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Home My WebLink About197-113MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-30 KUPARUK RIV UNIT 3K-30 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 3K-30 50-029-22777-00-00 197-113-0 W SPT 6579 1971130 1645 2840 2840 2840 2840 100 100 100 100 4YRTST P Josh Hunt 5/9/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3K-30 Inspection Date: Tubing OA Packer Depth 520 2020 1970 1970IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250510100016 BBL Pumped:1.1 BBL Returned:1.1 Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 14:09:07 -08'00' Wallace, Chris D (CED) From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, June 9, 2021 9:02 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Specialist CPF1 & CPF3 Subject: KRU 3K-30 (PTD 197-113) Completion of 30 day monitor period Attachments: 3K-30.pdf; 3K-30 TIO plot.pdf Chris, This emails serves as an update to the completion of the 30 day monitor period post patch installation on KRU 3K-30 (PTD # 197-113). The IA has shown no signs of re -pressurization during the monitor period. Therefore, CPAI intends to return the well to normal injection status post patch installation. Attached is the current well bore schematic and 90 day TIO plot. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM C0n0080 i9lps From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Sunday, July 26, 2020 3:20 PM To:'Wallace, Chris D (CED)' <chris.waIlace @a laska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: RE: KRU 3K-30 (PTD 197-113) Slow IA Pressurization Chris, During its monitor period, KRU WAG injector 3K-30 (PTD 197-113) has shown IA pressurization that doesn't appear to be a thermal response. The well will be shut in ASAP and the communication will be diagnosed. The well passed both positive and negative tubing- and inner casing-packoff tests on 5/14/20. It passed an MITIA on 5/15/20. (The results of the MITIA are attached.) Attached are the 90 day TIO trend and well schematic. Please let me know if you disagree with this plan or if you have questions. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 Originated:Delivered to:28-May-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 2E-10 50-029-21246-00 907100157 Kuparuk River Packer Setting Record Field- Final 19-Apr-21 0 1 2 2H-11 50-029-20052-00 n/a Kuparuk River Packer Setting Record Field- Final 18-May-21 0 1 3 2M-07 50-103-20178-00 907126248 Kuparuk River Plug Setting Record Field- Final 30-Apr-21 0 1 4 3K-03 50-029-21602-00 907097693 Kuparuk River Leak Detect Log Field- Final 16-Apr-21 0 1 5 3K-03 50-029-21602-00 907132626 Kuparuk River Packer Setting Record Field- Final 5-May-21 0 1 6 3K-30 50-029-22777-00 907098723 Kuparuk River Multi Finger Caliper Field & Processed 16-Apr-21 0 1 7 3K-30 50-029-22777-00 907098126 Kuparuk River Packer Setting Record Field- Final 6-May-21 0 1 8 3Q-06 50-029-21674-00 907089173 Kuparuk River Multi Finger Caliper Field & Processed 13-Apr-21 0 1 9 10 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: 06/01/2021 PTD: 1971130 E-Set: 35193 Originated:Delivered to:28-May-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 2E-10 50-029-21246-00 907100157 Kuparuk River Packer Setting Record Field- Final 19-Apr-21 0 1 2 2H-11 50-029-20052-00 n/a Kuparuk River Packer Setting Record Field- Final 18-May-21 0 1 3 2M-07 50-103-20178-00 907126248 Kuparuk River Plug Setting Record Field- Final 30-Apr-21 0 1 4 3K-03 50-029-21602-00 907097693 Kuparuk River Leak Detect Log Field- Final 16-Apr-21 0 1 5 3K-03 50-029-21602-00 907132626 Kuparuk River Packer Setting Record Field- Final 5-May-21 0 1 6 3K-30 50-029-22777-00 907098723 Kuparuk River Multi Finger Caliper Field & Processed 16-Apr-21 0 1 7 3K-30 50-029-22777-00 907098126 Kuparuk River Packer Setting Record Field- Final 6-May-21 0 1 8 3Q-06 50-029-21674-00 907089173 Kuparuk River Multi Finger Caliper Field & Processed 13-Apr-21 0 1 9 10 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: 06/01/2021 PTD: 1971130 E-Set: 35192 