perforate New Pool D 2. Operator Name: 4. Current Well Class: ConocoPhillips Alaska, Inc. Development D 3. Address: Stratigraphic D Perforate D Stimulate D Waiver ·n· Other D . Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D Service 0 200-077 ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Requires? Yes D No 0 1 D-38 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25661, '25650 RKB 31' Kuparuk River Field I Kuparuk Oil Pool, 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14324' I 6533' , 13965' Casing Length Size 50-029-22961-00 8. Well Name and Number: MD TVD 148' Burst Collapse CONDUCTOR 117' 20" 148' SURFACE 7178' 9-5/8" 7209' PRODUCTION 13596' 7" 13627' LINER 866' 3-1/2" 14324' 4276' 6291' 6533' Perforation Depth MD (ft): 13970'-14000' Packers and SSSV Type: Baker ZXP pkr @ Cameo DS nipple @ 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 15. Estimated Date for Commencing Ope rat 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name J~I Lone: /'f)rv-.,'" Signature (J¡' fJ fJ v (j /1. .Lf>ÌJr? 01 (/ .ó'ommission Use Onlv Perforation Depth TVD (ft): 6406'-6416' Tubing Size: 3-1/2" Tubing Grade: L-80 Tubing MD (ft): 13458' Packers and SSSV MD (ft) 13465' 536' November 13, 2006 Date: 14. Well Class after proposed work: Exploratory D Development D 16. Well Status after proposed work: Oil D Gas D WAG D GINJ D Service 0 Plugged D WINJ 0 Abandoned D WDSPL D Phone 265-1102 Jill Long @ 265-1102 Wells Group Engineer Date Contact: Title: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3DlP - ß58 Plug Integrity D BOP Test '~ Mechanical Integrity Test ~ Location Clearance D Other: ~~OO~';>~·\ \'J\\~\'M.Ù-,"",,- ro ~ _~ S'''""em Fo<m Req,;red 1-\0 ~~ };¡{ (I J~'I ./V"~·\ Approved by: T -/1 ./. C'8MIt'I1SSIONER Form 10-403 Revised 06/2006 rlR 1 r.;n~ A I , "...·8·· nus BF"¡ K "um~ .'. ¡.] ·4 2006 APPROVED BY , J! . I THE COMMISSION Date: /," ' O-b ~Submit in Duplicate ~(t/r~À /I·?·~ . . Kuparuk 1 D-38 General Workover Procedure Pre-RiQ Work 1. Set composite below seal assembly and pull valve in GLM 2. Load well with brine circulating through open GLM 3. Pressure test plug to 2,000 psi and freeze protect 4. Set BPV 5. Prepare location for arrival of Workover Rig General Workover Procedure r ~ \00 \>-s:\ ..,. 1. MIRU Workover Ri9_~__\'-<>.", x.\:..ù..\,-,J\ú.~ 2. NO tree, MU blanking plug, and pressure test BOPE. The last SBHP measurementwÞ~-\"'\~~~ 2,875 psi on December 1, 2005, at 10,630' MD (5,356' TVD). This correlates to 3,441 ~~ Û}.\c..~\c:À\c't\ psi at mid-perf depth (13,985 MD= 6,411 TVD). Prior to rig arrival, a composite plug will <.1:::>"~'~Q;.~\v~ be set in liner below the seal assembly and the well loaded with 9.6 ppg brine. Because of this, kill weight fluid should not be needed; however, in the event that the plug fails, the estimated mud weight needed at mid-perf would be 10.32 ppg. Assuming a 125 psi overbalance, the mud weight would need to be 10.70 ppg. The calculated maximum possible surface pressure assuming a full gas gradient (0.1 psi/ft) is 2,800 psi. Æc:ø'r1 \\/C(;; 3. Pull tubing and run new tubing/new completion. Prior to setting the new completion, ,/ circulate out brine leaving corrosion inhibitor in the IA. 4. NO BOPE, NU tree, and test tree 5. Set BPV M \ \" .-r¿CY0\~k2?¡.LL/g 6. RDMO workover rig Post-RiQ Work: 1. Pull BPV 2. Set DV in mandrel 3. Drill out composite plug 4. Tag fill 5. Return to injection . ConocÓPhillips Well: 10-38 Field: Kuparuk . API: 500292296100 PTD: 200-077 2006 RWO PROPOSED COMPLETION WELLHEAD Lift threads: 3Y:z" Srd EUE BPV: CIW H BPV Model: FMC Gen V Slim hole CONDUCTOR 20",91.5 ppf, X52 LP, welded SURFACE CASING 9%",40 ppf, L-SO, BTC PRODUCTION CASING 7", 26 ppf, L-SO, BTC-MOD TUBING 3Y:z", 9.3 ppf, L-SO, EUE-Srd LINER 33Y:z", 9.3 ppf, L-SO, EUE-Srd PERFS C-4 13,970'-14,000' MD 6,406'-6,416' TVD 4 spf, 05/03/01 A B c NEW COMPLETION A: SCSSV: 3Y:z" with 2.813" X profile 2,000' TVD= 2,031' MD B: Gas Lift Mandrel MD TVD TYPE 2,612 2,500 1" KBMG C: Sliding Sleeve: 3Y:z" with 2.S13" X profile Place at least 1 full joint above seal assembly D: Seal Assemblv <02 13.490' MD Last Tag: 4/15/06 Tag Depth: 13,965' This was as far as SL could get down- probably not a true tag TD: 14,319' RKB **Well has a history of schmoo** Last Updated: 3-Nov-06 Updated by: JWL KRU ID-38 (2000770) MITIA 04-05-05.xls / ) ) Subject: KRU 1D-38 (2000770) MITIA 04-05-05.xls From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Wed, 06 Apr 2005 09:17:17 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: Jim Regg AOGCC <jim_regg@admin.state.ak.us> Tom, Attached is the failed MIT-IA report for injection well 1 0-38 (2000770). 10-38 will be shut-in today and added to our monthly failed MIT report for injectors. Diagnostics are still in progress to determine the T x IA communication. Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907 -659-7224 «10-38 MITIA 04-05-05.xls» SC/~NNED AUG 0 9 2005 Content-Description: 1D-38 MITIA 04-05-05.xls ID-38 MITIA 04-05-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 ~J~~ ~\~ ,ttP~ 8/8/2005 4:08 PM ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk River Unit /1 0 04/05/05 Packer Depth Pretest Initial 15 Min. 30 Min. Well 10-38 Type Inj. S TVD 6,244' Tubing 1,360 1,751 1,723 1,556 Interval 0 P.T.D. 2000770 Type test P Test psi 3000 Casing 1,422 2,956 1,944 1,620 P/F F Notes: Well is showing signs of T x IA communication OA 100/250/150/100 Well 10-38 Type Inj. S TVD P.T.D. 2000770 Type test P Test psi Notes: Well is showing signs of T x IA communication 6,244' Tubing 1,556 1,763 3000 Casing 1,620 2,965 OA 100/250/150/100 1,734 1,581 Interval 0 1,904 1,644 P/F F Interval P/F Interval P/F Interval P/F Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 1 D-38 MITIA 04-05-05.xls :{e: 10-38 (PTO 2000770) T x IA communication -') ) Subject: Re: I D-38 (PTD 2000770) T x IA communication From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 05 Apr 2005 10:02:17 -0800 To: NSK Problem Well Supv <n 1617@conocophillips.com> Thanks Brad. You or Jerry should add this well to the monitoring list. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, We are conducting a MIT -IA today on 10-38 and I will provide you with the results once finished. Below is the TII/0 from Jan 1. 2005. The plot below has automated tubing and IA pressures readings for 10-38. The scale for Tubing and IA pressures are both 0-2500 psi. Please call with any questions. _...~-------_.._---_..__.._~,._~..._-_._.~._.._,~-_!..._~--,--- .. _........._--"ft........_________ -----Original Message----- From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Tuesday, April 05, 2005 8:29 AM To: NSK Problem Well Supv Cc: ¡im reQQ@admin.state.ak.us Subject: Re: 10-38 (PTD 2000770) T x IA communication Brad, Can you provide a T/I/O plot since January I. What is the schedule for your diagnostics?? Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom. Injector 10-38 (PTO 2000770) is showing signs of T x IA communication. On 412105 the Tubing and IA pressures equalized at - 1900 psi. On 04103/05 the Tubing PO's were tested and passed, T/lIO = 1450/1510/150 We have pinched back the injection rate to reduce wellhead pressures and would like to continue injection with increased monitoring until we can complete diagnostics. 1 of !.lR- rr¡ 4/5/2005 10:47 AM KRU ID-38 (2000770) MITIA 04-05-05.xls ') ) Subject: KRU 1D-38 (2000770) MITIA 04-05-05.xls From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Wed, 06 Apr 2005 09:17:17 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: Jim Regg AOGCC <jim_regg@admin.state.ak.us> JrßtT"" ø 17 Tom, Attached is the failed MIT-IA report for injection well 1 0-38 (2000770). 10-38 will be shut-in today and added to our monthly failed MIT report for injectors. Diagnostics are still in progress to determine the T x IA communication. Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907 -659-7224 «10-38 MITIA 04-05-05.xls» Content-Description: 1D-38 MITIA 04-05-05.xls ID-38 MITIA 04-05-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 SC,ANNED APR 1 4 2005 1 of 1 4/7/2005 10:06 AM ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD I UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk River Unit / 10 04/05/05 ,011 :»0·· Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us Packer Depth Pretest Initial 15 Min. 30 Min. Well 10-38 Type Inj. S TVD 6,244' Tubing 1,360 1,751 1,723 1,556 P.T.D. 2000770 Type test P Test psi 3000 Casing 1,422 2,956 1,944 1,620 Notes: Well is showing signs of T x IA communication OA 100/250/150/100 Interval P/F o F Well 10-38 Type Inj. S TVD P.T.D. 2000770 Type test P Test psi Notes: Well is showing signs of T x IA communication 6,244' Tubing 1,556 1,763 3000 Casing 1,620 2,965 OA 100/250/150/100 1,734 1,581 Interval 0 1,904 1,644 P/F F Interval P/F Interval P/F Interval P/F Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 1 D-38 MITIA 04-05-05.xls RE: ID-38 (PTD 2000770) T x IA communication Subject: RE: ID-38 (PTD 2000770) T x IA communication From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Tue, 05 Apr 200509:44:44 -0800 To: Thomas Maunder <tom _ maunder@admin.state.ak.us> Tom, We are conducting a MIT-IA today on 1 D-38 and I will provide you with the results once finished. Below is the T/I/O from Jan 1, 2005. The plot below has automated tubing and IA pressures readings for 1 D-38. The scale for Tubing and IA pressures are both 0-2500 psi. Please call with any questions. /- T"~ ~\>-\\Lk --'jU..lri.lI0J_ .ü....."U1 L ,,-. -~------------~_._-~-----~--------_._---~-~---._--~-~- --~-----~_._----_..._--~_. ----. 10f2 4/7 /2005 10:09 AM RE: ID-38 (pTD 2000770) T x IA communication __ ____ __ _ ___ _ _ __ . _____ .___n._ ._.~... _ ___un ___ __ __ _ _ _ _ ... _____.___.._._...___..____"__. ._.___ .____ ___._._______m__ - __ ._ - ___.______n - - - - ---.-. j ~< - - - - - .~ ~ I I ¡ ¡ I I 'I ' ~ - - . - --- ._~ .,.': . " _ 7 --- - - - - ¡ "'":::... ~ i y. _ ,,' _ I. _ .' _ _ . _. . - -. ~ ~"'" ~ ~ ,~~ _ . __ _ _ ~ ~J . -<-- ..-" ~. -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, April 05, 2005 8:29 AM To: NSK Problem Well Supv Cc: jimJegg@admin.state.ak.us Subject: Re: ID-38 (PTD 2000770) T x IA communication Brad, Can you provide a T/IJO plot since January 1. What is the schedule for your diagnostics?? Tom Maunder, PE AOGCC ~. NSK Problem Well Supv wrote: Tom, Injector 1 D-38 (PTD 2000770) is showing signs of T x IA communication. On 4/2/05 the Tubing and IA pressures equalized at - 1900 psi. On 04/03/05 the Tubing PO's were tested and passed, T/I/O = 1450/1510/150 We have pinched back the injection rate to reduce wellhead pressures and would like to continue injection with increased monitoring until we can complete diagnostics. Please call with any questions. Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907-659-7224 ~. 20f2 4/7/2005 10:08 AM ) ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk River Unit /10 04/05/05 - '\"".',..6" : ,,-If'. -,.~, '7' ':"7' ~fjJl tic, U 1,734 1,581 Interval 0 1,904 1,644 P/F F Interval P/F Interval P/F Interval P/F Packer Depth Pretest Initial 15 Min. 30 Min. Well 10-38 Type Inj. S TVD 6,244' Tubing 1,360 1,751 1,723 1,556 P.T.D. 2000770 Type test P Test psi 3000 Casing 1,422 2,956 1,944 1,620 Notes: Well is showing signs of T x IA communication OA 100/250/150/100 Well 10-38 Type Inj. S TVD P.T.D. 2000770 Type test P Test psi Notes: Well is showing signs of T x IA communication 6,244' Tubing 1,556 1 ,763 3000 Casing 1,620 2,965 OA 100/250/150/100 Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test SC.A~~NEr' þ i.i, /OfYì MIT Report Form Revised: 06/19/02 1 D-38 MITIA 04-05-05-1.xls Interval P/F o F INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= other (describe in notes) MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc ~i d Mike Mooney ,. ~ Wells Group Team Leader Drilling & Wells P. O. Box 100360 ~ Anchorage, AK 99510-0360 ConocoPh i iii pS Phone: 907-263-4574 December 17, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 10-38 (APD # 200-077) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 10-38. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, tA l1l~ M. Mooney Wells Group Team leader CPAI Drilling and Wells MM/skad RECEIVE,D JAN 0 5 ZOO4 A\aska Oil & Gas Cons. Commission Anchorage n. n I h , "I A 1 j I "~":' ! 'M" , \ <,Ç;,:(("l~I~¡J~Q~'~'i) IIAN~I~rl' liìì /ÏfJ[ CßrrO'{i :, 'I' 'I,; ",,',C'D;, "','"" \~\'\jth\tl'tJð'IJ¡ç;;[L., ",JJ D'i ({¿; \LII ¡f~!.JJ u ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Variance 0 Annular Disp. 0 Alter Casing 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 200-077 I 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22961-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 31' 1 D-38 8. Property Designation: 10. Field/Pool(s): ADL 25661, 25650, ALK 471 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 14324' feet true vertical 6533' feet Plugs (measured) Effective Depth measured 14272' feet Junk (measured) true vertical 6514' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 148' 20" 148' 148' SURFACE 7104' 9-5/8" 7209' 4276' PRODUCTION 13522' 7" 13627' 6291' LINER 866' 3-1/2" 14324' 6533' Perforation depth: Measured depth: 13970'-14000' true vertical depth: 6406'-6416' R E C E I VE JAN 0 5 2004 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 13458' MD. Alaska Oil & Gas Cons. Commission Packers & SSSV (type & measured depth) no packer Anchorage sssv= NIP sssv= 536' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 13481' Treatment descriptions including volumes used and final pressure: 720 bbls of seawater 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation - - NIA - Subsequent to operation - - 358 - 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilO GasO WAG 0 GINJO WINJ0 WDSPLO 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team leader Signature ¡11( ~ AI{ ~ Phone. Date) :2../2 zit) 3 , ,.', ! '" , ^ 8 Preoared bv Sharon AI/suo-Drake 263-4612 l.J ;'\ ~ l.J' ! \J Ii L Form 10-404 Revised 2/2003. SUBMIT IN DUPLICATE RBDMS BFl JM 0 1 21M ( ( ~PHILLIPS Alaska, Inc. KRU 10-38 .~ A Subsidiary of PHILLIPS PETROLEUM COMPANY TUBING 1 D.38 (0-13458, 00:3.500, 10:2.992) SURFACE Size To Bottom TVD Wt Grade Thread (0-7209, 20.000 0 148 148 91.50 X52 WELDED 00:9,625, 9.625 0 7209 4276 40.00 L-80 BTG Wt:40.00) 7.000 0 13627 6291 26.00 L-80 BTGM PRODUCTION 3.500 13458 14324 14324 9.30 L-80 EUE-8RD (0-13627, 00:7,000, Wt:26.oo) Comment Vlv Gas Lift Cmnt landrel/Oummy Valve 1 . -..._.___n ---. -- u--.. (13434-13435, . -.-. -"'-n. -. ._I~- . 00:5.968) ----.. - 2.B75 2.812 .--.-.. ___no 3.500 ------- -. i I LINER II (13458-14324, I: 00:3.500, Wt:9.30) . NIP I (13481-13482, i 00:3.500) !: , I I I SEAL i (13490-.13491. ! I 00.4.500) : I . , Perf . ! i i ! (13970-14000) j _. 1 ~ I HPBO .i i-- . I !I (13970-14000) .1: 'l II j ~ ~ ~ I' I : . I -... i ! '1 . - :1 L :: .1 '1;- ..... .. I I . I I ... . I .. .- '-, í ____n_- .; i : ( ( 1 D-38 Event H ¡story Date Comment 11/19/03 PUMP HPBD TO INCREASE INJECTION RATE INTO THE A SAND. PUMPED 720 BBLS OF 50 DEG SEAWATER @ MAX RATE POSSIBLE (4.5 BPM AVERAGE) @ 4000 PSI. PUMP 4 STAGES WITH 15 MIN SHUT DOWNS IN BETWEEN STAGES. [HPBD] Page 1 of 1 12/11/2003 Permit to Drill 2000770 MD 14324..~ 'I-VD DATA SUBMITTAL COMPLIANCE REPORT 612/2003 Well Name/No. KUPARUK RIV UNIT 1D-38 Operator CONOCOPHILLIPS ALASKA INC 6533 v Completion Dat 5/3/2001 ~ Completion Statu 1WINJ Current Status 1WINJ APl No. 50-029-22961-00-00 UIC Y REQUIRED INFORMATION Mud Log N_po Sample N_.go Directional Survey ~ ~Z.~, DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt _ Interval Log Log Run OH I Name Scale Media No Start Stop CH (data taken from Logs Portion of Master Well Data Maint) Dataset Received Number Comments L L 0 FINAL -E~erification FINAL ~Dual GPJDEN/NEU 2/5 FINAL ~ Dual 2/5 FINAL GPJDEN/NEU ~/D Dual GPJRes 2/5 FINAL · 'l~0P/DuaI GR/Res 2/5 FINAL ~ RPT Cement Bond Log/ 5 FINAL SCMT/PSP 7177 14269 Case 13267 14324 CH 6291 6533 ch 4266 6533 CH 7177 14324 CH 0 14324 OH 13277 14253 CH 2/22/2001 2/23/2001 2/23/2001 2/23/2001 2/23/2001 2/23/2001 2/23/2001 8/15~2000 6/15/2001 q~991'0 7177-14269 ~.99'10 LIS Verification Digital Data LIS Verification Paper Copy 13267-14324 BL, Sepia 6291-6533 BL, Sepia 4266-6533 BL, Sepia 7177-14324 BL, Sepia SPERRY 0-14324. 13277-14253 BL Well Cores/Samples Information: Name Interval Start Stop Sent Dataset Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~) Chips Received? ~ Analysis ~ R e.c~.ivP, d? Daily History Received? ~/N Formation Tops (~/N Comments: Permit to Drill 2000770 DATA SUBMITTAL COMPLIANCE REPORT 6~2~2003 Well Name/No. KUPARUK RIV UNIT 1D-38 Operator CONOCOPHILLIPS ALASKA INC MD 14324 'I-VD 6533 Completion Dat 5/3/2001 Completion Statu 1WINJ Current Status 1WINJ Compliance Reviewed By: Date: APl No. 50-029-22961-00-00 UIC Y PK.,LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 October 22, 2001 Cammy Oechsli-Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1D-38 (200-077) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforation operations on 1D-38 If there are any questions, please contact me at 263-4574 or 659-7348. Sincerely, M. Mooney Wells Group Team Leader Phillips Alaska Inc. MM/skad RECEIVED Alaska 0il & Gas Cons. Commission Anchorage OF INAL 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 Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 504' FNL, 421' FEL, Sec. 23, T11 N, R10E, UM At top of productive interval 459' FNL, 2447' FWL, Sec. 36, T11N, R10E, UM At effective depth At total depth 795' FNL, 2749' FEL, Sec. 36, T11 N, R10E, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service_X (asp's 560670, 5959161) (asp's 563630, 5948673) (asp's 563716, 5948336) 6. Datum elevation (DF or KB feet) RKB 105 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 D-38 9. Permit number / approval number 200-077 / 300-274 10. APl number 50-029-22961 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 14324 feet Plugs (measured) 6533 feet Effective depth: measured true vertical Casing Length Size CONDUCTOR 148' 20" SURFACE 7104' 9-5/8" PRODUCTION 13522' 7" LINER 866' 3-1/2" LINER 14251 feet Junk (measured) 6506 feet Cemented 9 cu yds High Early 816 sxAS III Lite, 1041 sx Class (~ 190 sx Class G 200 sx Class G Measured Depth 148' 7209' 13627' 14324' True vertical Depth 148' 4279' 6290' 6530' Perforation depth: measu red 13970'- 14000' true vertical 6406'-6416' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 13458' MD. Packers & SSSV (type & measured depth) no packer CAMCO DS NIPPLE NO GO PROFILE @ 536' MD. RECEIVED OCT Alaska Oil & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas-Md Water-Bbl Injector Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations ._X Oil M Gas M Suspended Service _Water Injector X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, "-',.~'~':~,/~ z/~ ,/~//~'~ Title Wells Group Team Leader Michae/ Mooney Questions? Call Mille Mooney 263-4574 Date Prepared by Sharon Al~sup-Drake 263-4612 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE Date comment 1D-38 Event History 05/03/01 PERFORATE 13970'-14000' (30' OF TOTAL 45' PLANNED) 2.5" HSD, 31J U J, 4 SPF, DP. GOT STUCK AT SEAL BORE COMING OUT OF HOLE W/3RD GUN - HAD TO PUMP 2.5 BPM DOWN HOLE TO GET FREE, CONTINUED PUMPING 1.5 BPM. HAD EXCESSIVE DRAG COMING UP HOLE, LOST DRAG AT Page I of I 10/19/01 PH!_LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 July 16, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1 D-38 (200-077 / 300-274) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the stimulation treatment on the KRU well 1D-38. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Staff Engineer Phillips Drilling MM/skad i STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Per/orate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 504' FNL, 421' FEL, Sec. 23, T11 N, R10E, UM At top of productive interval 459' FNL, 2447' FWL, Sec. 36, T11 N, R10E, UM At effective depth At total depth 795' FNL, 2749' FEL, Sec. 36, T11 N, R10E, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service__X (asp's 560670, 5959161) (asp's 563630, 5948673) (asp's 563716, 5948336) 6. Datum elevation (DF or KB feet) RKB 105 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 D-38 9. Permit number / approval number 200-077 / 300-274 10. APl number 50-029-22961 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 14324 feet 6533 feet Plugs (measured) Effective depth: measured 14251 feet true vertical 6506 feet Casing Length Size CONDUCTOR 148' 20" SURFACE 7104' 9-5/8" PRODUCTION 13522' 7" LINER 866' 3-1/2" LINER Junk (measured) Cemented 9 cu yds High Early 816 sx AS III Lite, 1041 sx Class 190 sx Class G 200 sx Class G Measured Depth 148' 7209' 13627' 14324' True verticalDepth 148' 4279' 6290' 6530' Perforation depth: measu red 13970'- 14000' true vertical 6406'-6416' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 13458' MD. Packers & SSSV (type & measured depth) no packer CAMCO DS NIPPLE NO GO PROFILE @ 536' MD. RECEIVED JUL 1 8 2001 Alaska Oil & Gas Cons. Comrnission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) See attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Avera.qe Production or Injection Data Gas-Md Water-Bbl Injector Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil m Gas __ Suspended __ Service _Water Injector X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Carl Mike Mooney 263-4574 Signed ~ ,/~ Michael Mooney Title Staff Engineer Prepared by Sharon AIIsup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Comment 1 D-38 Event History 05/03/01 05/12/01 PERFORATE 13970'-14000' (30' OF TOTAL 45' PLANNED) 2.5' HSD, 31J U J, 4 SPF, DP. GOT STUCK AT SEAL BORE COMING OUT OF HOLE W/3RD GUN- HAD TO PUMP 2.5 BPM DOWN HOLE TO GET FREE, CONTINUED PUMPING 1.5 BPM. HAD EXCESSIVE DRAG COMING UP HOLE, LOST DRAG AT HIGH PRESSURE BREAKDOWN @ 40 BPM WITH HIGH PERF FRICTION- PUMPED 1837 BBLS WATER- 69 BBLS DIESEL- 7712 LBS 20/40 SAND-400 LBS SALT WITH 8600 PSI MAX PRESS.~ [ HPBD] Page I of I 3/26/~ MEMORANDUM State of'Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~' ~\6\ DATE: May 21, 2001 Commissioner' [ SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~~~ Phillips Alaska P.I. Supervisor/~'y'- ' ~ - / 1D & 1L Pads FROM: John Crisp Kuparuk River Unit Petroleum Inspector Kupamk River Field NON- CONFIDENTI ,AL Packer Depth Pretest Initial 15 Min. 30 Min. WellI '1D:38I Type,,i.I s 'I"T.V.D.i~ l~u~,.~l ~ooI ~oo! ~ooI~oo I~nte~va~'l '1 P.T.D.I '20,00770 ITY. petest,I P ' 'lTest,PSil' i561 I Casin,g]. 1700,'1."2700 I 2670' I, 2660. Notes: 'VVelll 1L'.1~, I'TyPelni.I "S''I T.v.'D.'I 5866 I Tubingl 2570'i'2570 I 25701 2576 I~nterva~l I "p.T.D.I 19P~,56 IType'testl P ITestpsil 146'7 I C,aSin~l , 0 ','1'~'20°0 I 19so'l 1950 Notes: /' -' we,/ ,, P.T,.D,.I Notes: ' WellI ' P.T.D.I Notes: JTypelnj. l' I T.V.D.'I' I TUbin~i !' '1 ' I i ' ' I'nter~'J" TypetestJ .... jT,est ps~! ,' "' I"¢as~n9 I' ",' I ' ,, .I "',,., I,,, "'1, PiE I., JTyPelni.l' I T.V.O.'I I Tubin~t ! "I I ' I J lntervalJ Type te.stl ,' , I Test psil, i ' I,'casingI. ' i. I .' ...... .! ', I, I . p/F I, ', Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N -- NOT INJECTING ,. Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details I witnessed 2 MIT's in Phillips KRU. No failures witnesed. Intell~l I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 2 Attachments: none Number of Failures: Total Time during tests: 3 hrs. .C.C: MIT report form 5112/00 L.G. MIT KRU 1D & 1L 5-21-01jc 5123101 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 20, 2001 RE: MWD Formation Evaluation Logs 1D-38, AK-MM-00086 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1D-38: c'D' 13D'~ [3Q Q 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22961-00 1 Blueline 1 Folded Sepia 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22961-00 1 Blueline 1 Folded Sepia 2" x 5" MD Neutron & Density Logs: 50-029-22961-00 1 Blueline 1 Folded Sepia 2" x 5" TVD Neutron & Density Logs: 50-029-22961-00 1 Blueline 1 Folded Sepia WELL LOG TRANSMITTAL To: RE: State of Alaska Alaska Oil and Gas Conservation Comm. February 1, 2001 Attn.' Lisa Weepie 333 West 7a~ Avenue, Suite 100 Anchorage, Alaska MWD Formation Evaluation Logs 1D-38 ,~ AK-MM-00086 1 LDWG formatted Disc with verification listing. AP1//: 50-029-22957-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Signed~t_~~l ~-) PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 October 19, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Application For Sundry Approval for 1D-38 (200-077) OCT 26 2000 Alaska 0il & Gas Cons. C0mm[.~.Oll grtchor~e Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Application for Sundry Approval for the temporary shutdown of 1D-38. This well is temporarily suspended until it can be completed with perforations. The perforating activity is tentatively scheduled the week of October 23, 2000. Please return the completion report submitted on October 5, 2000 and we will submit another one after the perforation job. If you have any questions regarding this matter, please contact me at 265-6434 or Todd Mushovic at 265-6974. Sir~erely,._______. James Trantham Drilling Engineering Supervisor PA1 Drilling JT/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _X Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance _ Perforate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service __X 4. Location of well at surface 507' FNL, 421' FEL, Sec. 23, T11 N, R10E, UM (ASP: 560671,5959159) At top of productive interval 459' FNL, 2447' FWL, Sec. 36, T11N, R10E, UM (ASP: 563630, 5948673) At effective depth At total depth 797' FNL, 2530' FWL, Sec. 36, T11 N, R10E, UM (ASP: 563716, 5948336) 6. Datum elevation (DF or KB feet) RKB 31' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 D-36 9. Permit number / approval number 200-077 / 300-157 10. APl number 50-029-22961-00 11. Field / Pool Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 117' Surface 7179' Production 13597' Liner 14288' 14324' feet Plugs (measured) 6533' feet 14251' feet Junk (measured) 6506' feet Size Cemented 20" 9 cu yds High Early 9.625" 816 sx AS III Lite, 1041 sx Class 7" 190 sx Class G 3.5" 200 sx Class G Measured Depth True vertical Depth 148' 148' 7210' 4279' 13628' 6290' 14319' 6530' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) Not Perforated Not perforated 3.5#, 9.3#, L-80 @ 13505' Baker ZXP packer @ 13465', No SSSV OCT 26 2000 Naska 0ii & Gas Guns. ~;ommissi0n ,k~chorage 13. Attachments Description summary of proposal m Detailed operations program m BOP sketch ~ Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic 14. Estimated date for commencing operation July 21,2000 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil__ Gas~ Suspended~X Service _ 17. I hereby certify th,{t the foregoing is true and correct to the best of my knowledge. Questions? Call Todd Mushovic 265-6974 ~ ', Signed ,,~ (~'"~,,~ I I~[f~. '~t'~'~' Title: Drilling Engineering Supervisor Date %1'[, J. Trantharn ' - Prepared by Sharon Al~sup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. . Mechanical lnt-e-grityTest_ -- Subsequent formreq--~iredlO-/,/O~ (~'~ p~~. ~,~-r ---. ,,-~RIGINAL SIGNED BY // Approved by order of the Commission '~' ~.. ~_,,,,-,.- o..~mC~Lillt Commissioner Date ~__~e ~_/!~'-' W | - - - "'" 1.,~-- ~ r,m]/l-~'. '- .... - .................................................................................. Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 2000 Dear Ms. Mahan: ,,"~,s~,,,,,., ,. ...... Please find reposed below the volumes injected into surface casing oy pmaucuon casing annuli during the third queer of 2000, as well as total volumes injected into annuli for which injection authorizmion expired during the third queer of 2000. Annular Injection during the third quarter of 2000: h(1) h(~) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 CD1-03 33505 100 0 33605 385 33990, 1D-14 33916 100 0 34016 1487.5 35503.6 CD1-25 24860 100 0 24960 8627 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 Ms. Wendy Mahan AOGCC Third Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during the third quarter 2000: ~,otal " Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CD1-39 31408 100 0 3 ! 508 Open, Freeze Protected 1D-12 32791 100 0 32891 Open, Freeze Protected CD1-37 32487 100 0 32587 Open, Freeze Protected CD 1-23 33886 100 0 33986 Open, Freeze Protected CD1-01 5121 100 0 5221 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CCi Marry Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kupamk Area Annular Injection, Third Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the third quarter of 2000, as well as total volumes injected into annuli for which injection . authorization expired during the third quarter of 2000. Annular Injection during the third quarter of 2000: ~ h(1)~ h(~) [(3) Totaifor Previous New Well Name Volume Volume Volume Quar~r Total Total CD1-45 5036 100 0 5136 365 5501 D CD1-03 33505 100 0 33605 385 33990 ? 1D-14 33916 100 0 34016 1487.5 35503.6 ~CD1-25 24860 100 0 24960 8627, 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 ~nnutar vtsposat aunng me tntra t~,uarter oj h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-27 28133 100 0 28233 3633 31866 June 2001 July 2001 1C-127, lC-117, lC-111, 1C-123 CD2-42 13465 100 0 13565 18134 31699 May 2001 July 2001 CD2-24, CD2-33 CD2-24 . 30443 100 0 30543 375 30918 June2001 Sept2001 CD2-33, CD2-39, CD2-14 2N-318 520 100 0 620 16978 17598 Dec 2000 July 2001 2N-314, 2N-302, 2N-332' 31453 100 0 31553 325 31878 Aug 2001 Sept 2001 2N-348, 2N-350 1C-16 19579 100 0 19679 0 19679 Sept 2001 Sept 2001 1C-102, 1C-131 1C-26 34160 100 0 34260 0 34260 Aug2001 Sept2001 1C-123, 1C-119, 1C-102 CD2-39 279 100 0 379 0 379 Sept 2001 Sept 2001 Freeze protect volume from CD2-39 CD2-14 276 100 0 376 0 376 Sept 2001 Sept 2001 Freeze protect volume from CD2-14 Total Volumes into Annuli ~or which Disposal Authorization Expired during the third quarter 2001: ' Total Voiume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus CD1-43 30937 100 0 31037 Open, Freeze Protected Jan 2001 Feb 2001 CD1-NQ1, CD1-21 2N-332' 225 100 0 325 Open, Freeze Protected July 2000 July 2000 Freeze protect 2N-332 only 2N-347 31540 100 0 31640 Open, Freeze Protected Sept 2000 Sept 2001 2N-349, 2N-305 1D-38 33907 100 0 34007 Open, Freeze Protected July 2000 Sept 2000 1D-30, 1D-40, 1D-141, ' 1D-36 1D-30 31622 100 0 31722 Open, Freeze Protected Sept 2000 Oct 2000 1D-36, 1D-34 2N-318 ' 17498 100 0 17598 Open, Freeze Protected Dec 2000 July 2001 2N-314, 2N-302 2N-316 240 100 0 340 Open, Freeze Protected Aug 2000 Aug 2000 Freeze protect 2N-316 '2N-332 was permitted for annular disposal the first time in July 2000 (300-187) and re-permitted (301-219) in August 2001. The volumes for the expired permit applies just to that permit. PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 October 5, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for 1D-38 (200-077/300-157) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on 1D-38. If you have any questions regarding this matter, please contact me at 265-6434 or Tom Brockway at 263-4235. Sincerely, James Trantham Drilling Engineering Supervisor PAI Drilling JT/skad STATE OF ALASKA {, ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas E] Suspended D Abandoned [--] Service ['~ Injector 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 200-077 /300-157 3. Address 8. APl Number P. O. BOX 100360, Anchorage, AK 99510,0360,,,,.,-.