MEMORANDUM TO: Jim Regg P.I. Supervisor% 6�/ �� FROM: Lou Laubenstein Petroleum Inspector Well Name KUPARUK RIV UNIT 3K-30 Insp Num: mitLOL210523132436 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Cas Conservation Commission DATE: Thursday, May 27, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3K-30 KUPARUK RIV UNIT 3K-30 Src: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-22777-00-00 Inspector Name: Lou Laubenstein Permit Number: 197-113-0 Inspection Date: 5/23/2021 - Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-30 Type Inj 'N `TVD 6579 Tubing 2750 2750 2750 - 2750 PTD 1971130 IType Test'. SPT'�Test psi 1645 jA 460 2010 1970 - 1970 BBL Pumped: 0.8 _ IBBL Returned: 0.8 j OA so 100, 100 loo - Interval 4vRTST - P/F P Notes: MIT-lA post patch per sundry # 321-088. This will also satisfy the 4 MIT test requirement. Thursday, May 27, 2021 Page 1 of 1 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10375'feet n/a feet true vertical 6936'feet n/a feet Effective Depth measured 10375'feet 9818, 9852'feet true vertical 6936'feet 6532, 6557'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" L-80 9902' 6593' Packers and SSSV (type, measured and true vertical depth)9818' MD 9852' MD 500' MD 6532' TVD 6557' TVD 500' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title:Senior Well Integrity Specialist Contact Email: Contact Phone: Senior Engineer:Senior Res. Engineer: Collapse 121' BurstTVD 4108' 6920' 81' 5761' 5-1/2" x 4-1/2"10314'10353' Treatment descriptions including volumes used and final pressure: 1550 Casing Structural 16" 7-5/8" 121' 3. Address: Casing Pressure Tubing Pressure measured true vertical Kuparuk River Field/ Kuparuk River Oil Pool Conductor Intermediate KRU 3K-30 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-088 2783 Production Packer Length N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf measuredPlugs Junk measured Size Surface ConocoPhillips Alaska, Inc. ADL0025519 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-113 50-029-22777-00 5. Permit to Drill Number:2. Operator Name N 450 0 Representative Daily Average Production or Injection Data 2868485 P.O. Box 100360 Anchorage, AK 99510 0 1493 Oil-Bbl 4. Well Class Before Work: 5802' 0 Water-Bbl MD Packer: Northern Solutions Packer Packer: Northern Solutions Packer SSSV: Nipple 10026-10046', 10062-10082', 10084-10104' feet 6683-6698', 6709-6724', 6725-6740' feet N/A Jan Byrne jan.byrne@conocophillips.com (907) 659-7224 Authorized Name: Jan Byrne Authorized Signature with date: WINJ WAG t Frac O y e 6. API N y G L GIN , Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 12:03 pm, May 20, 2021 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室宇室宷宨孽季孵孳孵孴孱孳學孱孵孳季孳孼孽孷孻孽孳學孰孳孻孪孳孳孪安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孴孱孶Jan Byrne DSR-5/24/21 RBDMS HEW 6/10/2021 SFD 5/21/2021VTL 8/9/21 DTTMSTART JOBTYP SUMMARYOPS 5/6/2021 ANNCOMM SET LOWER 2.72" NSAK PACKER (OAL 18.21' / SN:NSP004) W/ 1.71" R NIPPLE & LOCK INSTALLED @ 9854' RKB (ME) TOP OF PACKER @ 9852.72' RKB (UTILIZING 2.5 EDPU) CMIT TBG x IA 2500 PSI (PASS) IN PROGRESS. 5/7/2021 ANNCOMM SET UPPER 2.72" NSP SPACER & SNAP LATCH (OAL 35.61' / SN:NSP003 / NSL002) @ 9819.38' RKB (ME) TOP @ 9818.10' RKB (UTILIZING 2.5 EDPU), MITT 2500 (PASS) DRAW DOWN TEST ON IA (PASS), PULLED 1.71" R-PLUG @ 9868.44' RKB, MIT IA 2500 (PASS). COMPLETE. 3K-30 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 10,033.0 1/8/2017 3K-30 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Opdated Tag from 2017 2/16/2021 3K-30 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 40.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.58 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.88 Top (ftKB) 41.0 Set Depth (ftKB) 5,802.5 Set Depth (TVD) … 4,108.4 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-Mod Casing Description PRODUCTION 5.5"x4.5"@9902' OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 38.8 Set Depth (ftKB) 10,353.0 Set Depth (TVD) … 6,920.5 Wt/Len (l… 15.50 Grade L-80 Top Thread LTC-MOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 36.8 Set Depth (ft… 9,901.6 Set Depth (TVD) (… 6,592.