--~--,.-,--- r ~j ~: ," -:.."t-..','. :;,~'"-. 50-029-22961-00 4. Location of well at surface. ___ ______ ¥':'~-~ ~ 9. Unit or Lease Name r At Top Producing Interval 'i ..-'r'i~-~ ,,,, tl.. ~,~~;' 10. Well Number 459' FNL, 2447' FWL, Sec. 36, T11N, R10E, UM (ASP: 563630, 5948673) i .---~.--'---.~-~Jl ,:,~~,.~ 1D-38 At Total Depth 797' FNL, 2530' FWL, Sec. 36, T11N, R10E, UU (ASP: 563716, 5948336) 11. Field and Pool ---- Kuparuk River Field 5. Elevation in feet (Indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 31' feetI ADL 25661 & 25650 ALK 471 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions June 27, 2000 July 16, 2000 July 21,2000I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 14324' MD /6533' TVD 14251' MD /6506' TVD YES r~ No [~I N/A feet MD 1623' 22. Type Electric or Other Logs Run GR/Res/Neu Dens 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'Fi'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 148' 30" 9 cu yds High Early 9.625" 40# L-80 Surface 7210' 12.25" 816 sx AS III Lite, 1041 sx Class G 7" 26# L-80 Surface 13628' 8.5" 19o sx Class G 3.5" 9.3# L-80 13458' 14319' 6.125" 200 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 13505' 13465' None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A Date First Production Method of Operation (Flowing, gas lift, etc.) Injector Date of Test Hours lested Production for OIL-BBL C_~S-MCF WATER-BBL CHOKE SIZE IGAS-OIL RAIIO Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') press, psi :24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A .... ,.r,," .." ';. .... ': ~ '"' ' '/', ,1 ',,, ..... ~, .. :'!'~ .... . ., .., Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ F sui3mit in duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 13951' 6399' Base Kuparuk C 14000' 6416' Top Kuparuk A 14232' 6499' Base Kuparuk A 14324' 6533' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I he~ I~y certify that the following is true and correct to the best of my knowledge. Questions? Call Tom Brockway 265-4135 , S,gned ~.~ ~~ Title Ddllln.qEn.qineefin.qSupervlsor Date ~ 0~-,~1"" ~ J. Trantham INSTRUCTIONS Prepared by Sharon AIIsup-Drai~e General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 08/29/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:ID-38 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:06/27/00 START COMP: RIG:NABORS 16E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22961-00 06/08/00 (D1) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 150/150 (150) LAYING DERRICK OVER SUPV:FRED HERBERT/SCOTT GOLDBERG Clear off rig floor for rig move. Prepare rig for move. 06/09/00 (D2) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 150/150 ( 0) MOVING RIG MODULES SUPV:FRED HERBERT/SCOTT GOLDBERG Continue to break down rig modules and prepare for move. 06/10/00 (D3) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 150/150 ( 0) WASHING RIG SUPV:FRED HERBERT/SCOTT GOLDBERG Move both modules to KOC parking lot. Rig up and begin rig maintenance. 06/11/00 (D4) MW: 0.0 VISC: TD/TVD: 150/150 ( 0) RIG MAINTAINENCE SUPV:FRED HERBERT/SCOTT GOLDBERG Rig maintenance. 0 PV/YP: 0/ 0 APIWL: 0.0 06/12/00 (D5) TD/TVD: 150/150 SUPV:FRED HERBERT MW: 0.0 VISC: ( 0) RIG MAINTENANCE Rig maintenance. 0 PV/YP: 0/ 0 APIWL: 0.0 06/13/00 (D6) TD/TVD: 150/150 SUPV:M. WINFREE MW: 0.0 VISC: ( 0) RIG MAINTENANCE Rig maintenance. 0 PV/YP: 0/ 0 APIWL: 0.0 06/14/00 (D7) TD/TVD: 150/150 SUPV:M. WINFREE MW: 0.0 VISC: ( 0) RIG MAINTENANCE Rig maintenance. 0 PV/YP: 0/ 0 APIWL: 0.0 06/15/00 (D8) TD/TVD: 150/150 SUPV:M. WINFREE MW: 0.0 VISC: ( 0) RIG MAINTANENCE 0 PV/YP: 0/ 0 Continue with rig maintenance. APIWL: 0.0 Date: 08/29/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 06/16/00 (D9) TD/TVD: 150/150 SUPV:M. WINFREE 06/17/00 (D10) TD/TVD: 150/150 SUPV:M. WINFREE 06/18/00 (Dll) TD/TVD: 150/150 SUPV:M. WINFREE 06/19/00 (D12) TD/TVD: 150/150 SUPV:M. WINFREE 06/20/00 (D13) TD/TVD: 150/150 SUPV:M. WINFREE 06/21/00 (D14) TD/TVD: 150/150 SUPV:M. WINFREE 06/22/00 (D15) TD/TVD: 150/150 SUPV:M. WINFREE 06/23/00 (D16) TD/TVD: 150/150 SUPV:M. WINFREE 06/24/00 (D17) TD/TVD: 150/150 SUPV:M. WINFREE 06/25/00 (D18) TD/TVD: 150/150 SUPV:M. WINFREE MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 (0) RIG MAINTANENCE Continue with rig maintenance. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0 0 (0) MOVEING SUB TO iD PAD Finish rig maintenance and prepare to move rig. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0 0 (0) MOVING SUB TO 1-D PAD Moving rig from KOC to iD pad. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0 0 (0) MOVING RIG TO ID PAD Move rig to 1D pad. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0 0 (0) RIG MOVE TO iD Moving rig to iD pad. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0 0 ( 0) MOVING RIG DOWN iD ACCESS ROAD Moving sub module to ID. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0 0 (0) MOVING MOTOR COMPLEX TO 1D Move sub onto 1D pad. NU BOP stack. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0 0 (0) MOVING MOTOR COMPLEX Move motor complex to iD pad. RU diverter on 1D-38. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0 0 (0) RIGGING UP Move motor complex to iD pad, hold PJSM. Raise derrick and pin. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 (0) RU TOP DRIVE Rig up. Date: 08/29/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 06/26/00 (D19) TD/TVD: 150/150 SUPV:M. WINFREE MW: 9.5 VISC: 145 PV/YP: 40/38 0) EST SPUD 7:00AM APIWL: 9.6 Hold pre-spud meeting. Rig accept 1730 hrs. 6/26/00. 06/27/00 (D20) MW: 9.7 VISC: 285 PV/YP: 45/75 TD/TVD: 1069/1068 ( 919) DRILLING AHEAD SUPV:FRED HERBERT Drilling from 115' to 1069' APIWL: 7.4 06/28/00 (D21) MW: 10.0 VISC: 260 PV/YP: 60/75 TD/TVD: 2849/2676 (1780) DRILLING AHEAD, DEPTH = 3330' SUPV:FRED HERBERT APIWL: 7.2 Drilling from 1069' to 2003'. Circ densified sweep around. Monitor well. POOH to HWDP (1075'). RIH to bottom. Wash and ream last 90', no fill. Circ bttms up. Drilling from 2003' to 2285'. Change out derrick screens. Blinded off with tar. Drilling from 2285' to 2661'. Change out swab #1 MP. Drilling from 2661' to 2849' 06/29/00 (D22) MW: 10.0 VISC: 238 PV/YP: 45/51 APIWL: 6.8 TD/TVD: 4261/3343 (1412) DRILLING AHEAD, DEPTH 4510' SUPV:FRED HERBERT Drilling from 2849' to 4261'. Pump densified sweeps as needed. POOH to 1163'. tight spots @ 2761', 2666'. RIH. 06/30/00 (D23) MW: 10.1 VISC: 227 PV/YP: 48/66 APIWL: 5.4 TD/TVD: 5615/3775 (1354) CIRC FOR WIPER TRIP @ 6046' SUPV:FRED HERBERT RIH, fill pipe as needed. No problems while RIH. Circ bttms up @ 4261', circ out thick mud and clay. Drilling from 4261' to 4647'. ream out tight spot from 4642' to 4647' Drilling from 4247' to 5615' 07/01/00 (D24) MW: 10.1 VISC: 244 PV/YP: 49/62 APIWL: 4.6 TD/TVD: 6615/4088 (1000) TRIPPING FOR BIT. NOTE; HELD PAD EVACUATION DRILL W/ A SUPV:FRED HERBERT Drilling from 5615' to 6046'. Circ densified sweep around, monitor well, pump dry job. POOH to 4200' (no problems) RIH to bottom. Break circ slowly, monitor for losses. Drilling from 6046' to 6615' 07/02/00 (D25) MW: 10.1 VISC: 228 PV/YP: 45/60 APIWL: 4.4 TD/TVD: 7090/4238 ( 475) POOH FOR WIPER TRIP SUPV:FRED HERBERT Drilling from 6615' to 6674'. circ densified sweep, cond for trip. Monitor well, pump slug, POOH. No tight spots. RIH. Circ @ 2290', not getting full returns. Ream from 6530' to 6674' Drilling from 6675' to 6980'. Circ shakers Date: 08/29/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 running over packing off slightly. Drilling from 6980' to 7090' 07/03/00 (D26) MW: 10.2 VISC: 211 PV/YP: 42/55 TD/TVD: 7220/4279 ( 130) RUN 9.625" CASING SUPV:FRED HERBERT APIWL: 4.8 Drilling from 7090' to 7220'. Circ and cond mud for wiper trip. Pump densified sweep, circ hole clean. Monitor well, pump slug. POOH, swabbing @ 3609' Tight @ 1540'. RIH slow, monitor returns. Bridge @ 5450'. Circ and condition. Pump densified sweep. Monitor well pump slug. POOH to run casing, tight @ 5620' work thru tight spot. POOH. 07/04/00 (D27) MW: 10.0 VISC: 66 PV/YP: 26/24 APIWL: 6.2 TD/TVD: 7220/4279 ( 0) NIPPLE DOWN DIVERTOR STACK SUPV:FRED HERBERT Rig up to run 9.625" casing. PJSM. Run 9.625" casing. Break circ @ 2000'. Repair fill up tool. ('O' ring failure) Run 9.625" casing. Circ casing volume. 07/05/00 (D28) TD/TVD: 7220/4279 ( SUPV:FRED HERBERT MW: 9.2 VISC: 42 PV/YP: 11/13 0) TEST BOP'S APIWL: 9.6 PJSM. Pump cement. Displace cement. Good returns until 2500 stks. Lost returns @ 2520 stks. Continue to displace, did not bump plug. Check floats, OK. ND diverter. Run in to top job to 740', attempt to work down will not go past 740' Circ until returns clean. Pump cement. Good cement to surface. 07/06/00 (D29) TD/TVD: 7220/4279 ( SUPV:FRED HERBERT MW: 8.8 VISC: 43 PV/YP: 14/12 0) DRILLING @ 7467' APIWL: 8.4 NU BOPE and test. RIH w/8.5" drilling assembly. Tag cement stringers @ 7010'. Circ out cement contaminated mud. Clean out cement from 7010' to 7106' Circ for casing test. Test to 3000 psi, no loss. Drilling cement from 7106', tag fit collar @ 7137', tag shoe @ 7212' 07/07/00 (D30) MW: 9.0 VISC: 43 PV/YP: 14/12 APIWL: 5.6 TD/TVD: 8822/4785 (1602) CIRC SWEEP AROUND FOR WIPER TRIP @ 9389' SUPV:FRED HERBERT Drilling cement to 7220'. Drill new hole to 7240' Displace well with LSND mud. Perform LOT to EMW=13.5 ppg. Drilling 8.5" hole from 7240' to 7787'. Perform ECD baseline test. Drilling 8.5" hole from 7787' to 8822' 07/08/00 (D31) MW: 9.1 VISC: 40 PV/YP: 12/12 APIWL: 5.8 TD/TVD:10234/5231 (1412) DRILLING @ 10739' SUPV:FRED HERBERT Drilling 8.5" hole from 8822' to 9388'. Pump sweep, circ Date: 08/29/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 hole clean for wiper trip. Monitor well, pump slug and POOH to shoe. RIH to bottom. No problems. Break circ slowly. Drilling 8.5" hole from 9388' to 10234' 07/09/00 (D32) MW: 9.2 VISC: 41 PV/YP: 13/14 APIWL: 6.2 TD/TVD:l1737/5683 (1503) DRILLING @ 12288' SUPV:FRED HERBERT Drilling 8.5" hole from 10234' to 11267'. Circ weighted sweep, monitor well, pump slug. POOH to 9300'. No hole problems. RIH. Break circ slowly. Drilling 8.5" hole from 11267' to 11737' 07/10/00 (D33) MW: 9.8 VISC: 47 PV/YP: 19/20 APIWL: 5.2 TD/TVD:13100/6117 (1363) CIRC. ON BOTTOM (HOLE NOT TAKING PROPER FILL DURING TR SUPV:FRED HERBERT Drilling 8.5" hole from 11737' to 12583'. Circ out sweep. Attempt to survey (computer problems). Drilling 8.5" hole from 12583' to 12771'. Lost 500 psi pump pressure. POOH looking for washout (2200'). RIH. Take check shot @ 10996' Circ. Drilling 8.5" hole from 12771' to 12830'. Change out valve gaskets on MP's 1 & 2. Drilling 8.5" hole from 12830' to 13100' 07/11/00 (D34) MW: 10.1 VISC: 52 PV/YP: 24/22 APIWL: 4.4 TD/TVD:13209/6150 ( 109) DRILLING @ 13570 SUPV:M. WINFREE Drill from 13100' to 13209' Circ hole clean, pump weighted sweep for LOT, POOH 5 stds, improper fill, swabbing, RIH. Circ 2 BU, check well, small flow. Weight up to 109 and check well, OK. Perform OH FIT. EMW=12.3 ppg. 07/12/00 (D35) MW: 10.0 VISC: 51 PV/YP: 23/28 APIWL: 4.0 TD/TVD:13638/6296 ( 429) RUNNING 7" CSG SUPV:M. WINFREE Drill from 13209' to 13638' Circ bttms up. Check for flow. Make short trip. Pump hi visc sweep. Circ well clean. Observe well, POOH, check for flow. Pump dry job. 07/13/00 (D36) MW: 10.1 VISC: 48 PV/YP: 22/21 APIWL: 4.6 TD/TVD:13638/6296 ( 0) LD 5" DP SUPV:M. WINFREE RU to run 7" casing. Hold PJSM. Run 7" casing. PJSM. Pump cement. 07/14/00 (D37) MW: 10.9 VISC: 58 PV/YP: 31/27 APIWL: 4.2 TD/TVD:13638/6296 ( 0) PU 4" DP SUPV:M. WINFREE Displace cement w/calculated strokes, Did not bump plug. Install 7" pkoff and test to 50009, ok. PJSM. Test BOPs to 250/3500 psi. PJSM. Date: 08/29/00 ARCO ALASKA INC. WELL SIIMMARY REPORT Page: 6 07/15/00 (D38) TD/TVD:13638/6296 ( SUPV:M. WINFREE MW: 10.9 VISC: 60 PV/YP: 32/27 0) CHANGING OUT MUD TO 10.9 APIWL: 4.2 PJSM. tag cement at 13082', drill cement 13525'. CBU. Drill float equipment. 07/16/00 (D39) MW: 11.1 VISC: 49 PV/YP: 21/25 APIWL: 3.4 TD/TVD:14324/6525 ( 686) SUPV:M. WINFREE Drill float equipment & 18' new hole. Hole packed off at shoe. Circ. Perform FIT, EMW 13.9. Drill from 13637' to 14324' 07/17/00 (D40) TD/TVD:14324/6525 ( SUPV:M. WINFREE MW: 11.7 VISC: 52 PV/YP: 24/28 0) POOH W/ DP APIWL: 3.2 PJSM. RIH to 14233', break circ pressure high, hole taking fluid. POOH. Hole tight packing off. Circ & rotate, trip gas on BU. Wash and ream to 13800' tight and packing off. Pull back to shoe. Ream from 13626' to 14324'. POOH to 13626'. No problems. 07/18/00 (D41) MW: 0.0 VISC: 52 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:14324/6525 ( 0) RUNNING 3-1/2" LINER SUPV:M. WINFREE Monitor well. RIH. Break circ slow pump sweep, circ BU, wt up to 11.7 ppg. Check well, POOH to shoe, monitor well, pump dry job. POOH. PJSM. Run liner and packer. 07/19/00 (D42) TD/TVD:14324/6525 ( SUPV:M. WINFREE MW: 0.0 VISC: 52 PV/YP: 0/ 0 0) LD 4" DP APIWL: 0.0 RIH w/liner. PJSM. Pump cement. Bump plug. Set packer. PJSM. 07/20/00 (D43) TD/TVD:14324/6525 ( SUPV:M. WINFREE MW: 11.7 VISC: 73 PV/YP: 30/24 0) DISPLACE WELL TO SEAWATER PJSM. Run 3.5" tubing. APIWL: 4.5 07/21/00 (D44) TD/TVD:14324/6525 ( SUPV:M. WINFREE MW: 0.0 VISC: 73 PV/YP: 0/ 0 0) MOVING TO 1D-30 APIWL: 0.0 Run 3.5" completion. PJSM. Displace to seawater. Test tubing to 3000~. Displace tubing with diesel. ND stack. NU tree and test to 50009. Rig release @ 2130 hrs. 7/21/00 06-Aug-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 D-38 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 14,324.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, RECEI D Kenneth W. Allen Survey Manager Attachment(s) AU6 1 5 2000 Alaska 0il & Gas 6o,qs. Commission Anchorage North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-38 Job No. AKMMO0086, SURVEY REPORT 6 August, 2000 Your Ref: API.500292296100 Surface CoOrdinates: 5959159.04 N, 560670.82 E (70° 17' 56.3282" N, 210° 29' 28.8414" E) Kelly Bushing: 104.82ft above Mean Sea Level 13RI I,. L.I N Ci SEIRVI A Halliburton Company Survey Ref: svy9264 Sperry-Sun Drilling Services Survey Report for 1D-38 Your Ref: API-500292296100 Job No. AKMMO0086, North Slope Alaska Measured Depth (~t) 0.00 120.00 201.25 293.67 382.67 Incl. 0.000 0.000 0.150 0.250 0.260 Azim. 0.000 0.000 163.230 144.430 178.130 473.92 0.380 238.300 565.08 0.590 291.890 655.35 0.900 355,600 747.03 1.150 1.210 835.67 1.120 352.700 Sub-Sea Depth ffi) .104.82 15.18 96.43 188.85 277.85 369.10 460.25 550.52 642.18 730.81 Vertical Depth ffi) 0.00 120.00 201,25 293.67 382,67 473.92 565.07 655.34 747.00 835.63 929.02 1.150 18.310 824.14 928.96 1018,71 1.570 84.420 913.81 1018.63 1108.95 2.360 90.010 -1003.99 1108.81 1201.91 4.950 95.850 1096.76 1201.58 1295.97 8.000 93.740 1190.21 1295.03 1389.41 9.450 88.500 1282.56 1387.38 1482.46 11.070 94.170 1374.13 1478.95 1577.12 13.410 105.310 1466.64 1571.46 1670.92 16.040 107.530 1557.35 1662.17 1765.82 19.600 113.830 1647.69 1752.51 1859.12 20.360 115.840 1953.67 21.460 114.560 2049.83 24.220 122.720 2142.16 26.760 130.980 2236.17 28.300 136.160 1735.38 1823.70 1912.33 1995.70 2079.07 1840.20 1928.52 2017.15 2100.52 2183.89 Local Coordinates Northings Eastings (ft) (ft) 0.00 N 0.00 E 0.00 N 0.00 E 0.10 S 0.03 E 0.38 S 0.18 E 0.74 S 0.30 E 1.11 S 0.05 E 1.09 S 0.64 W 0.21 S 1.13 W 1.43 N 1.16 W 3.18 N 1.25 W 4.97 N 1.08 W 5.94 N 0.43 E 6.06 N 3.52 E 5.65 N 9.42 E 4.81 N 19.99 E 4.59 N 34.15 E 4.14 N 50.70 E 0.58 N 70.36 E 6.20 S 93.21 E 16.58 S 120.28 E 29.98 S 44.34S 62.32 S 86.20 S 116.16 S Global Coordinates Northings Eastings (ft) (ft) 5959159.04N 560670.82 5959159,04N 560670.82 5959158.94 N 560670.85 5959158.66N 560671.01 5959158.30 N 560671.13 5959157.93 N 560670.88 5959157.94 N 560670.19 5959158.82 N 560669.70 5959160.46 N 560669.65 5959162.20 N 560669.54 5959164.00N 560669.70 5959164.99 N 560671,20 5959165.13 N 560674.29 5959164.77N 560680.20 5959164.01N 560690.77 5959163.91N 560704.93 5959163.59 N 560721.48 5959160.19 N 560741.16 5959153.60N 560764.07 5959143.43N 560791.22 149.20 E 5959130.27 N 560820.25 179.74 E 5959116.16 N 560850.89 212.35 E 5959098.45 N 560883.64 243.99 E 5959074.82 N 560915.47 275.41E 5959045.12 N 560947.13 Dogleg Rate (°/lOOft) Alaska State Plane 4 Kuparuk 1D Vertical Section Comment E 0.00 E 0.00 0.00 E 0.18 0.11 E 0.13 0.42 E 0.17 0.79 E 0.37 1.08 E 0.52 0.88 E 0.92 -0.09 E 0.29 -1.68 E 0.19 -3.39 E 0.54 -5.08 E 1.70 -5.62 E 0.90 -4.92 E 2.81 -2.96 E 3.25 0.64 E 1.77 4.60 E 2.05 9.4O E 3.50 18.03 E 2.87 30,60 E 4,26 47.77 E 1.10 68.33 E 1.26 90.25 E 4.36 116.21 E 4.73 147.60 E 3.03 184.79 Continued... 6 August, 2000 - 12:04 - 2 - DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 1D-38 Your Reft API-500292296100 Job No. AKMMO0086, North Slope Alaska Measured Depth (it) Incl. 2330.06 31.140 2420.75 32.570 2516.38 34.400 2611.45 37.350 2706.10 40.880 2799.34 43.460 2893.17 46.450 2988.16 48,400 3081.52 48.410 3177.81 52.320 3272.37 53.950 3365.25 57.550 3460.42 59.960 3554.09 62.770 3648.44 65,820 3743.24 68.880 3836.34 71.010 3932.26 71.280 4024.64 71.610 4115.66 71,330 4210.82 71.840 4306.32 72.220 4396.68 70,760 4490.23 70.920 4586.58 70.750 Azim. 140.340 143,870 143.960 147.040 148.810 149.380 151.560 153.270 156.460 157.350 158.660 159.380 159.540 163.160 165.410 166.710 168.740 168.790 168.590 169.690 167.180 168.780 173.330 174.760 176.010 Sub-Sea Depth (ft) 2160.61 2237.65 2317,40 2394.44 2467.86 2536.96 2603.36 2667.62 2729.61 2791.02 2847.75 2900.02 2949.38 2994.28 3035.20 3071.70 3103,63 3134.63 3164.02 3192.95 3223.02 3252.48 3281.18 3311.89 3343.52 Vertical Depth (ft) 2265.43 2342.47 2422.22 2499.26 2572.68 2641.78 2708.18 2772.44 2834.43 2895.84 2952.57 3004.84 3054.20 3099.10 3140.02 3176.52 3208.45 3239.45 3268.84 3297.77 3327.84 3357.30 3386.00 3416.71 3448.34 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (it) (ft) (ft) (it) 150.91S 188.68 S 231.32 S 277.25 S 327.85 S 381.56 S 439.24 S 501.24 S 564.43 S 632.64S 702.78 S 774.46 S 850.65 S 928.53 S 1010.35 $ 1095.25 S 1180.70 S 1269.73 S 1355.61S 1440.37 S 1528.81S 1617.66 S 1702.27 S 1790,16 S 1880.87 S 306.33E 5959010.62 N 560978.33 E 335.69 E 5958973.09 N 561007.99 E 366.76 E 5958930.71 N 561039.40 E 398.26 E 5958885.04 N 561071.27 E 429.93 E 5958834.70 N 561103.35 E 462.07E 5958781.26 N 561135.92 E 494.71E 5958723.85 N 561169.02 E 527.09 E 5958662.12 N 561201.89 E 556.74 E 5958599.17 N 561232.04 E 585.80 E 5958531.21N 561261.65 E 614.13 E 5958461.30 N 561290.54 E 641.60 E 5958389.86 N 561318.59 E 670.14 E 5958313.91N 561347.75 E 696.39 E 5958236.25 N 561374.62 E 719.39 E 5958154.62 N 561398.28 E 740.46 E 5958069.90 N 561420.02 E 759,04 E 5957984.62 N 561439.29 E 776.72 E 5957895.74 N 561457.69 E 793.90 E 5957810.01 N 561475.56 E 810.16 E 5957725.40 N 561492.50 E 828.26 E 5957637.11 N 561511.32 E 847.18 E 5957548.43 N 561530.95 E 860.51E 5957463.94 N 561544.96 E 869.68 E 5957376.13 N 561554.84 E 877.00 E 5957285.49 N 561562.89 E Dogleg Rate (°/lOOft) 3.74 2.59 1.91 3.64 3.91 2.80 3.58 2.44 2.56 4,12 2.05 3.93 2.54 4.53 3.88 3.47 3.07 0.29 0.41 1.19 2.56 1.64 5.04 1.45 1.24 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 226.48 270.67 320.00 372.62 429.79 490.08 554.34 622.69 691,47 764.93 840.07 916.46 997.48 1079.53 1164.52 1251.97 1339.29 1429.83 1517.20 1603.23 1693.32 1784.01 1869.13 1956.32 2045.75 Continued... - 3 - DrillQuest 2.00.02 6 August, 2000 - 12:04 Sperry-Sun Drilling Services Survey Report for 1D-38 Your Reft API-500292296100 Job No. AKMMO0086, North Slope Alaska Measured Depth (it) 4680.66 4773.45 4868.87 4962.25 5057.08 Incl. 70.130 70.550 70.320 70.860 70.700 Azim. 177.090 178.390 179.360 180.350 180.710 Sub-Sea Depth (~) 3375.02 34O6.24 3438.19 3469.22 3500,44 Ve~ical Depth (fi) 3479.84 3511.06 3543.01 3574.04 3605.26 5151,28 74.290 177.170 3528.78 3633.60 5244.71 73.230 176.650 3554.91 3659.73 5339.91 72.270 177.580 3583.14 3687.96 5433.41 71.030 175.780 3612.58 3717.40 5527.10 71.560 177.100 3642.62 3747.44 5619.58 70.840 175.140 3672.43 5714.14 70.680 174.790 3703.59 5808.39 71.470 174.380 3734.16 5902.66 71.590 173.530 3764.02 5993.33 72.080 171.770 3792.29 6089.03 71.890 172.320 3821.89 6185.17 72.290 172.060 3851.45 6281.23 72.960 169.020 3880.15 6372.74 71.970 166.090 3907.72 6466.39 71.570 165.000 3937.02 3966.56 3995.87 4025.62 4055.59 4084.66 6560.14 7i.700 163.720 6653.39 71.660 163.790 6748.32 71.810 164.300 6842.75 71.190 166.550 6935.53 72.290 166.390 3777.25 3808.41 3838.98 3868.84 3897.11 3926.71 3956.27 3984.97 4012.54 4041.84 4071.38 4100.69 4130.44 4160.41 4189.48 Local Coordinates Northings Eastings (ft) (ft) 1969.36 S 2056.67 S 2146.56 S 2234.63 S 2324.17 S Global Coordinates Northings Eastings (ft) (ft) 2413.96 2503.53 2594.33 2682.92 2771.49 S S S S S 882.34 E 5957197.06 N 561568.94 E 885.78 E 5957109.79 N 561573.09 E 887.55 E 5957019.92 N 561575.58 E 887.77 E 5956931.86 N 561576.51 E 886.94 E 5956842.33N 561576.41 E 2858.83 2947.76 3036.52 3125.44 3210.88 888.63 E 5956752.56 N 561578.82 E 893.46 E 5956663.04N 561584.38 E 898.04 E 5956572.29 N 561589.69 E 903.17 E 5956483.75N 561595.54 E 908.68 E 5956395.24N 561601.76 E 3301.01 3391.64 3482.06 3567.25 3653.39 914.60 E 5956307.96 N 561608.38 E 922.44 E 5956219.10 N 561616.94 E 930.85 E 5956130.42 N 561626.07 E 940.27 E 5956041.60 N 561636.20 E 951.29 E 5955956.26 N 561647.91 E 3739.O6 3824.05 3910.73 3997.39 4083.05 963.89 E 5955866.24 N 561661.23 E 976.32 E 5955775.72 N 561674.39 E 991.39 E 5955685.43 N 561690.19 E 1010.18 E 5955600.40 N 561709.67 E 1032.39 E 5955514.46 N 561732.57 E 1056.37 1081.14 1105.92 1128.45 1149.07 E 5955428.98 N 561757.24 E E 5955344.21 N 561782.69 E E 5955257.74N 561808.17 E E 5955171.28 N 561831.40 E E 5955085.79 N 561852.70 E Dogleg Rate (°/lOOff) 1.27 1.39 0.99 1,16 0.40 5.23 1.25 1.37 2.26 1.45 2.15 0.39 0.93 0.86 1.92 0.58 0.49 3.10 3.24 1.19 1.30 0.08 0.53 2.35 1.20 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 2132.5o 2217.62 2304.78 2389.78 2475.92 2562.97 2650.63 2739.41 2826.21 2913.o9 2998.89 3086.73 3174.56 3262.80 3348.12 3438.38 3529.o7 3620.26 3707.39 3796.33 3885.30 3973.81 4O63.95 4153.49 4241.55 Continued... - 6 August, 2000 - 12:04 - 4 - DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 1D-38 Your Ref: API-500292296100 Job No. AKMMO0086, North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 7032.64 71.530 165.280 4114.81 4219.63 7122.75 71.29o 163.80o 4143.54 4248.36 7168.61 71.010 164.890 4158.36 4263,18 7245.21 71.280 161,610 4183,12 4287,94 7340.60 70.790 161,570 4214.12 4318,94 7432,03 7o.510 161.430 4244.41 4349,23 7527,03 70.260 163,450 4276,31 4381,13' 7621.76 70.430 163.730 4308,17 4412,99 7715.8o 71.15o 166,10o 4339,12 4443.94 7808.95 71,110 166,560 4369,24 4474,06 7904.67 70.940 167,070 4400,37 4505.19 7999.20 72.070 167.040 4430,35 4535.17 8090.78 72.410 167,150 4458,29 4563.11 8185.87 72.100 166.800 4487.27 4592,09 8280.63 71,830 167,140 4516.61 4621,43 8372.56 71.550 166,870 4545.49 4650.31 8465.94 72,730 166,560 4574.13 4678.95 8561.28. 72.690 166,380 4602,46 4707.28 8658.60 72.820 166,190 4631,31 4736.13 8750.94 72.450 166,58o 4658,87 4763,69 8843.43 72.100 166.610 4687,03 4791.85 8940,07 72.320 164.660 4716.56 4821,38 9034.69 71.97o 164.530 4745.57 4850.39 9120.20 71.680 164.740 4772,24 4877,06 9224,60 71,600 165,080 4805,13 4909,95 Local Coordinates Northings Eastings (~) (~) 4172,55 S 1171,65 E 4254,87 S 1194,42 E 4296,66 S 1206,13 E 4366,06S 1227,02 E 4451,65 S 1255,51E 4533,46 $ 1282,88 E 4618,77S 1309,88 E 4704,35 S 1335,08 E 4790,08 S 1358,19 E 4875,73 S 1379,02E 4963,86 S 1399,67 E 5051,23 S 1419,75 E 5136,24 $ 1439,23 E 5224,48 S 1459,64E 5312,26 S 1479,95 E 5397,30 S 1499,58 E 5483,80 S 1520.00 E 5572,31S 1541,30 E 5662,60 S 1563,34E 5748,26 S 1584,08 E 5833,96 S 1604,51 E 5923,09 S 1627,34E 6009.92 S 1651,26 E 6088,26 S 1672,79 E 6183.93 S 1698.58 E Global Coordinates Dogleg Northings Eastings Rate (fi) (fi) (°/lOOft) 5954996,48 N 561876,01 E 5954914.36 N 561899.43 E 5954872,67 N 561911,48 E 5954803,45 N 561932,93 E 5954718,09 N 561962.11 E 5954636,52 N 561990,13 E 5954551.44N 562017,82 E 5954466,07N 562043,71 E 5954380,54 N 562067.50 E 5954295,07N 562089.02 E 5954207.11 N 562110.38 E 5954119,92 N 562131.16 E 5954035.08 N 562151,33 E 5953947,02 N 562172.45 E 5953859,41 N 562193.47 E 5953774,54 N 562213,78 E 5953688.21 N 562234,90 E 5953599,89 N 562256,91E 5953509,79 N 562279,67 E 5953424,31 N 562301,10 E 5953338,79 N 562322,22 E 5953249,85 N 562345,76 E 5953163.22 N 562370.38 E 5953085,07 N 562392.54 E 5952989,62 N 562419,11 E 1.34 1.58 2.33 4,07 0.52 0,34 2,02 0.33 2.50 0.47 0.53 1,20 0,39 0,48 0.44 0,41 1,30 0.19 0.23 0.57 0.38 1.93 0.39 0.41 0.32 Alaska State Plane 4 Kuparuk 1D vertical Section comment 4333.84 4419.25 4462,65 4535,10 4625,18 4711.31 4800,73 4889.92 4978.72 5o66,82 5157.28 5246.85 5333.99 5424.48 5514.51 5601.71 5690.54 5781.52 5874.43 5962.52 6050.57 6142,58 6232.64 6313,88 6412.97 Continued... 6 August, 2000 - 12:04 -5- urillQuest 2,00, 02 Sperry-Sun Drilling Services Survey Report for 1D-38 Your Reft API-500292296100 Job No. AKMMO0086, North Slope Alaska Measured Depth (It) Incl. Azlm, Sub-Sea Depth (It) Vertical Depth (It) 9316.90 71.290 164.480 4834.50 4939.32 9409.70 71.160 164.150 4864.37 4969.19 9501.78 70.900 164.770 4894.30 4999.12 9595.13 70.500 165.070 4925.16 5029.98 9690.99 71.630 165.300 4956.26 5061.08 9784.79 71.590 165.270 4985.85 9880.27 71.480 165.730 5016.09 9975.50 71.190 166.260 5046.57 10068.14 71.740 165.270 5076.02 10163.41 71.910 164.660 5105.74 10256.97 71.990 165,520 5134.73 10349.12 71.730 165.340 5163.42 10442.10 71.620 164.920 5192.65 10537.40 71.620 165.190 5222.70 10633.21 73.240 163.640 5251.62 5O90.67 5120.91 5151.39 5180.84 5210.56 5239.55 5268.24 5297.47 5327.52 5356.44 10722.53 73.470 162.770 5277.21 5382.03 10821.18 73.050 163.070 5305.62 5410.44 10913.44 72.790 162.760 5332.72 5437.54 11009.46 72.780 163.090 5361.14 5465.96 11102.79 72.870 162.780 5388.70 5493.52 11192.14 72.700 162.910 5415.14 11289.11 72.490 163.530 5444.15 11382.25 72.370 163.460 5472.26 11474.19 72.350 164.180 5500.13 11568.22 72.040 165.610 5528.88 5519.96 5548.97 5577.08 5604.95 5633.70 Local Coordinates Northings Eastings (It) (ft) 6268.36 S 6352.95 S 6436.85 S 6521.92 S 6609.57 S Global Coordinates Dogleg Northings Eastings Rate (fi) (fi) (°/lOOff) 1721.55 E 5952905.38 N 562442.76 E 1745.31 E 5952820.99 N 562467.19 E 1768.64E 5952737.30 N 562491.19 E 1791.56 E 5952652.43 N 562514.80 E 1814.74 E 5952564.97 N 562538.69 E 6695.66 6783.34 6870.88 6956.02 7043.43 1837.35 E 5952479.07 N 562561.99 E 1860.03E 5952391.58 N 562585.37 E 1881.86 E 5952304.23 N 562607.91 E 1903.46 E 5952219.28 N 562630.19 E 1926.94 E 5952132.07 N 562654.37 E 7129.39 7214.15 7299.46 7386.84 7474.81 7556.74 S 7647.04 S 7731.34 S 7819.01 S 7904;26 S 7985.81S 8074.39 S 8159.53 S 8243.68 S 8330.11S 1949.83 E 1971.86 E 1994.51E 2017.83 E 2042.38E 2067.10 E 2094.85 E 2120.76 E 2147.69 E 2173.86 E 2199.03E 2225.75 E 5952046.30 N 562677.95 E 5951961.74N 562700.66 E 5951876.62 N 562724.00 E 5951789.44N 562748.03 E 5951701.68 N 562773.28 E 5951619.96 N 562798.66 E 5951529.89 N 562827.14 E 5951445.82 N 562853.72 E 5951358.37N 562881.36 E 5951273.35 N 562908.21 E 5951192.01 N 562934.04 E 5951103.65 N 562961.46 E 562987.37 E 563012.46 E 563036.49 E 2250.97 E 5951018.73 N 2275.39 E 5950934.79 N 2298.72 E 5950848.56 N 0.70 0.36 0.70 0.52 1.20 0.05 0.47 0.61 1.17 0.63 0.88 0.34 0.44 0.27 2.29 0.97 0.52 0.43 0.33 0.33 0.24 0.65 0.15 0.75 1.49 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 6500.47 6588.33 6675.41 6763.51 6854.18 6943.18 7033.74 7123.93 7211.75 7302.26 7391.22 7478.78 7567.o4 7657.48 7748.81 7834.36 7928.78 8o16.93 8108.61 8197.73 8283.04 8375.54 8464.31 8551.92 8641.44 Continued... 6 August, 2000- 12:04 - 6 - Dr#/Quest 2.00.02 Sperry-Sun Drilling Services Survey Report for 1D-38 Your Reft API-500292296100 Job No. AKMMO0086, North Slope Alaska Measured Depth (ft) 11663.32 11760.21 11853.98 11947.18 12040.22 Incl. 71.91o 71.68o 71.88o 71.90o 71.81o Azim. 165.82o 165.29o 164.990 164.93o 164.240 Sub-Sea Depth (~) 5558.31 5588.58 5617.90 5646.87 5675.84 Ve~ical Depth (fi) 5663.13 5693.40 5722.72 5751.69 5780.66 12134.55 71.880 164.930 5705.23 5810.05 12223.91 71.790 165.000 5733.09 5837.91 12323.56 71.710 165.810 5764.30 5869.12 12416.96 71.710 165.100 5793.61 5898.43 12511.12 71.710 164.790 5823.16 5927.98 12604.17 71.690 165.050 5852.38 5957.20 12697.75 71.680 165.180 5881.78 5986.60 12792.51 71.600 165.590 5911.63 6016.45 12885.91 71.570 165.720 5941.14 6045.96 12979.27 71.300 165.540 5970.86 6075.68 6001.88 6031.78 6063.28 6O94.34 6125.92 13075.54 71.110 165.730 13167.62 70.990 165.160 13264.04 70.870 165.400 13357.92 70.500 165.400 13451.39 70.000 165.150 6106.70 6136.60 6168.10 6199.16 6230.74 13547.15 69.840 164.840 6158.80 6263.62 13681.97 69.760 164.960 6205.35 6310.17 13775.59 71.270 164.740 6236.58 6341.40 13872.17 70.630 165.380 6268.10 6372.92 13967.33 70.220 164.450 6299.98 6404.80 Local Coordinates Global Coordinates Dogleg Northings Eastings Northings Eastings Rate (fl) (fl) (fl) (fl) (°/lOOfl) 8417.74 S 2321.03 E 5950761.12 N 563059.51 E 8506.87 S 2343.99 E 5950672.18 N 563083.18 E 8592.96 S 2366.83 E 5950586.29 N 563106.72 E 8678.51S 2389.82 E 5950500.94 N 563130.39 E 8763.74 S 2413.32 E 5950415.90 N 563154.58 E 8850.15 S 2437.14 E 5950329.70N 563179.10 E 8932.15 S 2459.17 E 5950247.89 N 563201.78 E 9023.74S 2483.02 E 5950156.51N 563226.36 E 9109.57 S 2505.29 E 5950070.86 N 563249.33 E 9195.91S 2528.51 E 5949984.72 N 563273.24 E 9281.21S 2551.49 E 5949899.62 N 563296.91E 9367.07S 2574.32E 5949813.96 N 563320.42 E 9454.09 S 2597.01 E 5949727.12 N 563343.82 E 9539.95 S 2618.96 E 5949641.46 N 563366.46 E 9625.68 S 2640.93 E 5949555.91N 563389.12 E 9713.97 S 2663.54 E 5949467.82 N 563412.44 E 9798.26 S 2685.43 E 5949383.71 N 563435.00 E 9886.40 S 2708.58 E 5949295.78 N 563458.86 E 9972.13 S 2730.91 E 5949210.23 N 563481.89 E 10057.22 S 2753.27 E 5949125.34N 563504.93 E 10144.09 S 2776.56 E 5949038.67 N 563528.91 E 10266.25 S 2809.52 E 5948916.79 N 563562.86 E 10351.44S 2832.59 E 5948831.80 N 563586.61 E 10439.64 S 2856.12 E 5948743.80 N 563610.85 E 10526.21 S 2879.46 E 5948657.43 N 563634.88 E 0.25 0.57 0.37 0.06 0.71 0.70 0.13 0.78 0.72 0.31 0.27 0.13 0.42 0.14 0.34 0.27 0.60 0.27 0.39 0.59 0.35 0.10 1.63 0.91 1.02 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 8731.86 8823.89 8912.95 9001.54 9089.95 9179.58 9264.49 9359.12 9447.79 9537.19 9625.53 9714.37 9804.30 9892.90 9981.39 10072.52 1O159.6o 10250.72 10339.31 10427.28 10517.22 10643.74 lO732.oo 10823.29 10912.94 Continued... 6 August, 2000 - 12:04 -7- DrillQuest 2. 00. 02 Sperry-Sun Drilling Services Survey Report for 1D-38 Your Reft API-500292296100 Job No. AKMMO0086, North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 14063.02 69.390 165.620 6333.02 6437.84 10612.97 S 2902.65 E 14159.15 69.040 166.130 6367.13 6471.95 10700.12 S 2924.58 E 14255.02 67.900 167.460 6402.32 6507.14 10786.94 S 2944.96 E 14324.00 67.900 167.460 6428.27 6533.09 10849.33 S 2958.83 E Global Coordinates Northings Eastings (ft) (ft) 5948570.87 N 563658.77 E 5948483.90 N 563681.41 E 5948397.26 N 563702.48 E 5948334.99 N 563716.86 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 164.680° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14324.00ft., The Bottom Hole Displacement is 11245.56ft., in the Direction of 164.745° (True). * Grid Coordinate Scale Factors have been apPlied to all local coordinates. Dogleg Rate (°/100ft) 1.44 0.62 1.75 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 11002.75 11092.60 11181.72 11245.55 Projected Survey Continued... 