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 36.8 36.8 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 500.1 499.8 6.30 NIPPLE CAMCO 'DS' NIPPLE 2.812 9,835.8 6,544.9 43.57 SLEEVE BAKER CMD SLIDING SLEEVE w/SELECTIVE PROFILE 2.812" (Completion tally IDs sleeve as CMU; field testing 10/12/2008 indicates CMD) VERIFIED SLEEVE IS IN OPEN POSITION 3/28/21 2.812 9,884.0 6,580.0 43.23 LOCATOR BAKER LOCATOR 3.000 9,884.8 6,580.6 43.23 SEAL ASSY BAKER GBH-22 LOCATOR/SEAL ASSEMBLY (seals stabbed into 4" ID SBE @ 5.5"x4.5" CSG crossover) 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 9,818.1 6,532.2 43.97 PACKER - PATCH - UPR Northern Solutions Upper packer with 28.45' spacer pipe below with snap latch Assembly, OAL=35.91' 5/7/2021 1.810 9,852.0 6,556.7 43.24 PACKER - PATCH - LWR Northern Solutions Lower packer with 10' spacer pipe below with 1.71 R nipple, OAL=17.05 5/6/2021 1.710 CSG PATCH SURFACE CASING PATCH: 12' OAL 16" 62.5# API 5L GR B 6/14/2008 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 10,026.0 10,046.0 6,683.3 6,697.8 A-3, 3K-30 7/27/1997 4.0 IPERF 2 1/8" EnerJet, 90 deg. pH 10,062.0 10,082.0 6,709.4 6,723.9 A-2, 3K-30 7/27/1997 4.0 IPERF 2 1/8" EnerJet, 90 deg. pH 10,084.0 10,104.0 6,725.3 6,739.8 A-2, 3K-30 7/26/1997 4.0 IPERF 2 1/8" EnerJet, 90 deg. pH; Oriented (+/-) 45 deg. FLSH Notes: General & Safety End Date Annotation 2/20/2009 NOTE: View Schematic w/ Alaska Schematic9.0 12/29/2008 NOTE: .05 BBL/MINUTE LEAK FOUND @ 9836' SLEEVE 3K-30, 5/11/2021 4:26:57 PM Vertical schematic (actual) PRODUCTION 5.5"x4.5"@9902'; 38.8-10,353.0 IPERF; 10,084.0-10,104.0 IPERF; 10,062.0-10,082.0 IPERF; 10,026.0-10,046.0 PACKER - PATCH - LWR; 9,852.0 PACKER - PATCH - UPR; 9,818.1 SURFACE; 41.0-5,802.5 NIPPLE; 500.1 CONDUCTOR; 40.0-121.0 KUP INJ KB-Grd (ft) 41.02 Rig Release Date 7/27/1997 3K-30 ... TD Act Btm (ftKB) 10,375.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292277700 Wellbore Status INJ Max Angle & MD Incl (°) 56.53 MD (ftKB) 3,508.30 WELLNAME WELLBORE3K-30 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Wallace, Chris D (CED) From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Thursday, February 18, 2021 3:17 PM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler Subject: 3K-30 (PTD 197-113) Update 2/18/21 Chris, KRU 3K-30 (PTD 197-113) was last reported on 7/26/20 after exhibiting continued IA pressurization. The well was shut in shortly after the report. The plan forward is to pull and replace the existing tubing patch and then bring the well online for a 30 day monitor period to confirm integrity. A 10-403 has been submitted for the well work. A follow up email with the plan forward will be provided upon conclusion of the monitor period. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. 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The well will be shut in ASAP and the communication will be diagnosed. The well passed both positive and negative tubing- and inner casing-packoff tests on 5/14/20. It passed an MITIA on 5/15/20. (The results of the MITIA are attached.) Attached are the 90 day TIO trend and well schematic. Please let me know if you disagree with this plan or if you have questions. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Tuesday, May 12, 2020 10:54 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU 3K-30 (PTD 197-113) Slow IA Pressurization Chris, KRU WAG injector 3K-30 (PTD 197-113) is showing a slow IA pressurization while on water injection. CPAI intends to have DHD perform diagnostics (including an MITIA) and will put 3K-30 on a 60 day monitor while it continues on water injection. If tubing by IA communication is confirmed, the well will be shut in as soon as operationally possible. Attached are the 90 day TIO trend and well schematic. Please let us know if you disagree with this plan or if you have questions. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Tuesday, May 12, 2020 10:54 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 3K-30 (PTD 197-113) Slow IA Pressurization Attachments: 3K-30 90 day TIO Trend 5-12-20.pdf, 3K-30 Well Schematic 5-12-20.pdf Chris, KRU WAG injector 3K-30 (PTD 197-113) is showing a slow IA pressurization while on water injection. CPAI intends to have DHD perform diagnostics (including an MITIA) and will put 3K-30 on a 60 day monitor while it continues on water injection. If tubing by IA communication is confirmed, the well will be shut in as soon as operationally possible. Attached are the 90 day TIO trend and well schematic. Please let us know if you disagree with this plan or if you have questions. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 Wallace, Chris D (CED) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday, June 4, 2019 2:36 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: KRU 3K-30 (PTD 197-113) Suspect IA Pressure Rise Attachments: KRU 31(-30 TIO plot 90 -day 6-4-19.JPG Chris, KRU 3K-30 (PTD 197-113) is at the end of a 30 -day water injection monitor. The well showed integrity during the monitor, so it will be returned to normal injection status. Attached is a 90 -day TIO plot. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: NSK Well Integrity Supv CPF3 and WNS Sent: Sunday, May 5, 2019 1:05 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU 3K-30 (PTD 197-113) Suspect IA Pressure Rise Chris, KRU injector 3K-30 (PTD 197-113) is showing suspect IA pressurization during water injection. CPAI intends to put the well on a 30 -day monitor for observation during water injection and have a DHD crew perform diagnostics including a MITIA. If tubing to IA communication during water injection is confirmed, the well will be shut-in as soon as operationally possible. Attached is a 90 -day TIO plot. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday, May 5, 2019 1:05 PM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: KRU 3K-30 (PTD 197-113) Suspect IA Pressure Rise Attachments: KRU 3K-30 TIO plot 90-dayto 5-5-19.JPG Chris, KRU injector 3K-30 (PTD 197-113) is showing suspect IA pressurization during water injection. CPAI intends to put the well on a 30 -day monitor for observation during water injection and have a DHD crew perform diagnostics including a MITIA. If tubing to IA communication during water injection is confirmed, the well will be shut-in as soon as operationally possible. Attached is a 90 -day TIO plot. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 s s Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday,January 30, 2018 7:37 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 3K-30 (PTD 197-113) Suspect IA pressure Attachments: 3K-30 90-day TIO 01302018 jpg Chris— KRU injector 3K-30(PTD 197-113) has demonstrated elevated IA pressures at some points in its recent history. The pressure is not elevated at this time, and it is possible these anomalies are due to thermal effects. CPAI proposes that the well continue on water injection for a 30-day monitoring period. If the IA exhibits further anomalies during this period, we will pursue additional diagnostics. If there are no further signs of IA pressurization,the well will return to normal status. A 90-day TIO plot is attached. Let me know you have any questions or disagree with the plan. Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED " 9 1 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,May 16,2017 P.I.Supervisor (� 5/ (17 SUBJECT: Mechanical Integrity Tests ( l CONOCOPHILLIPS ALASKA INC 3K-30 FROM: Chuck Scheve KUPARUK RIV UNIT 3K-30 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-30 API Well Number 50-029-22777-00-00 Inspector Name: Chuck Scheve Permit Number: 197-113-0 Inspection Date: 5/9/2017 Insp Num: mitCS170511070310 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-30 Type Inj W' TVD 6579 ' Tubing 1660 1660 1660 - 1660 - PTD 1971130 Type Test SPT Test psi 1645 - IA 1030 2520 ' 2470 - 2470- BBL Pumped: 0.7 BBL Returned: I ' OA 70 - 250 - 250 250 Interval 4YRTST P/F P V Notes: scow .JUL 1 :t 201. Tuesday,May 16,2017 Page 1 of 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. //~'7-' //'--~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items- Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Odginal- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type -OVERSIZED [] .Logs of vadous kinds n Other Complete COMMENTS: Scanned by: sev~y Mildred Daretha~Lowell TO RE-SCAN Notes' Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /si MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,May 15,2013 'P.I.Supervisor �G'` S t?ti 3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-30 FROM: Bob Noble KUPARUK RIV UNIT 3K-30 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-30 API Well Number 50-029-22777-00-00 Inspector Name: Bob Noble Permit Number: 197-113-0 Inspection Date: 5/12/2013 Insp Num: mitRCN130513053906 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 3K 30 'Type J W TV D 6579 - - —_ —I s2o 2210 2190 2180 PTD I9zII3o 'Type Test sPT Test psi 1644 - OA 190 280 280 280 Interval 4YRTST 1P/F ' P ✓'Tubing 2850 2850 2850 2850 Notes: -- - — - -- -- ---- SCANNED FEB 2 0 2014 Wednesday,May 15,2013 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 21, 2012 TO: Jim Supervisor ' l t I 1 ty l 2 ( ,, i P.I. Su i SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K -30 FROM: Bob Noble KUPARUK RIV UNIT 3K -30 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry r NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3K - 30 API Well Number: 50 029 - 22777 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN120205205450 Permit Number: 197 - 113 - Inspection Date: 2/4/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K -30 ' Type Inj. W ' TVD 6581 ' IA 1420 2240 - 2200 2200 - P.T.D 1971130 TypeTest SPT Test psi 1645 ' OA 200 290 290 290 Interval INITAL P/F P Tubing 2850 2850 2850 2850 Notes: KiiibitiEDFEB 3 al Tuesday, February 21, 2012 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ❑ Repair Well 0 Plug Perforations ❑ Stimulate ❑ Other ❑ Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ 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 ❑ • 197 -113 / 3. Address: Stratigraphic ❑ Service El 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 - 50- 029 - 22777 -00 W 00 1 7. KB Elevation (ft): 9. Well Name and Number: RKB 75' r 3K - 8. Property Designation: 10. Field /Pool(s): ADL 25519 ALK 2555 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 10375' feet true vertical 6936' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet 01`' 3NNED MAR :I ti 2012 Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' , SUR. CASING 5727' 7 -5/8" 5802' 4108' PROD. CASING 9810' 5 -1/2" 9885' 6581' RECEIVED PROD. CASING 468' 4 -1/2" 10353' 6921' FEB 0 8 2E2 Perforation depth: Measured depth: 10,026- 10,046, 10,062- 10,082, 10,084- 10,104 Alaska Oil & Gas Cons. Commission true vertical depth: 6683.3 -6698, 6709.5- 6723.9, 6725.4, 6739.8 Anchorage Tubing (size, grade, and measured depth) 3-1/2" , L -80, 9902' MD. TBG Patch FR 9822' - 9852' Packers & SSSV (type & measured depth) Baker GBH -22 Locator Seal Assembly and Sealbore 9884' SSSV= NIP SSSV= 500' 12. Stimulation or cement squeeze summary: NA 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 Casing Pressure Tubing Pressure Prior to well operation NA Subsequent to operation NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ❑ Development ❑ Service Daily Report of Well Operations _X 16. Well Status after proposed work: OHO Gas El WAG El 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 if C.O. Exempt: 309 -029 C Contact Brent Rogers /Kelly Lyons Printed Name .:,. .