6 August, 2000.12:04 -8- DrillQuest 2. 00. 02 Sperry-Sun Drilling Services Survey Report for 1D-38 Your Re f: API-500292296100 Job No. AKMMO0086, North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (~t) (~t) (~t) (ft) 14324.00 6533.09 10849.33 S 2958.83 E Projected Survey Survey tool program From To Measured Vertical Measured vertical Depth Depth Depth Depth (fi) (~t) (ft) (fi) 0.00 0,00 14324.00 6533.09 Survey Tool Description MWD Magnetic 6 August, 2000 - 12:04 -9- DrillQuest 2. 00. 02 SENT BY: Phone:263-4612 7-01- 0 ' 3:33PM ' PHILLIPS AK INC~ 907 276 7542:# 1/ 2 Fax To: Mr. Wondzell From: Sharon AIIsup-Drake F~,x: 9-907-276-7542 Date: July 31,2000 Phon~ Pages: 2 Re: 1D-38 Sund~/attachments Cc: I-1 Urgent [] For Review [] Please Comment [] Please Reply D Please Recycle ,Comments: Mr. Wonclzell, Here are the attachments to the Sundry Application of 1 D-38. Thanks, Sharon SENT BY' 7-31- 0 ' 3:33PM ' PHILLIPS AK INC~ 907 276 7542;~ 2/ 2 Phillips Alaska Drilling Cementing Details Well Name' 1'l~-3~ Rrq~rt Date: 07105/2DO0 ReDOA Nufflber; 25 AFC No,: AK0093 Field.' KRU C8~lng SizB Hole Dlameleff. I A~g~o thru K~U: Shoe Dep~: LC De~: % ~heut: 9.625' 12.2~ ~ ~ 7136 ,,. . C~m~: O~ centrllEer ~ Jori on JoMts 1-15. ~e ~nBIIEer e~ ~ber j~nl//Joint 17 to ~nt 1~ a one olnl 1-3 w~le oN atop eoil~ In ~a middle of I~ Jo~te. .. MUd "' Weight: PV~r~r co~}: PV(aflar con~: YP(prior ~n~: YP(a~r , Co~en~: 10,0 S~ 2S ~8 Gal~ b~om: ~3 ~o~ T~I Vulu~ Cl~ulate~: a~2 ~8 29~ bDla , , i ,~. ~eM8: AR~ ~O Col~m~: Ag III LEe ......] 80 ~._ 816~ .10'7 ....... Additivm;: Cla~ 'G' wi 6~ D124, ~% D~ 0,4% D46~ 3~ D~ 1.5% S1,1,5% D~, TMI Cel~ 0 T~m Mix ~r 1omp: N0, ~ S~kS; Wel~ld: Yield: Cemmenls= G 80 1~1 15,B 1.17 .,. , . A~dlllvee: Claee ~G' wi 0,5% ~ ~.2% D4~, 0.3%. DS6, 0~% D167, ,. ,,..-. ~.. ,,- D~plg~em~nl 0 Rate(b~m~ ~ail at ~hoe)~ R=~u[lail ar~n~ a~oe)'. Str, Wi, Up: C~mun~'. ? bpm ~ bpm , , . 31~k ., .... R~etlon I~: Heelpmemi~n ~pood: ~{r. ~. Down: 15' 20 fpm .,.,,.. , _ ,,,, Thoomlic81 Dia~lecem~t; ~u~ Dlspl~emenl: ~tr. WL in C81cul~od top of cDmatt[ UP: Bumpe$ plug: Floats held: ~, Date:~lO5~0 No Yea .... .... ,,. r Remar~:Ca~lng ran g~o with tull dbplK=menl & no trouble when =lmul~9 wi running ~alng, Circuited on bMtem e 8 bpm wi 750 pal w~h no I=~ea. Reclp callng until drappMg Top ~ug, Had gee= r~urna until 2~ I~O~l I~0 ~lgpla~nt. Lod ~omplete ~Turne ~ 2520 stm~s. Conll~ed dlepl~m~t uflable W regain any mluma. FIM~ was mwndina full ~ the annulus. Did not bump , .... i , ,, , ?....; ',, l cement Company: I Rig Contractor; l^pproved By: , [Dowell [NABOR$ IFred Herbert STATE OF ALASKAi'_' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X Annular Injection 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service __X 4. Location of well at surface 507' FNL, 421' FEL, Sec. 23, T11N, R10E, UM (ASP: 560671,5959159) At top of productive interval At effective depth At total depth 863' FNL, 2349' FWL, Sec. 36, T11 N, R10E, UM (ASP: 563536, 5948268) 6. Datum elevation (DF or KB feet) RKB 35' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 D-38 9. Permit number/approval number 200-077 / 300-157 10. APl number 50-029-22961-00 11. Field / Pool Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 7174' Production 13592' Liner 861' 14324 feet Plugs (measured) 6533 feet 13627 feet Junk (measured) 6290 feet Size Cemented 20" 9 cubic yds High Early 9.625" 816 sx AS III Lite, 1041 sx Class G 7" 190 sx Class G 3.5" 200 sx Class G Measured Depth TrueverticalDepth 115' 115' 7209' 4279' 13627' 6290' 14319' 6530' Perforation depth: measu red true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) None None 0RI61NAL 3.5#, 9.3#, L-80 @ 13505' Baker ZXP packer @ 13465', No SSSV 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic __ XI 14. Estimated date for commencing operation August 1,2000 16. If proposal was verbally approved (~,. ~,~,~,¢. (~ me of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service 17. I hereby~ertify that the foregoing is true and correct to the best of my knowledge. -- Signed . ~ /,~ ~,,.. Title: Drilling Engineering Supervisor J~an~am Questions? Call Tom Brockway E6'5-4135 Prepared b~/ Sharon AIlsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance _ Mechanical Integrity Test_ Subsequent form required 10- Approved by order of the Commission :IR1GINAL SIGNED BY 'Taylor Seamount Commissioner Date ~'"' ¢'~""' O0 Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE CASING TEST and FORMATION INTEGRITY TEST Well Name: 1 D-38 Date: 7/7/00 Reason(s) for test: Supervisor: Fred Herbert [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9.625", 40#, L-80, BTC Casing Setting Depth: 7,209' TMD Hole Depth: 4,279' TVD Mud Weight: 8.8 ppg Length of Open Hole Section: 7,240' TMD 4,286' TVD 31' EMW = Leak-off Press. + Mud Weight = 1,050 psi 0.052 x TVD o.o52 x 4,286' EMW for open hole section = 13.5 ppg + 8.8 ppg Pump output = 0.0846 bps Fluid Pumped = 6.4 bbl 3,200 psi 3,100 psi 3.0OO psi 2,900 psi 2,800 psi 2,700 psi 2,dO0 psi 2,500 psi 2,400 psi 2,300 psi 2.200 psi 2,]00 psi 2,000 psi ],gO0 psi 1,800 psi 1,700 psi ] ,600 psi ],500 psi ],400 psi '1,300 psi 1,200 psi 1,]00 psi ],000 psi gO0 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi ]00 psi 0 psi , I I : i ; ~ -.I-.I.,~t~.1.~1..I I I ~--~--LEAK-OFFTEST I r T i i ; i ' i ; ....~*~*~'~'~"¢'"";~1 J ' --~--CASINGTEST i' i i ~_~__,~,%~_ : I ' ~;?'~LOTSHUTINTIME ! I !_~ _ I I ! I I I I III :"/L._!.. :1 I,II1~, CAS NG TEST SHUT IN TIME I I I I i '~ ' '" ' ,I I I i I i I I t I I 'fflMELINE I I I I i I I I I TIME LINE I i I I I . nNFMNHTFTn~g I I I ! i f i I I I..-----. ....: ...... ~ I I I I I I I I ! I I i ' ~ i : ;--i ! i ! I I I I i ! I i / I I I I I I I I I I I i I I~ I , : ' ' ' ; L I I l~ I i ! I I I~'~q i ! ! ! .i .i_j. ! ! I I ¥ I I ! I ! I I I i ! .... ~--~ ~'i ~ I I J _, ':.: I I I ~1 I I I I I I I I I I I i -i ; i": '" : I I I I I ! I I I~ I I I I I I I I I I i I I I f ; i ~" · ~ ! I I STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE i ................ ..... iri,-a- .... i ..................... ......... .... : i ................................................ t- ............................................. -.- ---i 4 stks 75 psi : 5 stks 100 ps~ i ................ J- ............... · ................. .~ ~- ................ ~ ............... '~ ................. , _8__s__t_k__s_ ....... _l__2__5___p_s_L_j 10 stks 225 psi ................ ~---:12 stks j 300 psi i .................... -1-~'~¥1~'-' ................ i---:1-~--~ .....~,:~,--I~-~i'- ' i ................... ~-~:t-I~'-' 625psi i T i ~i~--~'~i ] ................. ~ .................... i,-~'f'-i .................. ~--~i~ ........ 25 stks r- ............................... .1 ................. ................ i___2__4__s__t~_s_ ...... _7__~_o___p_s_!___j ................... ~.O___s_t_k__s_ ..... !,_O__O_O___p__s~,~ ................. i___~_.~_.s__t~.s_ ...... ~_s__o___p_s_!___j .................... ~_s___s_tk._s- ..... _!,_~Zs___p__,-_. .................... _~_?_.s_!~.s_ ...... ~Z_s_._p.s_!___] ..................... ~_o___s_~&s_ ..... !,_3__o_o___p_.s_i__. .................... ~.%s__t~.s_ ..... _t,__o_2__s._p__s.i__i .................... _4__s___s_tk__s' ..... !_,_4._s_o___p_.s_L. .................... .4_9_.s__tk_.s- ..... !,__o_s__o__p__s. Li ................... _S__0___s_t_k__s_ ..... !,_s__s_o_._p_.s_L. .................... .4_.4_.s__t.k_.s_ ..... .l_ ,. _0_5_ .0_ _ .p_ _s. i_ _i 55 stks 1,750 psi ..................... .4_.~_.s__t.k_.s_ ..... !,._0.2_.5__p__s. Lj .................... _6__O___s_t_k__s_ ..... !,_~__2_s_._p_.s_L., 52 stks 1,000 psi j 65 stks 2,025 psi j ................ -,- ............... ~ ................. .~ ~. ................ ~. ............... .~ ................. 56 stks 1,000 psi i 70 stks 2,150 psi ! i ................................. .[ ................. .~ ! ................................................... .................... .6_9_.s_!~.s_ ..... !,__o.o__o__p__s.i__i .................... Ls___s_~_s_ ..... _2_,_~__2_s__p_.s_i__] .................... .6_.4_.s__t.k_.s_ ..... .l_,._O.O_.O__.p__s.i__i 80 stks 2,500 psi ! ................... .6_.~_.s__t.k_.s_ ..... !,._o.o_.o__p__s. Lj .................... ~__s_t_k__s_ ..... _2_,?__o_o___p_.s_i__~ .................... ?..2_.s__t~.s_ ..... !,__o.o_.o__p_.s. Lj .................... ~_o___s_t~_s_ ..... _2.,_~__2_5___p..s_L 76 stks 1,000 psi i 95 stks 3,050 psi ................ · .~ ............... · ................. .~ i I I ~ SHUT IN TIME SHUT IN PRESSURE , .................................. ................................................... ~ 1.0 min 3,000 psi i '- .......................................... i ' - 'a~)'"'.'(~ - ~"~-i-r~---r .................. ~;b-6-6'~; ! s. UT,. T,ME SHUT,. P.ESSU,E ___3:.0___mj_n_ ...................... _3_.9_0_0___p..S_;_~ [ ................ .4- ............... ~ ................. 0.0 min 1,000 psi i 4.0 min 3,000 psi i ................ ~ ............... .~ ................. .~ , ................ ~. ............... .i ................. 1.0min . . 950 psi i 50min 3,000 psi i ................................................... - .... L' ............................................. -{ __ _ _2_ . _o__ _m_ Ln' ....................... .9_.o_.o_._p.s_L_i . __ _6:.o__ _m_ !n_ ...................... ~,_o__o.o__.p_.s_Li __ _ _3_ : _O_ _ _m_ j _n_ ...................... .8_.7__.5_._p_s_!___i 7.0 min 3,000 psi i -! ____4_._o__m ...................... ::::::::::::::::::::::::::::::::::::::::::::::::: .... _5_ : _o_ _ _m_ j _n_ ...................... .8_.o_.o_._p.s_L_j ~____9_._o___m__i_n_ ................... j___3_,_o__o.o__ p_.s_[_ j __ _ _6_ . _o_ _ _m_ j _n_ ...................... .7_Z.5_._p.s_]___j ..__l__O:_O___m_j_n_ .................. j___3_,_o__o.o__ p__s_i__ j 7.0 min 725 psi i15.0 min i 3,000 psi i .... E6"~iR- ....................... ~iB-'~'ii_~_9_._o___mj.n_ ................. i___3_._o__og___p__s_L i ......................................9.0min ~6~"~,'~i"-i ....~..5:.o...m.j.n. .................... j ~,_o._o.o__~RL ::::::::::::::::::::::::::::::::::::::::::::::: .................. NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1 D-38 Date: 7/11/00 Reason(s) for test: Supervisor: m.winfree [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9.625", 40#, L-80, BTC Casing Setting Depth: 7,209' TMD Hole Depth: 4,279' TVD Mud Weight: 10.0 ppg Length of Open Hole Section: 13,209' TMD 6,150' TVD 6,000' EMW = Leak-off Press. + Mud Weight = 725 psi 0.052 x TVD 0.052 x 6,150' EMW for open hole section = 12.3 ppg + 10.0 ppg Pump output = 0.0846 bps Fluid Pumped = 6.3 bbl 3,200 psi 3 100 psi I I I I I I I I 3:000 psi ~ LEAK-OFF TEST zmo psi 2 800 ps ~'~ ppSsi ..... '-"~'""- LOT SHUT IN TIME ~,..~ ~,,. I -~--CASING TEST SHUT IN TIME ~'~o ppSs: ..... · ^'.~ I I I I I I I I I I Z, I UU pSI , 2,030 ps' 1 mo ~si I · ~' 1,800 psi ' ]'500 psi i ~'400 psi ]'mOp~ I I ~'ooo i · pS · 900 psi I J ~p,i ' 7oo P~ ~~ , .......... ~r~ .,600 ps ~~ .'¢~ P~ I J J I I I I I --1~"d"~ I 4uupr~ ~oo-¢ STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE , ................ .~ ................ ~ ................. 0 stks 0 psi i ................................. + ................. ..................... .5_.s__tk__s_ ......... _0__R_s_i_ ..... .................... l_O__s__Lk__s_ ...... j__4__o___p_s_] .... .................... l_5__s__Lk__s_ ..... _2__o__o___p_s_] .... .................... .2_.0_.s__Lk__s_ ...... _2.Z_o___P_sj .... ................... _2..S_ ?__t.k__s_ ...... ~_2__5___p_s_] .... ..................... _3__o_.s__Lk__s- ...... &7__5___p_s_] .... ................... .~__s__s__Lk__s- ...... _4_ _5_ p_ _ _p_sj .... ..................... .4_.o_.s__Lk__s_ ...... _5__0__0___p_s_] .... .................... .4_f_?__t_k__s_ ...... 9.Z_s___p_s_] .... .................... _5_ _0_.s__Lk__s_ __, __ _ ~_2_ _S_ _ _P_S_ ] .... .................... .S_.5__s__Lk__s_ ...... _6__7__5___p_sj .... 60 stks 725 psi i ................................. ,i, ................. ................... _~__S__s__t~_s_ ...... _6_ _5_ _0_ _e_s_ ! .................... _7__o__s__Lk__s_ ...... ~_2__5___p_s_] .... .................... Z_s__s_!_k__s_ ...... ~_o__o___p_sj .... l 1' i ................ · .i- ............... + ................. , i ! ................................................. J ! SHUT IN TIME SHUT IN PRESSURE ___.o_:.o_..m_Ln' ...................... __6_o__o___p_s_! .... .... j_ : .o_ . .m_ !_n_ ....................... ~_4__2___p_s_] .... 2.0 min 533 psi .__~:.o_..m_!.n_ ...................... _5_j__~___p_s_! .... ___.4_:.o_..m_!.n_ ...................... _s_ j_ _e_ __p_s_ ! .... 5.0 mJn 6.0 min 7.0 min , ................ .J.. ............... z ................. ,i CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE 0 stks 0 psi i- ................ i- ............... .~ ................. ..~ i 'I , jUL ~ ~~' ............... , -.~--1 ;~- ................ ~chorag~ ................................. ] ................. ' SHUT IN TIME SHUT IN PRESSURE '"'bi~%i~ ................... ! ..... -6-~;i ..... 1 1.0 rain 2.0 rain , · 3.0 min , ................................. I ................. I 4.0 min ~ .................5.0 min ~ ................................ i i 6.0 Bin ................ ! ................. i ................... ................. 8.0 rain ~ ~.0 rain , 10.0 rain ~ NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1 D-38 Date: 7/20/2000 Supervisor: Mike Winfree ~'~ Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 3-1/2" 9.3# L-80 EUESRD mod x 7" 26# L-80 BTC mod Casing Setting Depth: 7,209' TMD ~'~. f,.~/-..- Hole Depth: 12,960' TMD 4,279' TVD 6,069' TVD Mud Weight: 11.3 ppg Length of Open Hole Section: 5,751' EMW = Leak-off Press. + Mud Weight = 1,125 psi + 11.3 ppg 0.052 x TVD 0.052 x 6,069' EMW for open hole section = 14.9 ppg Pump output = 0.0199 bps Fluid Pumped = 9.0 bbl 1,400 psi 1,300 psi - - 1,100 psi 1,000 psi gOO psi 700 psi 500 psi ..... 400 psi 300 psi 2gO psi 100 psi 0 psi Y --e-- LEAK-OFF TEST' I~ICASING TEST ........ :.::.:::--'--- LOT SHUT IN TIME ~-CASING TEST SHUT IN TIME LONE rs ~ ..... i LINE MINUTE TICKS ..... -~-- STROKES · I LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ' ................ '~ ................ '- ................. l " ................ ~' ............... ~ ................. .................... _o__s__tk__s____i ..... _o__.p_?L .... : ..................... .o__?_t._k.s____j ..... g__p_?j_ ..... j 650pi J 50 stks s ................................. I .................. I .................~- ............... a. ................. , 100stks i 750 psi ................... J__q _o__s_!_k_?__j____s__qg___p_?!___i ................................. ~' .................. .................. -2- -0- -O--s--t-k-?- - i -- ! '- '0'0' '0'- R?'L ~ ................................. i .................. 250 stks ! 1,075 psi ) 300 stks ! 1,125 psi ! : ,,.-~- ................ · .m- ............... + ................. 4 ~- ................................ I .............. ................... ~_q_o_ _s__t_k_?_ _ i__ ! ,__0_7_ _5__ _p_?! _j ................................. ., ................ 400 stks i 1,075 psi J ,' ,: 450 stks 1,075 psi i ' ~'~ ~-~ ~¢-~, ~_..~ ! ~/~ ~ .................................................. l ............ ,,'~ [~' ,'~'-- ' -~'1~"~'I~' - ' ~-' ~' '--'~ , ................ ~ ............... .t ................. I I .a- .~ ................. ~. ............... -~ ................. .J j ~, ~ , ..... :_ ~: z~-_ .-= .~-_-_--'- ....... t' ................. I ................................ I ................. I ................................. ................. i ................. ................ ................................ I ................. I I I | j , I SHUT IN TIME I SHUT IN PRESSURE ,___9:_°___m_j_n____L ............... J ..... 9_ _P_ _sj ..... i ................................. ~ ................. I 1.0 min: ,! I I : : : 2.0 mmn ' SHUT IN TIME SHUT IN PRESSURE .__3:O_min_..:__ __._ 0.0rain i 1,075psi i 4.0min ~ .~ ~. ................................................ 1.0rain . ) 850 psi ............ : .... T ............... i ............. ;--'I 2.0mln -E j 800 psi 4.0min j j 800 psi ____5_:9___m_!_n_ ................... j____8__°..°_._P.S_L_i 6.0 min : J 7.0 min J 8.0 rain 9.0 rain j j 6.0 rain : 7.0 rain : r---~-jy~-i~---r .................................. 9.0 min ~ . , 10.0 m~n j ................il. ............... .~ ................. ..m 15.0 min, .................................. 25.0 rain I NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ~ROM: NABORS 16~ DRILL~HG FAX 140.: 987 659i741 87-24-88 84:59A P.85 NABOR~ ALASKA DRILLI~GRIG 16-1~' ,NJECTI"~ ,,T~ WELL/~)-/'?'" DAIL¥ ANNULAR INJECTtON REPORT DATE ,?/~/~j [FLU,DS 'F~0M WELL TIME ......... ~P~T[ I~A~C INJECTION 'VOLU~ C~U~I~V~ .... MILITARY Fluid~ {BPM} PRESSURE ~E$$U~a INJECTED VObU~E COMMENTS i i i L ii ...... , ,. ,~ ....... ,.~,, _ , , ....... . .......... ,, ............ ,. ......... ~. _ ...... , , , _~. . .-. ,,__ ,, ,, ,,, ,,,,, .... ~ ~ ,, - . .......... .......... ..... ....... ,, , . .... · .............. ..... , ............. 4~ ......... ii iiii., i , , . Il III ..... II .................. _. J .~ . .,_. ,, ........................... ......... ~AD~ITJONAL NoTEs OR COMME NT5: Ill .. ,j,,. ~ ..... . ,,,, ,. ................ .......... ....... .;~... ::: :------Il. Ill, ............. , .... .--. ,,,,, , . .J hill . ~' II I II II I .......... ~1 I II ~11 I I IIIIII NIG T 480TION SUE IS · ~ADDITIVES USED: DA~[~ VpLUME TOTALS ..... ~~F~ ...... NIGHTS .i DAYS MUD , D~~TID=~~. SU~"YiSO" :. ~ ~ GEL-- ,, ,~ ' wA~ER ~D~ ..... _ t V~ [ ~~_,_.. 81CARB l .... OTHER I '~TOTALS FOR D~Y ,,, ULATiV~._T6TAL INjECTeD INTO T~iS ANNULUS · i i i L i .,. i iiii ii ~- ' . .,_ I FROM: NABORS 16E DRILLING FAX NO.: 907 6591741 07-23-0~ 07 :O~;A P.04 'NABORS A-LASKA DRILLING RI~ 16-E INJE'~TING INT0'WELL/,Z) "._/~' DAILY ANNULAR INJECTION REPORT iiii i i i DATE ~G,-,;::['o[¢~2_~ I~LUIDS FROM WELL /Z~' mn mi · · IlJl 'hME "' Pul~ RA'TE 5T,&TIC INJECTION VOLUME CUMUL.Je. TIVE MILITARY Fluid type {BPM) PRESSURE PRESSUR'E INJECTED VOI,..UME COMMENTS ~/.~ /-t]~~ ~,~ ~..~ /,,~mc, /~C, /~ ....... ... -- .... ~, ....... . . · ., . ......... ,, ,, ...... ,, ,.. ....... ,~ , ,., , . ._. .. j,, - , .., ... nl ,,, ..... ,__. IIll . i ~ljj_ .... iii ... i Il . . i [ . ................ ,, ,[,, [ ..... ,,,, · · ,i, .... , [ .. .. ,- .... ....... ~ ..... . .- . .... .- , , 1, - .... ,, , ....... ................. ..... .............. ,, , .. · -~ . . ........ ,,[ .---- . ........ , ..... [ ,ii illll ii i1~11 J ii ...... ADDITION~M.. NOTES OR COMMENTS: ,, . ,,~ ,,,, ~ ~ ......... _. , · .. · .............. .-... ,, , ,,,,,,, ~ I~ . ~ fill IlUll ~ .... IIII _11 . . I I PHILLiI~, ALASKa SUPERVISOR: X,..TEN D CUTTINGS -- BICARt~ J OTHER ................ __ ...... i , '-- ,. r p I Il ~1 ..... I II Ill I ~llll TOTALS FOR DAY U ..... .... INTO THIS ANN LU$ ~ i j__[:. · . iii SF~NT BY: 7-31- 0 ' I'$4PM ' PHILLIPS AK INC--, 907 276 7542'# 2/ 3 Phillips Alaska Drilling Cementing Details Well Nam;e~ 1D-~8 R=pnn Dmn: 07/OE~2DO0 RePc~ Numbec 26 Rig Name: Nabom leE APO No,: AI(Oi~3 Field: Casing Size Hole Dl~,mete:][ Anglo thru KRU: ,Shoe Das:4.h; LC Dap111: % washout; 9.625" 12,25" ...........- NIA NI~ Conlr~llz,~1 S~afo He u;ed, im'ervats covered and spacing C;OnWl~Unt.~ MUa Weil~ht: PV(priur cOnd): PV(alter cond):I YP{prtor cond): YP(after c~nd): Comrnente: 10.0 54 .... . Gnl~ b~)f=~e: Ceos after: 'l'otel Volume Circulated; a/18 100 bbl~ ............ , , .... Wash 0 Typ=. Vnhamt~: Welghl; Comnlellte; Spacer 0 l ype: Valume: WelgnI; Cornmer~ts: ................. Lead Cement 0 Typo: Mix wVtemp: Iqo. of .e;~ek.'=: Weight: Yield: Common~s: ASLLI '~ 1&3 ....... L. 10.7 Additive,-,: Tall Cemenl 0 Type: Mix wtr tamp; No. of Sacl~=: WelOl3t: Yield: Comm{3r~lt;: ,,,,,,, ,~ ........ .._~,,, . I AddltNos: ..... ~ .................... . ..... Dl~placetl~ent 0 RGte(befom ~all at shoe): rlale(talI around shoe): Str, Wt. Up: Comm~rllu: ...... . ........ rteclpmcsLIo~ lengllV. Reciprocation speed: Sir. WI. Down: 11merrill;al Di,<plut~ewrlel iL: AcluSl Di$~lacentelnt; ~tr. Wt. in mud: r~afculaterJ lop o! ¢emen!: CP: Bumped plug: Floats held: surre~ I Dnt.:a?/~g/o0 N/A 1 ............ T!?':.~° Remarks:TQp Job. ¢lrculaled will1 H20 until returns clean/,100 Dbls,) Pumped 143 bbls 10,?# cemcnL 10.7~ cemenl al ,~uriace. Ran 1"1o76§' could not go itny Cooper. ,,,,. · . _ ........... ! ..... Cement Company: [Rig Contractor: IAppmved By: Oowell I NABOnS I Fred Herbert F'ROM: HABORS 16E DRILLING FAX NO.: 907 6591741 07-07-00 12:0~P P .02 P-r- - o'7'7 Phillips Alaska Drilling Daily Drilling Report AKO093 ~ 07/05/2g0~ 28 1 ~,/iN]~]O 05:30~D0 Rig Rel~. h~ ......[ MUD D~TA ORILLING DATA GIT DATA EH&5 DRILL~P DATA MUD ~ 0[~ 8~ NO. ~T NO. A~IDE~ [non-,~l~ BOP~I~ ~ B~RILL ~IG~ ROT ~ SlZ[ SIZE ...... ~MPLO~ - ~ST H~S DRILL ~A~hR~-~R~LE ~-2pp9 ~ VI~ PU ~ "- MA~ ~MAKE S~LL ~ST CONFINED LA~ S~ILL DRILL Pv~P ~0 ~ ~PE ~FE ~E FUEL & WA?E~ GEL5 AVG DRAG SERIAL NO SERIAL NO VOLUME ~allo~s) ¢UBL USED 5t51 ~Pl WL M~ DRAG ~ OUT .... ~'~'-- ...... LA~'SAF~ M~G .... DRILL WATER US~D- 9.6 07~ ~ml/~ min I~EGT~ V~EO - SOLIDS ~O OFF FOOTAGE F~TAGE IN~ON WELL ~THER & ~LE'VOLUM~ PUMP PR~S ;ADTI~ '" ADTa~ " SbURCEW6LL ...... ~M~ *r MBT . PUMP NO WOB 2 WO~ 2 RA~ (~m) WIND SPEED ph LINER SZ RPM 1 ~PM 1 PRESSURE (~1) WIND DIRECTION L~S $PM ~ ~A TFA ~J~C~ON FLUI~ CHILL FACTOR .... ~7~= PIT VOL GPM 2 J~S J~S Fr~h W~r PHILLIPS ~o Ill I I Ill Il Itl ~ ~ERSONNEL sg, ss.s~ Ill o PERSONNEL ~,.,. TOTAL MUD SPP 1 DULL DULL TOTAL V~ (bbl) MISC PER3ONNEL ~MPANY MUD ~' GRAD~ GRAD~ ~T ~R WELL (bbl) S~VIC~ TOTAL BHA DE~RI~I~ ~ .... ' DRILLPI~ DATA ~aNA NO O0 ID WEIGHT G~DE CONNEC~OH C~SS 2 L~N~ BHA LENGTH ., .. DATE INSPE~D: ~OURS ON JARS. [ TIME ~ ENO ~ HOURS OPS COOE ~ HOLE SECT ~PNASE OPS ~ OPERATIONS FROM ~- ~ 12;~ AM ~:OO AM 3.~ CEMENT SURF ~Nng aha HaM PJSM. ~ment wi ~ll. PT IIn~ ~ ~, ~ 2qO bb~ T =~ 15.7, Top plug B hms cm~, 15 H~. ~) 03:~ AM ~:30 ~ 2.~ CEMENT SURF ~slng an; Dlspl~ ceme~w/~g puma. 1 ~;m ~ ~m~ bum~ ~ug, o~k fl~ IOK), ~:~ AM 07:~ ~ 1.~ ~ SURF QaMn9 aha ~ camm ~ulp. clear fl~r ~ ~1;. Wash out ~Ck. 07:~ AM 09:~ ~ ~.~ N~_NO SURP ~nr Nlpe~ ~ dlve~t li~. ~t ~ck suite 09:~ AM ~:~ PM e.~ PRB. TJOB SURF Casi~ a~ W~e t" ~ ~er & wn In ~me for Top Job ~ 0S:~ PM o9;3o PM 4.~ PRe_T JOB SURF ~sl~g arid CIm ~ ~11 u~! ~m~ eleafl. Pum~ ~ ~bls ~ Cvme~flg bpm I 3~ ~i, ~mp t~ bbll tO.~ AS !11 c~eM ~ ~0.~ ~;~ PM 41:30 PM 2.~ PEaT JOB SURF C~qlflO ewe ~H ~ I" & ~ ~me. t ~ ;~ PM ~ 2;~ AM 0.~ NU_ND SURF ~er '1~11S~ Heae. Daily Drilling Report: 1 D-38 07/05/2000 Page I OPERATIONS I~ROM O0(X) - 00(~ Hole PJSM. Cement wi De, tell. PT IIn~ te ~, ~ p~~h, ~ ~ls ~acer, To~ plug, ~ ~1~ ~, mit ~ 10,7, 2~ 0 bbb T c~ ~ ~ 5.7, Top plug ~ b~t; =m~, ~ 5 H~. (R~Ip ~~) Dtspl~ c~me~wl ~g pump. T Ppm ~ ~~ u~l ~, ~d ~~ ~ ~D ~. ~~u~ ~ Ol~pl~, 41~ n~ Dump ~ug. Ch~k fl~ (OK), la~dln~ HlpuM ~ dlve~r li~. ~t ~ck su~co ~ck. W~ t" ~ ~~r & ~n In ~me ~or Top dob ~ ~H ~ l"& ~ ~me. Page I PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 June 14, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 1D-38 Dear Mr. Commissioner: Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached Application for Sundry Approval to change the name on a previously submitted Permit to Drill from 1D-21 to 1D-38. If you have any questions regarding this matter, please contact me at 265-6120 or William Lloyd at 265-6531. Sincerely, G. C. Alvord Drilling Engineering Supervisor PAI Drilling GCA/skad i " STATE OF ALASKA i~' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X Name change 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 507' FNL, 421' FEL, Sec. 23, T11N, R10E, UM At top of productive interval 564' FNL, 2480' FWL, Sec. 36, T11 N, R10E, UM At effective depth At total depth 931' FNL, 2581' FWL, Sec. 36, T11 N, R10E, UM 5. Type of Well: Development _X Exploratory __ Stratigraphic _ Service _ 6. Datum elevation (DF or KB feet) RKB 35' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 D-38 9. Permitnumber/approvalnumber 200-077 10. APInumber 50-029-22961-00 11. Field / Pool Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Conductor Surface Production Liner measu red true vertical Length Size feet feet Plugs (measured) feet feet Junk (measured) Cemented Measured Depth True vertical Depth Perforation depth: measu red true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) ORIGINAL 13. Attachments Description summary of proposal__ Detailed operations program __ BOP sketch __ Refer to attached morning drilling for LOT surface cement details and detail report test, casing sheets, schematic 15. Status of well classification as: 14. Estimated date for commencing operation June 15, 2000 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Service i 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Suspended __ Questions? Call Bill Lloyd 265-6531 ~ ~'. ~7'l~'~ Title: Drilling Engineering Supervisor Date G. c. Alvord Prepared by Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test_ Location clearance_ Mechanical Integrity Test_ Subsequent form required 10- ¢¢"~ ORIGINAL SIGNE[. ' _ Approved by order of the Commission D Taylor Seamou,'. "'~d O~p.V Commissioner .:~.aturned Form ~0-405 Rev 06/15/88 ...?-.~ ~' Approval no. SUBMIT IN TRIPLICATE ALASKA OIL AND GAS G. C. Alvord CONSERVATION CO~llSSION Drilling Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re~ Kuparuk River Unit 1D-21 ARCO Alaska, Inc. Permit No: 200-077 Sur Loc: 573'FNL, 601'FEL, Sec. 23, T1 IN, R10E, UM Btmhole Loc. 93 I'FNL, 2581'FWL, Sec. 36, T11N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 1D-21. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 1D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Commissioner BY ORDER OF THE ~OMMISSION DATED this 2_~f-~ day of May, 2000 dlf/Enclosures CC2 Department of Fish & Game, Habitat. Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type ofwork: Drill [~ Redrill D I lb. Type ofwell. 'E'xploratory 'El Stratigraphic Test'r'-~ Development ~)i, r~ .......... Re-entry ~] Deepen D Service r'] Development Gas r-~ single zone F~ Multiple Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool f~ ~laska, Inc. ~ RKB 35 feet 3. Address /- 6. Property Designation ~ ~5"4,5~,.~3 Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25661 ALK 471 Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 573' FNL, 601' FEL, Sec. 23, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 564' FNL, 2480' FWL, Sec. 36, T11N, R10E, UM 1D-21 #U-630610 At total depth 9. Approximate spud date Amount 931' FNL, 2581' FWL, Sec. 36, T11N, R10E, UM May 29, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 2480 @ TargE feetI 1D-11 11.5' @ 460' feet 2560 14011 'MD/6580 'TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 600 MD Maximum hole angle 68.51° Maximum surface 3469 psig At total depth (TVD) psig 18. Casing program Settin.q Depth size Specifications Top Bottom Quantity of Cement Hole Casin~l Wei~lht Grade Coupling Len~]th MD TVD MD TVD (include sta~le data) 20" 16" 62.5# R-3 Weld 85' 35' 35' 120' 120' 230 sx ASI 12.25" 9.625" 40# L-80 BTC 7887' 35' 35' 7922' 4271' 800 sx AS III L & 1000 sx Class G 8.5" 7" 26# L-80 BTC-Mod 13087' 35' 35' 13122' 6254' 180 sx Class G 6.125" 3.5# 9.3# L-80 EUE 1039' 12972' 6199' 14011' 6580' 270 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) ,.., ORIGINAL Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface "It,'"' ~,~'" ~'~ ~1~1 Production ~-,~i~,.~-,,,~/~ ~' '~l l~*~ ~' Liner L,i:,'!~,Y 18 Perforation depth: measured ~o.^ttachmen~ F, ingfee ID Prope~yP~at I-'! BOP Sketch ID DiverterSketch ID Dri,ing program ID Dri,ing,uid program [DTime vs depth p~ot I--IRe~action ana~sis D Seabed report I'-! ~o~c ~s.oso re~uiremen~ I--I 21. I hereby certify that the foregoing is true and correct to the best of my knowledg~ Questions? Call Bill Lloyd 265-653 Signed ..~-'~ ~ ~"/~L Title: DrilllngEngineeringSuporvlsor Date G. C. Alvord Pr~.n~r~cJ hv .gharon AIl.~ut3-Drak~ Commission Use Onl) Permit Number APl number I Approval d.~.ate _._, I See cover letter ~.~-""~)'77 50-{~;),~_?'- ,,2,-2...?~/--{~)I ~ ---C:~ ~:~'""~ Ifor other requirements Co,ditionsofapprova, Samp,esre, uired D.__.Yes Et No Uud,ogre,u,red r-I Yes ~ No Hydrogen sulfidemeasures D Yes [~ No Directional surveyrequired [~ Yes D No Required working pressure for BOPE 1--12u; E] 3M; r"] 5M; r-~ lOU;[--I Other: ORIGINAL SIGNED BY by order of --~'"C>~ Approved bi/ ~ Taylor Seamount Commissioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate Phillips Alaska, Inc. Drill and Case Plan for 1D-2:1. Kuparuk Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Hove in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 12 1/4" hole to the surface casing point at 7922' MD/4271' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. · Employ lightweight permafrost cement lead slurry to assure cement returns to the surface in a one stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. ~ Notify AOGCC 24 hours before test 7. Hake up 8 1/2" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 8. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 9. Drill 8 1/2" intermediate wellbore to 12766' IVlD/6124' TVD and perform second LOT to evaluate long string option. Drill ahead to +13122' MD/6254' TVD:to base HRZ if LOT is inadequate for long string. 10. If top set is required, run and cement 7" 26# L80 BTC-Hod and continue with step 1:1. If Iongstring is applicable based upon mid-HRZ LOT, drill well to TD,. run and cement 7" casing and skip to step 16. :11. Hake up 6:1/8" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 12. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town :13. Drill 6 1/8" hole to TD at 140:1:1' MD/6580' TVD · Condition hole and mud for casing :14. Run and cement 3 1/2" 9.3# L80 EUE Liner 15. Hake a cleanout run with bit and scrapers · Displace to filtered seawater · Pressure test well to 3000 psi for 30 minutes · Record results and fax to town 16. Run and land 3 1/2" tubing with gas lift completion 17. Nipple down BOP's. Install production tree and pressure test same. 18. Secure well, release rig. f " Phillips Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 1D-21 Drillinq Fluid Pro Density PV YP Funnel Vis Tnitial Gel 10 IVlinute Gel APT Filtrate pH % Solids )erties: Spud to surface casing point 9.5-10.2 ppg 16-26 25~35 100- 120' Drill out to TD 9.5- 12.9 ppg 6-20 5-20 35-50 10-20 15-40 7-15 9.5-10 +10% 2-6 4-8 <6 through Kup 9.0-10 <11% .:.,iY 'l 8 200¢ Drillinq Fluid System: Triple Derrick Shale Shakers Desander~ Desilter¢ Hud Cleaner Centrifuqe Pit Level fndicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Degasser Fluid Agitators *Spud mud should be adjusted to a FV between 100-200 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Two possibilities exist for the Maximum anticipated surface pressure (HASP) while drilling the production hole: 1) Based upon a reservoir pressure of 3500 psi and a gas gradient of 0.11 psi/R, the HASP is calculated as 2787 psi. (([3500 psi/6475' TVD]-0.11)*6475' = 2787 psi) or 2)If gas charge sands in the D shale exist as a result of historic Gas Storage Area injection, the HASP would be based upon a 12.5 ppg equivalent pressure or (([4176 psi/6426' TVD]-0.11 gas gradient)~6426' = 3469 psi. Based upon this information, Phillips will test the BOP equipment to 3,500 psi after setting surface casing. Based upon the anticipated pressures as shown, a maximum mud weight requirement for this well is established upon the potential gas charging of the D Shale sands or (4176+150)/.052/6426=13.0 ppg. In order to allow for a long string design, the minimum LOT in the Mid-HRZ or surface casing shoe must be greater than ECD (equivalent circulating density) with a 13.0 ppg fluid as measured (or modeled) with the Pressure While Drilling (PWD) sub, plus adequate safety margin. Well Proximity Risks: The nearest well to 1D-21 is 1D-11. The wells are 11.5' from each other at a depth of 460' MD. Drillinq Area Risks: Drilling risks in the 1D-2:I. area are surface interval hydrates, lost circulation and potential borehole instability in and below the permafrost formation as well as through the intermediate shales. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and optimum rheological properties to safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM) and managed flowrates. Shale instability will be controlled primarily with the planned fluid densities. Additional risk exists with unpredictable charging of the D-shale Phillips Alaska, Inc. I sands during historic gas injection. Gas pressure risks are mitigated with mid-HRZ LOT's and top setting option above the D shale based upon those results. Annular Pumpinq Operations: ];ncidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class T! disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1D-21 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. At the end of drilling operations, a request for 1D-21 to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 3H pad, per regulation 20 AAC 25.080, will be submitted. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300- 500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC 3,090 psi NA 5,750 psi 4,888 psi 7" 26 L-80 3 LTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi 31/2''* 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi * if needed Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). 10,165' MD 1D-21 WELLBORE SCHEMATIC and CEMENT DESIGN 16" Conductor Casing at 135' MD / RKB Base of permafrost 1,649' MD Port~ co~r Top of West Sak 5,923' MD Base of West Sak 7,183' MD 9-5/8" Surface Casing at 7,922' MD Top of Cement at 12,300' MD Intermediate Casing at 13,122' MD 3-1/2" Production Liner @ 12,972' MD to 14,011' MD 8-1/2" Hole 6-1/8" Hole Conductor Casing Size/Hole Size 16" in 20" hole Depth: 135' MD RKB Top of Cement Sudace Excess Calculated: 100% Volume Calculations: (135 II) (0.7854 cf/If) (2.00) = 212 cf (212 cf) /(0.93 cl/sx) = 230 sx Slurry Volume: 212 cf or Arctic Set 1 230 sx Slurry Weight 15.7 ppg rounde, Slurry Yield 0.93 cf/sx Surface Casing excess 9-5/8" in 12-1/4" hole Stage 1: Volume (1,649 If) (0.3132 cf/If) (2.50): 1,808 cf (3,774 II) (0.3132 cf/If) (1.45) = 1,714 cf Lead (3,521 cf) /(4.43 cf/sx) = 795 sx Tail (2,499 If) (0.3132 cf/if) (1.45) = 1,135 cf shoe joint vol 34 cf + (1,135 cf) /(1.17 cf/sx) = 999sx System: Lead (Arctic Set 3 Lite cement + 9% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCI2) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (CIG cmt + 1% SI(CaCI2) + 0.3% D65 (disp.) + 0.2% D46 (defoam.) + 0.1% D156 Lead Slurry Volume: 3,521 cf or 800 sx Slurry Weight 10.7 ppg Arctic Set 3 Lite Slurry Yield 4.43 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 1,135 cf or 1,000 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.17 cf/sx Thickening Time 3.5 - 4.5 hours Intermediate Casing Size / Hole Depth: Top of Cement Excess Calculated: BHT (Static): Volume around 7 " (822 If) shoe joint vol 17 cf + (182 cf) System: (Class G cement + 1% De00 + Size 13,122' 12,300' 75% 1602 F (0.1268 cf/If) /(1.17 cf/sx). 7" in 8-1/2" hole 130~ F BHT (Circ): excess (1.75) = 182cf = 171 sx 0.2% D46 + 0.3% D65 Slurry Volume: 200 cf Slurry Weight 15.8 ppg Slurry Yield 1.17 cf/sx Thickening Time 3.5 - 4.5 hours 180 sx Class G Production Casing Size / Hole Size Depth: 14,011' Top of Cement 12,950' Excess Calculated: 50% BHT (Static): 160~ F 3-1/2"in 6-1/8" hole Volume around 3-1/2" (1,061 If) (0.1378 cf/If) shoe joint vol 4 cf + (219 cf) /(1.20 cf/sx) Volume of 200' above liner System: (Class G cement w/Gasblok + 0.1 gps D47 (defoam.) + 3% D53 (Gyp) + 0.75% D65 (disp) + 1 gps D135 + 2 gps D600 + 0.1% De00 (ret.) 130~ F BHT (Circ): excess (1.50) = 219cf = 186 sx 80 sx Slurry Volume: 223 cf or 270 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.20 cf/sx Thickeninq Time 3.5 - 4.5 hours 5/16/00 Well Name: 1D- , AFC#: ADL#: ALK APl #: 50-103- Permit #: Well Name: KRU 1D-21 AFC#: 0 ADL#: 0 ALK 0 APl #: 50-103- Permit #: 0 Surface Location: 573' Target Location: 564' Bottom Hole Location: 931' FNL 601' FNL 2,480' FNL 2,581' FEL Sec 23 T11N R10E FWL Sec 36 T11N R10E FWL Sec 36 T11N R10E Expected Formation Tops Base of Permafrost West Sak Base of West Sak C80 C50 C40 (K5) C30 (K2) Top HRZ Mid-HRZ Base HRZ K-1 Marker Kuparuk D Top Kuparuk C Top C3 Top C2 Top C1 Top B Shale TD 9-5/8" Csg Point 7" Casing Point KOP Begin Turn to Target EOC Well TD 7" Cement top at Sub Sea TVD 1,511' 3,512' 3,966' 4,344' 5,300' 5,528' 5,858' 5,549' 6,019' 6,149' 6,241' 6,321' 6,325' 6,350' 6,390' 6,390' 6,400' 6,475' MD 1,616' 1,649' 3,617' 5,923' 4,071' 7,183' 4,449' 8,194' 5,405' 10,804' 5,633' 11,426' 5,963' 12,327' 5,654' 12,208' 6,124' 12,767' 6,254' 13,122' 6,346' 13,373' 6,426' 13,591' 6,430' 13,602' 6,455' 13,670' 6,495' 13,725' 6,495' 13,779' 6,505' 13,807' 6,580' 14,011' 4,166' 6,149' 4,271' ' '7,922'. 6,254' 13,122' 600' 600' 998' 1,000' 2,584' 3,104' 6,580' 14,011' 5,961' 12,322' GL 70' Sub 35' 105' 1,649' MD / 1,616' 'T'VD 5,923' MD / 3,617' TVD 7,183' MD / 4,071' TVD 8,194' MD / 4,449' -I'VD 10,804' MD./5,405' TVD 11,426' MD / 5,633' TVD 12,327' MD/5,963' TVD 12,208' MD / 5,654' TVD 12,767' MD / 6,124' TVD 13,122' MD / 6,254' TVD 13,373' MD / 6,346' TVD 13,591' MD / 6,426' TVD 13,602' MD / 6,430' TVD 13,670' MD / 6,455' TVD 13,725' MD / 6,495' TVD 13,779' MD / 6,495' TVD 14,011' MD / 6,580' TVD 0' MD / 0' TVD 7,922' MD / 4,271' TVD 13,122' MD / 6,254' TVD 600' MD / 600' TVD 1,000' MD / 998' TVD 3,104' MD / 2,584' TVD 14,011' MD / 6,580' TVD 12,322' MD / 5,961' TVD Nearest Well: Initial Az: Build Rate Turn to Final Azimuth: Max Angle: Target Angle: Departure: 1D-11 110-0 3-°/100' 165.0-° 165.0-0 69-0 69-0 11,374' Initial Az: 110-0 Build Rate: 3°/100' Turn to 165.0-° Final Azimuth: 165.0-o Max Angle: 69-o Target Angle: 69-0 Departure: 11,374' 5/18/00 Drilling Plan Surface Location: 573' FNL, 601' FEL, Sec 23, T 11 N, R 10 E Target Location: 564' FNL, 2,480' FWL, Sec 36, T 11 N, R 10 E Bottom Hole Location: 931' FNL, 2,581' FWL, Sec 36, T 11 N, R 10 E AFC#: 0 ADL#: 0 APl#: 50-103- Well Name: KRU 1D-21 Pad Level: 70' RKB: 105' Permit #: 0 Formation Tops Well Geometry Hydraulics Cement Logging Surface Hole 12-1/4" Hole 12-1/4" Hole 9-5/8" Casing 12-1/4" Hole Base of Permafrost KOP Steerable Motor Assembly 9-5/8" X 12-1/4" 1,649' MD / 1,616' TVD 600' MD / 600' TVD w/8" M1C Motor bow spring centralizers MWD Initial Az: 110= Pump Pressure: (1 per joint on bottom (Directional) West Sak Build Rate: 3¢/100' 1100 - 1800 psi 12 joints, then one 5,923' MD / 3,617' TVD Flow Rate: inside conductor) Begin Turn to Target 700-800 GPM Base of West Sak 1,000' MD / 998' TVD Bit Recommendation Single Shot Gyro 7,183' MD/4,071' TVD STC M05ODCL (surface - 500') 2-24's, 1-26 jets Single Stage Job Mud Weight: 20 bbl ARCO Wash 9-5/8" Csg Point 10.0 by 1100' TVD 40 bbl ARCO Spacer 7,922' MD / 4,271' TVD at 10.7 lb/gal WOB 10 -30 M Lead 800 sx AS3 + additives Tail 1000 sx CIG cmt + additives Rotary 80 - 120 RPM Turn to 165.0~ Mud Motor 300 - 352 Max Angle: 69~ ','t Stabilize BHA to avoid differential sticking .... EOC 10.2 by 1600' TVD 3,104' MD / 2,584' TVD Final Azimuth: 165.0¢ Intermediate Hole 8-1/2" Hole 8-1/2" Hole 7" Casing 8-1/2" Hole 1 - bowspring centralizer Steerable Motor BHA per joint for 800' (20 total) C80 w/6-3/4" M1XL MWD 8,194' MD / 4,449' TVD motor and PDC bit 7" Cement top at (Directional) 12,322' MD / 5,961' TVD STC S88HPX (new) LWD GR C50 Hycalog DS70FGNPV 20 bbl ARCO Wash, to Interval TD 10,804' MD / 5,405' TVD (rebuilt if required) 40 bbl ARCO Spacer: C40 (KS) TFA = 0.803 @ 12 ppg 11,426' MD / 5,633' TVD 180 sx C30 (K2) Class G+ additives 12,327' MD / 5,963' TVD Base HRZ WOB 5 -30 M 13,122' MD / 6,254' TVD Rotary 80 - 110 RPM K-1 Marker Mud Motor 300 - 357 13,373' MD / 6,346' TVD Pump Pressure: 1100 - 1800 psi Flow Rate: 600 - 800 GPM Mud Weight: ~ 9.1 -10.8 ppg Production Hole 6-1/8" Hole 6-1/8" Hole 3-1/2" Liner 6-1/8" Hole Top Kuparuk C Target Angle: 69= PDC Design TBD 2 Weatherford Spirolizer 13,602' MD / 6,430' TVD per it., perf dependent Cement Top: LWD Triple Combo Top C3 I WOB 200' above Liner Top GR/Res logs real time- 13,670' MD/6,455' TVDI 5- 10M Den/Neu recorded Rotary 70 - 100 RPM 10 bbls ARCO Wash Mud Motor 120 - 180 40 bbls ARCO Spacer If HOT is present, an TD @ 13.5 ppg eline conveyed CMR 14,011' MD / 6,580' TVD Pump Pressure: 270 sx log may be requested 1100 - 1500 Class G + Additives Flow Rate: 300 - 330 Mud Weight: 10.8 5/18/00 PHILLIPS Alaska, Inc. Diverter Schematic Nabors 16e 211/~,, 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline ~ 21 lA,, HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE , 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) Phillips Alaska, Inc. Nabors 16e 13-5/8" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT L, J / J I F- I I J L 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE MANUAL GATE V KILL LINE L 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator J F- i BSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP ~~,.~raulic actuator 13-5/8" 5,000 psi WP DRILLING SPOOL w/two 3" 5M psi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams 1600 I~te piotted: 16-1~k~y-2000 Pto~ Refere~c~ is 21 Version ~. Coercl',~cdes o~e in feet reference slc~ J21 ,I True Vad. lcal D~ths are reference est N16£.~ PHILLIPS Alaska, Inc. Structure: Pad 1D Well : 21 Field : Kuparuk River Unit Location : North Slope, Alaska SURFACE LOCATION ESTIMATE: 573' FNL. 601' FEL SEC. 23, TllN, RIOE PROFILE COMMENT DATA ~ ~ 11~ 74~ -1.01 ~ 1.74 1~ ~75 11~ ~41 -~ 27~1 17~1 !~91 2~ 1~ 16t~ -1~ t~ t~ 11~ ~1 1~ ~ · __D_~ ~1o ~to ~ 1~7~1 ~1 1~ ~ -~ ~ ~7.16 1~121~7 ~1 1~ ~ -lO11~tD~ 1~19 1~01 ~51 1~ ~ --1~ ~ 1~15 1~ ~1 1~,~ ~ -1~11A7 ~1~ 11~ 1~74 ~1 1~ ~ -10~ 31~47 1t1~ ~ Top of We~ ~k ~ ~ of W~ ~k I ~' FN~ 24~' ~L 9-5/8 ~;~ I SEC. 56 T11N, RIOE ~ ~o (K-a) C~O (.~ ~i.t) ~ C~ (K-2) Targ~ - Top ~ T~ B ~h~e ~s;ng ......................... ,,.2~;~,a , , 0 ~ 1~ 2~ 32~ 4~ ~ ~ ~ ~ ~ ~ 9~ l~ 11~ VeHicol Section (feet) -~ Azimuth 165.68 with reference 0.00 N, 0.00 E from slot #21 £asf (feet) -> i i i i I i 1.5 Deg/lO0' Build Begin 5 Deg/lO0' Build Begin Build ~ Turn Bose of Permafrost EOC Top of We,st Sok Bose of West Sok Casing C80 C30 (K-2) C,20 (HRZ midpoint) Bose HRZ Top Kuparuk D Torge~ - Top C4 Top CD Top C2 Tap C1 Top B Shale TD - Casing Pt 4O00 o lOO0 2000 3ooo 4OOO 5oo0 6O00 700o -51 7 Cos;rig ITD LOCATION: I 9:51' FNI_. 2581' FWL SEC. 36, T11N, RIOE PHILLIPS Alaska, Inc. Pad iD 21 slot #21 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 21 Version #4 Our ref : prop1850 License : Date printed : 16-May-2000 Date created : 16-0ct-1996 Last revised : 16-May-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 55.680,w149 30 36.428 Slot Grid coordinates are N 5959091.719, E 560490.619 Slot local coordinates are 573.00 S 601.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North PHILLIPS Alaska, Inc. Pad 1D,21 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 0.00 0.00 0.00 0.00 0.00 N 0.00 E 500.00 0.00 0.00 500.00 0.00 N 0.00 E 600.00 0.00 0.00 600.00 0.00 N 0.00 E 700.00 1.50 110.00 699.99 0.45 S 1.23 E 750.00 2.25 110.00 749.96 1.01 S 2.77 E 775.00 3.00 110.00 774.94 1.40 S 3.84 E 875.00 6.00 110.00 874.62 4.08 S 11.22 E 975.00 9.00 110.00 973.75 8.55 S 23.48 E 1000.00 9.75 110.00 998.41 9.94 S 27.31 E 1100.00 11.61 122.79 1096.69 18.28 S 43.72 E 1200.00 13.87 131.78 1194.23 31.72 S 61.12 E 1300.00 16.36 138.20 1290.77 50.21 S 79.45 E 1400.00 19.00 142.92 1386.05 73.70 S 98.66 E 1500.00 21.73 146.50 1479.79 102.13 S 118.69 E 1600.00 24.52 149.32 1571.75 135.42 S 139.50 E 1648.91 25.90 150.48 1616.00 153.44 S 149.94 E 1700.00 27.35 151.58 1661.68 173.47 S 161.02 E 1800.00 30.21 153.45 1749.31 216.19 S 183.21 E 1900.00 33.10 155.03 1834.43 263.46 S 205.98 E 2000.00 36.00 156.37 1916.79 315.15 S 229.29 E 2100.00 38.91 157.54 1996.16 371.11 S 253.08 E 2200.00 41.84 158.57 2072.34 431.20 S 277.26 E 2300.00 44.77 159.49 2145.10 495.24 S 301.79 E 2400.00 47.71 160.32 2214.26 563.07 S 326.58 E 2500.00 50.66 161.08 2279.62 634.49 S 351.58 E 2600.00 53.60 161.77 2341.00 709.31 S 376.71 E 2700.00 56.56 162.42 2398.23 787.33 S 401.91 E 2800.00 59.51 163.02 2451.16 868.33 S 427.11 E 2900.00 62.47 163.58 2499.65 952.09 S 452.23 E 3000.00 65.43 164.12 2543.55 1038.38 S 477.21 E 3100.00 68.40 164.63 2582.76 1126.96 S 501.98 E 3103.80 68.51 164.65 2584.15 1130.37 S 502.92 E 3500.00 68.51 164.65 2729.30 1485.88 S 600.52 E 4000.00 68.51 164.65 2912.46 1934.52 S 723.69 E 4500.00 68.51 164.65 3095.63 2383.16 S 846.86 E 5000.00 68.51 164.65 3278.80 2831.80 S 970.03 E 5500.00 68.51 164065 3461.96 3280.44 S 1093.20 E 5923.21 68.51 164.65 3617.00 3660.18 S 1197.45 E 6000.00 68.51 164.65 3645.13 3729.08 S 1216.37 E 6500.00 68.51 164.65 3828.30 4177.72 S 1339.53 E 7000.00 68.51 164.65 4011.46 4626.37 S 1462.70 E 7162.52 68.51 164.65 4071.00 4772.19 S 1502.74 E 7500.00 68.51 164.65 4194.63 5075.01 S 1585.87 E 8000.00 68.51 164.65 4377.80 5523.65 S 1709.04 E 8194.37 68.51 164.65 4449.00 5698.05 S 1756.92 E PROPOSAL LISTING Page 1 Your ref : 21 Version #4 Last revised : 16-May-2000 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 0.00 1.50 0.78 1.50 1.74 3.00 2.42 3.00 7.07 3.00 14.80 3.00 17.21 3.00 29.83 3.00 47.62 3.00 70.51 3.00 98.45 3.00 131.36 3.00 169.16 3.00 3.00 3.00 3.00 3.00 189.39 Base of Permafrost 211.73 258.96 310.73 366.88 3.00 427.27 3.00 491.73 3.00 560.09 3.00 632.15 3.00 707.72 3.00 786.59 3.00 868.54 3.00 953.36 3.00 1040.80 3.00 1130.64 3.00 1222.61 3.00 1226.15 0.00 1594.75 0.00 2059.93 0.00 2525.10 0.00 2990.28 0.00 3455.45 0.00 3849.19 Top of West Sak 0.00 3920.63 0.00 4385.80 0.00 4850.98 0.00 5002.18 Base of West Sak 0.00 5316.15 0.00 5781.33 0.00 5962.16 C80 8500.00 68.51 164.65 4560.96 5972.29 S 1832.21 E 0.00 6246.50 9000.00 68.51 164.65 4744.13 6420.93 S 1955.38 E 0.00 6711.68 9500.00 68.51 164.65 4927.30 6869.57 S 2078.55 E 0.00 7176.86 10000.00 68.51 164.65 5110.46 7318.22 S 2201.72 E 0.00 7642.03 10500.00 68.51 164.65 5293.63 7766.86 S 2324.89 E 0.00 8107.21 Ail data is in feet unless otherwise stated. Coordinates from slot ~21 and TVD from est N16E (105.00 Ft above mean sea level Bottom hole distance is 11374.11 on azimuth 163.71 degrees from wellhead. Total Dogleg for wellpath is 72.86 degrees. Vertical section is from wellhead on azimuth 163.68 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ PHILLIPS Alaska, Inc. Pad 1D,21 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 21 Version #4 Last revised : 16-May-2000 Dogleg Vert Deg/10Oft Sect 10804.01 68.51 164.65 5405.00 8039.64 S 2399.78 E 0.00 8390.04 C50 11000.00 68.51 164.65 5476.80 8215.50 S 2448.06 E 0.00 8572.38 11426.40 68.51 164,65 5633.00 8598.10 S 2553.10 E 0.00 8969.08 C40 (K-5) 11500.00 68.51 164.65 5659.96 8664.14 S 2571.23 E 0.00 9037.56 12000.00 68.51 164.65 5843.13 9112.78 S 2694.40 E 0.00 9502.73 12327.21 68.51 164.65 5963.00 9406.38 S 2775.00 E 0.00 9807.16 C30 (K-2) 12500.00 68.51 164.65 6026.30 9561.42 S 