•'.n Title Problem Well Supervisor Signature Phone 659 -7224 Date dv I - /a, RBDMS FEB b $ -i3 -1 Y Form 10-404 Revised 04/2004 ,,,‘ fX�� Original Only • • ~V • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED Y February 06, 2012 FEB 0 8 2012 Alaska Oil & Gas Cons. Commission Anchorage ! I Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find the 10 -404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 3K-30 (PTD 197 -113) for a Weatherford retrievable tubing patch. Please call Brent Rogers or myself with any questions. Sincerely, Kelly Lyons Problem Wells Supervisor • 3K -30 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary MIT -IA (FAILED). ESTABLISHED LLR OF 5.05 GPM. T /I /O= si2600/2550/10. IA -FL @ SF. Pressured up IA with .5 bbls diesel, T /I /O= si2600/3100/10 15 min T/I/O= si2600/2600/10. Pressured up IA to 3100 in 2 min w/ 14.1 gall. diesel. monitored 3 min bled down to 2700 psi. Pressured up IA to 3100 in 2 min w/ 17.96 gall. diesel. monitored 3 min bled down to 2700 psi. Pressured up IA to 3100 in 2 min w/ 13.41 gall. diesel. monitored 3 min bled down to 2700 psi. Established avg. LLR of 5.05 GPM. Bled IA, T /I /O= si2600/2600/10. 11/22/2011 T -POT (PASSED), T -PPPOT (PASSED) T /I /O= si2600/2600/10 Stung into T -PO with 250 psi. Pressured up to 4700 psi, allowed to stabilize. 15 min reading =4500 psi. 30 min reading =4500 psi. Bled T -PO. IC -POT (PASSED), IC -PPPOT (PASSED) T /I /O= si2600/2600/10 Stung into T -PO with 2400 psi. Pressured up to 3000 psi, allowed to stabilize. 15 min reading = 3000 psi. 30 min reading =3000 psi. Bled IC -PO. SET LOWER PATCH PACKER WITH MID - ELEMENT AT 9852'. CCL TO MID - ELEMENT 1/1/2012 OFFSET 14.8', CCL STOP DEPTH 9837.2'. READY FOR SLICKLINE. TESTED ER PKR @ 9852' RKB WITH TEST TOOL USING NEW WEATHERFORD 2.22" PKG SEAL ASS'Y. CMIT 3200, PASSED. READY FOR UPPER PATCH ASS'Y. * * *CMIT 1/6/2012 pass: Pre TIO= 1950/1775/0, Initial TIO= 3350/3210/0, 15 min = 3340/3190/0, 30 m i n= 3340/3190/0. * * *T SET 32' WEATHERFORD UPPER ER PATCH ASSY' © 9803' SLM, RAN ER PKR TT TO UPPER PKR @ 9769' SLM, TEST GOOD TO 3200 PSI, OBTAINED 3200 PSI MITT & 3200 , 1/10/2012 PSI MITxIA, COMPLETE. * *MITT pass: PreTIO= 1850/1700/0, Initial TIO= 3225/1800/0, 15 ✓ min = 3150/1800/0, 30 min = 3125/1800/0. MITIA pass: PreTIO= 1850/1700/0, Initial= 2000/3200/0, 15 min = 2025/3150/0, 30 min = 2025/3150/0. * ** STATE WITNESSED (BOB NOBLE) MITIA- PASSED (post patch replacement); Initial T /I /O= 2850/1420/200; IA FL @ SF. Pressured up IA (LRS) with .2bbls. of diesel T /I /O= 2/4/2012 2850/2240/290 15min. reading T /I /O= 2850/2200/290 30min. reading T /I /O= 2850/2200/290; Bled IA. Final T /I /O= 2850/1000/210 Summary Set TBG Patch from 9822' to 9852' and conducted passing MITIA • • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, December 06, 2011 3:38 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: Monthly failed MIT report for November 2011 Attachments: CPAI Failed MITIA Monthly Data 11- 11.zip „. s,� E n14 Tom, Jim, Guy Attached is the monthly failed MIT report for November 2011. 1Q -02B was deleted (after a patch was set across CMU, witnessed MITIA performed and 10 -404 were submitted in October). 2T -28 and 3E1-30 were added 1Q-11 was inadvertently deleted from October's report after it had its AA cancelled. It has been added back into November's report and will remain on future reports. Thanks Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 12/7/2011 • • ConocoPhillips Well 3K -30 Injection Data (- • Water Injection 0 Gas Injection I 4000 3500 3000 V I11111111•Ail► • • ♦W • .° 2500 * a 2000 1500: • • 1000 500 • 0 0 1000 2000 3000 4000 5000 Injection Rate, bwpd or mscfpd J Date of Water Gas Tubing IA Pressure OA Pressure Injected Injected Pressure Injection (bwpd) (mscfpd) (psi) (psi) (psi) 30- Nov -11 0 0 1158 2150 20 29- Nov -11 0 0 1465 2150 20 28- Nov -11 0 0 1469 2350 20 27- Nov -11 0 0 1135 2350 20 26- Nov -11 0 0 1181 2450 20 25- Nov -11 0 0 1312 2450 20 24- Nov -11 0 0 1129 2450 20 23- Nov -11 0 0 1630 2550 20 22- Nov -11 0 0 1883 2550 20 21- Nov -11 0 0 2098 2750 20 20- Nov -11 0 0 2557 2750 20 19- Nov -11 0 0 2717 2875 160 18- Nov -11 1427 0 2874 2750 340 17- Nov -11 1561 0 2874 980 340 16- Nov -11 1561 0 2874 1800 320 15- Nov -11 1448 0 2873 1300 250 14- Nov -11 1242 0 2872 1750 1800 13- Nov -11 1238 0 2870 1450 200 12- Nov -11 1154 0 2868 1250 200 11- Nov -11 1411 0 2867 950 200 10- Nov -11 1481 0 2867 1900 300 9- Nov -11 1503 0 2866 