2817.57 E 0.00 9967.91 12766.70 68.51 164.65 6124.00 9800.73 S 2883.27 E 0.00 10216.04 C20 (HRZ midpoint) 13000.00 68.51 164.65 6209.46 10010.06 S 2940.74 E 0.00 10433.08 13121.57 68.51 164.65 6254.00 10119.15 S 2970.68 E 0.00 10546.19 Base HRZ 13372.71 68.51 164.65 6346.00 10344.49 S 3032.55 E 0.00 10779.83 K-1 13500.00 68.51 164.65 6392.63 10458.71 S 3063.90 E 0.00 10898.26 13591.09 68.51 164.65 6426.00 10540.44 S 3086.34 E 0.00 10983.00 Top Kuparuk D 13601.95 68.51 164.65 6429.98 10550.19 S 3089.02 E 0o00 10993.11 15D 16-May-00 13602.01 68.51 164.65 6430.00 10550.24 S 3089.03 E 0.00 10993.16 Target - Top C4 13670.25 68.51 164.65 6455.00 10611.47 S 3105.84 E 0.00 11056.65 Top C3 13724.85 68.51 164.65 6475.00 10660.46 S 3119.29 E 0.00 11107.45 Top C2 13779.44 68.51 164.65 6495.00 10709.44 S 3132.74 E 0.00 11158.24 Top C1 13806.74 68.51 164.65 6505.00 10733.94 S 3139.47 E 0.00 11183.63 Top B Shale 14000.00 68.51 164.65 6575.80 10907.35 S 3187.07 E 0.00 11363.43 14011.47 68.51 164.65 6580.00 10917.64 S 3189.90 E 0.00 11374.11 TD - Casing Pt Ail data is in feet unless otherwise stated. Coordinates from slot #21 and TVD from est N16E (105.00 Ft above mean sea level). Bottom hole distance is 11374.11 on azimuth 163.71 degrees from wellhead. Total Dogleg for wellpath is 72.86 degrees. Vertical section is from wellhead on azimuth 163.68 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ PHILLIPS Alaska, Inc. Pad 1D,21 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 21 Version #4 Last revised : 16-May-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 1648.91 1616.00 153.44 S 149 94 E Base of Permafrost 5923.21 3617.00 3660.18 S 1197 45 E ToD of West Sak 7162.52 4071 8194.37 4449 10804.01 5405 11426.40 5633 12327.21 5963 12766.70 6124 13121.57 6254 13372.71 6346 13591.09 6426 13601.95 6429 13602.01 6430 13670.25 6455 13724.85 6475 13779.44 6495 13806.74 6505 14011.47 6580 .00 4772.19 S 1502 74 E Base of West Sak 00 5698.05 S 1756 92 E C80 00 8039.64 S 2399 78 E C50 00 8598.10 S 2553 10 E C40 (K-5) 00 9406.38 S 2775 00 E C30 (K-2) 00 9800.73 S 2883.27 E C20 (HRZ midpoint) 00 10119.15 S 2970.68 E Base HRZ 00 10344.49 S 3032.55 E K-1 00 10540.44 S 3086.34 E Top Kuparuk D 98 10550.19 S 3089.02 E 15D 16-May-00 00 10550.24 S 3089.03 E Target - Top C4 00 10611.47 S 3105.84 E Top C3 00 10660.46 S 3119.29 E Top C2 00 10709.44 S 3132.74 E Top C1 .00 10733.94 S 3139.47 E Top B Shale .00 10917.64 S 3189.90 E TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 7708.47 4271.00 5262.07S 1637.23E 9-5/8" Casing 0.00 0.00 0.00N 0.00E 14011.50 6580.00 10917.64S 3189.90E 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 15D 16-May-00 563665.000,5948568.000,0.0000 6429.98 10550.19S 3089.02E 31-Mar-2000 PHILLIPS Alaska, Inc. Pad iD 21 slot #21 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 21 Version #4 Our ref : prop1850 License : Date printed : 16-May-2000 Date created : 16-0ct-1996 Last revised : 16-May-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 55.680,w149 30 36.428 Slot Grid coordinates are N 5959091.719, E 560490.619 Slot local coordinates are 573.00 S 601.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <O-5142'>,,l15,Pad iD PMSS <0 - 6270'>,,l14,Pad iD PMSS <293 - 6866'>,,l13,Pad 1D PMSS <294 - 8250'>,,l12,Pad 1D PMSS <556-7024'>,,9,Pad 1D PMSS <0 - 7340'>,,10,Pad iD PMSS <4674'-5639'>,,125A, Pad 1D PMSS <5155'- 5905'>,,l10A, Pad 1D PMSS <256 - 5973'>,,IlO,Pad 1D PMSS <0-8702'>,,14,Pad 1D PMSS <0-9250'>,,12,Pad 1D PMSS<0-7045'>,,lll,Pad 1D PMSS <O-4850'>,,109,Pad 1D PMSS <0 - 7150'>,,108,Pad 1D PGMS <0 - 6400'>,,WS-8,Pad iD PGMS <O-8365'>,,1,Pad 1D PMSS <291 - 5795'>,,125,Pad iD PMSS <0-5047'>,,124,Pad iD PMSS <290-6245'>,,l16,Pad 1D GSS <0-175'>,,l16,Pad 1D PMSS <287-6055'>,,123,Pad ID GSS <O-173'>,,123,Pad iD PMSS <0 - 5445'> PMSS <0 - 6580'> PMSS <0 - 7432'> PMSS <0 - 6716'> PMSS <0-4530'>, PGMS <0-8070'> PGMS <0-7502'> PMSS <0-5205'>, PMSS <0-4515'>, PGMS <0-8850'> 28-May-81, PMSS <0-5462'>, PGMS <0-8610'> ,122,Pad iD ,128,Pad iD ,127,Pad ID ,126,Pad iD 120,Pad 1D ,3,Pad 1D ,4,Pad 1D ll7,Pad 1D llg,Pad 1D MP 1 17-ii-ii,Pad 1D 129,Pad 1D ,6,Pad 1D Closest approach with 3-D Last revised Distance 2-Jun-1998 512.0 2-Sep-1998 22-Sep-1998 21-Sep-1998 29-Apr-1998 28-Apr-1998 24~Apr-2000 24-Apr-2000 24-Apr-2000 6-0ct-1999 21-Jan-2000 3-SED-1998 2-Jun-1998 28-0ct-1998 27-Apr-2000 10-Dec-1997 19-Aug-1998 2-Jun-1998 17-Sep-1998 8-Sep-1998 13-Sep-1998 4-Sep-1998 29-Aug-1998 17-Aug-1998 6-Ju1-1998 1-Ju1-1998 2-Jun-1998 13-Aug-1998 4-Aug-1992 2-Jun-1998 2-Jun-1998 23-Apr-1999 2-Jun-1998 13-Nov-1997 524.3 542 0 556 9 437 0 11 5 287 0 617 0 617 0 782 0 794 2 601 7 632 0 647 0 3O 0 809 6 287 0 302 0 497 0 497 0 358 8 362 O 376 2 206 0 236.4 265.5 407.0 570.0 449.2 482.0 422.0 8350.1 161.9 209.0 Minimum Distance method M.D. 160 0 642 9 160 0 200 0 100 0 460 0 100 0 100 0 100 0 100 0 600 0 400.0 100.0 100.0 0,0 600.0 100.0 100.0 100.0 100.0 420.0 160.0 440.0 952.8 712.5 685.7 100.0 0.0 614.3 100.0 100.0 3380.0 737.5 420.0 Diverging from M.D. 160.0 642.9 160.0 200.0 100.0 460.0 725.0 100.0 100.0 100.0 600.0 400. 100. 100. 930. 600. 725. 100. 100. 100. 420. 160. 440. 952 712 685 100 614 614 100 100 3380 737 2155 0 0 0 6 0 0 0 0 0 0 0 0 8 5 7 0 3 3 0 0 0 5 6 PMSS <0-11234'>,,il,Pad iD MSS <3311-8200'>,,7,Pad iD PMSS <0-4414'>,,121,Pad 1D PMSS <0-4778'>,,130,Pad 1D PMSS <0 - 6472'>,,131,Pad 1D PMSS <467 - 5802'>,,132,Pad 1D PMSS <1957-5265'>,,133,Pad 1D PMSS <377 - 6224'>,,134,Pad 1D PMSS <0-4590'>,,liS,Pad 1D PMSS <0-5015'>,,135,Pad 1D PGMS <O-9783'>,,2,Pad 1D PMSS <381-6092'>,,105,Pad 1D PMSS <0-5126'>,,106,Pad 1D PGMS <O-8930'>,,5,Pad 1D 30-Dec-1999 6-Nov-1997 2-Jun-1998 2-Jun-1998 23-Ju1-1998 6-Aug-1998 2-Jun-1998 3-Aug-1998 2-Jun-1998 2-Jun-1998 4-Aug-1992 2-Jun-1998 2-Jun-1998 13-Nov-1997 12.2 75 3 392 0 166 5 106 4 72 4 112 3 47 7 466 3 47 0 689 8 706 5 677.0 329.5 280 830 100 700 685 685 919 725 440 380 4O0 28O 100 300 280.0 830.6 100.0 700.0 685.7 685.7 919.4 5280.0 440.0 380.0 400.0 280.0 100.0 300.0 Phillips Alaska, Inc. ( Post Office Box 10u360 Anchorage, Alaska 99510-0360 May 16, 2000 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill: KRU 1D-2! Surface Location: 573' FNL 601' FEL Sec 23 TllN-RIOE~ UM Target Location: 564' FNL~ 2480' FWL Sec. 36~ TI:I.N-RIOE~ UM Bottom Hole Location: 931' FNL~ 2581' FWL Sec. 36f T:I. 1Nf RIOE, UI~I Dear Commissioner Christenson, PHILLIPS Alaska, Inc. hereby applies for a Permit to Drill' an onshore development well to the Kuparuk interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 1D pad. The well is designated as a conventional production well using a 9 5/8" surface casing string, a 7" intermediate casing, 3-1/2" production liner and 3-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) 2) 3) 4) S) 6) 7) 8) 9) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. PHILLIPS does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. Robert Christenson ~ Application for Permit to Drill - ID-21 Page 2 lO) Due to the large volume of regional information available, PHILLIPS considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned.The following are PHILLIP's designated contacts for reporting responsibilities to the Commission: 1) 2) Completion Report Technologist (20 AAC 25.070) Geologic Data and Logs (20 AAC 25.071) Sharon AIIsup-Drake, Drilling 263-4612 Bill Raa~, Geologist 263-4952 The anticipated spud date for this well is May 29, 2000. If you have any questions or require further information, please contact Bill Lloyd at (907) 265-6531 or Chip Alvord at (907) 265-6120. · Senior Drilling~e~- CC: Kuparuk 1D-21 Well File Chip Alvord ATO-1030 MJ Loveland NSK-06 ARCO ^'o~uo~,oo~o, Inc. ~ AAI PAYABLES P.O. Box 102776 Anchorage, AK 99510-2776 PAY TO THE ORDER OF: STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE CHECK NUMBER i ,75-42~; 205094633 839 MAY 12, 2000 VOID AFTER 90 DAYS 099757 EXACTLY ***********100 DOLLARS AND O0 CENTS $***********100.00 The First National Bank of C~cago-0710 Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 205094633 Ogg ? S ?g," WELL PERMIT CHECKLIST COMPANY ~-~/~-d.~ WELL NAME //-~ - Z../ PROGRAM: exp dev ~/~edrll serv wellbore seg ann. disposal para req FIELD & POOL (TZ"~(~)z/<~"~ INIT CLASS ~-----'~/ ~'~_~//.~..- GEOL AREA ~-)~:~.~ UNIT# <:~Z"/'/'~:'~ ON/OFF SHORE ADMINISTRATION 1. Permit fee attached. '=z~'_5.~.,~.~ ~_~__ ~/o~_~,~-~_ ~' ~ /-:t~/__. ,5-(~"0 ; ,~.~.~ 2. Lease number appropriate. ~. ................. '~ N -.~./i / ~/~-~,( ~,~c_ ' .,¢-~ 3. Unique well name and number .................. ~ ~ j ~'~ . 4. Well located in a defined pool .................. AP~.R DATE 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to %~Ob ~, psig. 27. Choke manifold complies w/APl RP-53 (May 84) .' ....... 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. ....,,-.~ N N N N N ' ( U GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... (~ N 31. Data presented on potential overpressure zones ....... ,~-/,~ Y N 32. Seismic analysis of shallow gas zones ............. /v',/~ Y N DATE 33. Seabed condition survey (if off-shore) ............. ,,,~//:2 Y N r---S. ~, ~'L.)34. Contact name/phone for weekly progress reports [exploratory onl~,/~ N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLC~Y; ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: o Z O i c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Jan 31 14:44:21 2001 Reel Header Service name ............. LISTPE Date ..................... 01/01/31 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/01/31 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit 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-00086 P. SMITH F. HERBERT 1D-38 500292295700 PHILLIPS Alaska, Inc. Sperry Sun 30-JAN-01 MWD RUN 4 AK-MM-00086 P. SMITH M. WINFREE 23 11 10E 507 421 .00 DERRICK FLOOR: 104.82 GROUND LEVEL: 70.92 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.630 7210.0 8.500 7.000 13627.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 - 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED 3. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AND STABILIZED LITH-DENSITY (SLD) . 5. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. OF 10/2/00. MWD DATA CONSIDERED PDC. 6. GAMMA RAY LOGGED BEHIND CASING TO 7210' MD, 4277' TVD. GAMMA RAY LOGGED BEHIND CASING FROM 13593' MD, 6279' TVD TO 13627' MD, 629 7. MWD RUNS 1 - 4 REPRESENT WELL 1D-38 WITH API# 50-029-22957-00. THIS WELL REACHED A TOTAL DEPTH OF 14324' MD, 6533' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME SBD2 = SMOOTHED BULK DENSITY (LOW-COUNT BIN) SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTNA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTFA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE ENVIRONMENTAL PAR3LMETERS USED IN PROCESSING THE NEUTRON LOG DATA: HOLE SIZE: 6.125" MUD WEIGHT: 11.8 PPG MUD FILTRATE SALINITY: 500 - 550 PPM CHLORIDES FORMATION WATER SALINITY: 13,000 PPM CHLORIDES FLUID DENSITY: 1.00 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/31 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: FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP NCNT .5000 START DEPTH 7177 0 7200 0 7200 0 7200 0 7200 0 7200 0 7220 5 13617 0 STOP DEPTH 14269.5 14276 5 14276 5 14276 5 14276 5 14276 5 14323 5 14221 0 FCNT 13617.0 NPHI 13617.0 RHOB 13623.0 DRHO 13623.0 PEF 13623.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 14221.0 14221.0 14237.0 14237.0 14237.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 7177.0 13638.0 4 13639.0 14323.5 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CP30 4 1 68 NCNT MWD CP30 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD B/E 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 7177 14323.5 ROP MWD FT/H 0.5 2079.83 GR MWD API 27.85 455.54 Mean Nsam 10750.3 14294 118.982 14207 139.13 14186 First Reading 7177 7220.5 7177 Last Reading 14323.5 14323.5 14269.5 RPX MWD OHMM RP$ MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HR NPHI MWD PU-S FCNT MWD CP30 NCNT MWD CP30 RHOB MWD G/CM DRHO MWD G/CM PEF MWD B/E 2 1 150 0 78 1 21 0 66 0 39 0 23 3 01 03.6 64.3 1.61 0.18 2.68 1569.16 1569.32 2000 2000 103.87 65.66 584.09 34937.9 3.17 0.43 15.22 4.25316 14154 4.88601 14154 12.0103 14154 16.5476 14154 2.00017 14154 37.2755 1209 308.464 1209 23229.7 1209 2.43935 1229 0.0674858 1229 6.06282 1229 7200 7200 7200 7200 7200 13617 13617 13617 13623 13623 13623 14276.5 14276.5 14276.5 14276.5 14276.5 14221 14221 14221 14237 14237 14237 First Reading For Entire File .......... 7177 Last Reading For Entire File ........... 14323.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/31 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: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR RPX RPS FET RPD RPM ROP $ 3 .5000 START DEPTH 7177 0 7200 0 7200 0 7200 0 7200 0 7200 0 7220 5 STOP DEPTH 13594 5 13587 0 13587 0 13587 0 13587 0 13587 0 13638 0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined 12 -JUL- 00 Insite 4.05.2 5.41 Memory 13640.0 69.7 73.5 TOOL NUMBER PB01538HWGR6 PB01538HWGR6 8.500 13627.0 LSND 10.00 52.0 9.0 5O0 4.4 2.000 1.131 3.100 3~000 70.0 129.0 70.O 70.0 Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD030 FT/H 4 1 68 MWD030 API 4 1 68 MWD030 OHMM 4 1 68 MWD030 OHMM 4 1 68 MWD030 OHMM 4 1 68 MWD030 OHMM 4 1 68 MWD030 HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 7177 13638 ROP MWD030 FT/H 0.5 1655.17 GR MWD030 API 27.85 455.54 RPX MWD030 OHMM 1.11 1569.16 RPS MWD030 OHMM 1.23 1569.32 RPM MWD030 OHMM 1.52 2000 RPD MWD030 OHMM 0.39 2000 FET MWD030 HR 0.23 98.22 Mean Nsam 10407.5 12923 123.863 12836 142.21 12836 4.09963 12775 4.60342 12775 8.6933 12775 9.59746 12775 1.31076 12775 First Reading 7177 7220.5 7177 7200 7200 7200 7200 7200 Last Reading 13638 13638 13594.5 13587 13587 13587 13587 13587 First Reading For Entire File .......... 7177 Last Reading For Entire File ........... 13638 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD RPX RPM FET RPS GR NPHI FCNT NCNT PEF RHOB DRHO ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 13587 5 13587 5 13587 5 13587 5 13587 5 13595 0 13617 0 13617 0 13617 0 13623 0 13623 0 13623 0 13638 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): STOP DEPTH 14276 5 14276 5 14276 5 14276 5 14276 5 14269 5 14221 0 14221 0 14221 0 14237 0 14237 0 14237 0 14323 5 17-JUL-00 Insite 4.05.2 0.41 Memory 14324.0 67.9 71.3 TOOL NUMBER PB01563FGR4 PB01563FGR4 PB01521NL4 PB01521NL4 6.125 LSND-LT 11.10 49.0 9.0 55O 3.4 1.700 70.0 MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 .822 1.400 2.100 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CP30 4 1 68 36 10 NCNT MWD040 CP30 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 B/E 4 1 68 52 14 152 . 0 70.0 70.0 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HR NPHI MWD040 'PU-S FCNT MWD040 CP30 Min 13587.5 2.34 41 56 0 78 1 21 0 66 1 81 0 55 23 01 103.6 Max Mean Nsam 14323.5 13955.5 1473 2079.83 73.2782 1371 246.98 109.853 1350 46.97 5.67547 1379 1150.23 7.50397 1379 2000 42.7387 1379 2000 80.9331 1379 103.87 8.38689 1379 65.66 37.2755 1209 584.09 308.464 1209 First Reading 13587.5 13638.5 13595 13587.5 13587.5 13587.5 13587.5 13587.5 13617 13617 Last Readinc_ 14323 5 14323 5 14269 5 14276 5 14276 5 14276 5 14276 5 14276 5 14221 14221 NCNT MWD040 CP30 RHOB MWD040 G/CM DRHO MWD040 G/CM PEF MWD040 B/E 15064.3 34937.9 23229.7 1.61 3.17 2.43935 -0.18 0.43 0.0674858 2.68 15.22 6.06282 1209 13617 14221 1229 13623 14237 1229 13623 14237 1229 13623 14237 First Reading For Entire File .......... 13587.5 Last Reading For Entire File ........... 14323.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/01/31 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/01/31 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