1550 300 8- Nov -11 1596 0 2865 1380 300 7- Nov -11 1617 0 2867 1050 250 6- Nov -11 1760 0 2868 900 200 5- Nov -11 1674 0 2863 900 200 4- Nov -11 1650 0 2864 900 200 • • ConocoPhillips Well 3K -30 Injection Data • Tbg Psi • IA Psi • OA Psi I 4000 - 3500 - 3000 - .2 2500 - •1•66 a 2000 - • • 1500 - • ; • • « ■■ • •• • 1000 - ' • • 500 - 0 08/11 09/11 10/11 11/11 12/11 Date J PTD: 197 -113 Failed MITIA 11/16/11 - MITIA/MITOA passed 11/20/11 - IA DDT failed 11/22/11 - MITIA failed, T -POTs & IC -POTs passed 12/2/11 - Slickline identified leaking top PKR in existing patch ConocoPhillips intends to replace existing patch • • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Wednesday, November 23, 2011 2:25 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: FW: KRU Injection Well 3K -30 (PTD 197 -113) Attachments: 3K -30 TIO.pdf; 3K- 30.pdf Tom, Initial diagnostics were a passing MITIA and MITOA on 11/16/11. The well was SI on 11/18/11 due to the communication appeared to become more evident. Following diagnostics now include a failed MITIA on 11/22/11. The suspected leak point is a failed tubing patch that was set in Feb. 2009 under Sundry 309 -029. The plan forward is to troubleshoot the patch which may include the need to pull the upper section if not the whole patch. If the repair is to replace the existing patch, which would include slightly adjusting the length so the packers are set in different locations, would an additional 10 -403 need to be submitted? Following the newly installed patch, a witnessed MITIA would be scheduled and a 10 -404 submitted to show the adjustments. If diagnostics indicate an additional leak, it is ConocoPhillips intention to submit a 10 -403 for the additional patch if needed. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 From: NSK Well Integrity Proj Sent: Tuesday, November 15, 2011 11:34 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)' Cc: NSK Problem Well Supv Subject: KRU Injection Well 3K -30 (PTD 197 -113) Tom, KRU Injection Well 3K -30 (PTD 197 -113) was reported to have suspected TxIA communication. ConocoPhillips intends to leave the well on injection until a diagnostic MITIA can be completed later this week. Additional diagnostic and repair (with the appropriate 10 -403) or AA plans will follow pending the outcome of the diagnostic MITIA. Please let us know if you do not agree with this plan TIO and Schematic are attached and the well has been added to the Monthly injector report. MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 MJ's Cell (907) 943 -1687 • 12/8/2011 Well Name 3K -30 Notes: IA Bleeds Reported Start Date 8/15/2011 Days 90 End Date 11/13/2011 Annular Communication Surveillance 3500 - - -- - 80 3000 - -- L. - 70 _ WHP _ IAP — 60 OAP 2500 WHT — 50 2000 - - - - LL • .— 40 y Q - a 1500 — 30 1000 — 20 500 — 10 0 Aug -11 Sep -11 Oct -11 Nov -11 I •DGI i .m....m GI —PWI u■SWI • 1•BLPD U 2 1500 1000 500 0 r Aug -11 Sep -11 Oct -11 Nov -11 Dec -11 Date • • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, November 23, 2011 3:04 PM To: 'NSK Problem Well Supv' Cc: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: KRU Injection Well 3K -30 (PTD 197 -113) Brent, If the repair is accomplished by working with /modifying the existing patch then no sundry will be required. If an additional leak point is found, you are correct to plan to submit a new 403. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Wednesday, November 23, 2011 2:25 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: FW: KRU Injection Well 3K -30 (PTD 197 -113) Tom, :�ti . .. Initial diagnostics were a passing MITIA and MITOA on 11/16/11. The well was SI on 11/18/11 due to the communication appeared to become more evident. Following diagnostics now include a failed MITIA on 11/22/11. The suspected leak point is a failed tubing patch that was set in Feb. 2009 under Sundry 309 -029. The plan forward is to troubleshoot the patch which may include the need to pull the upper section if not the whole patch. If the repair is to replace the existing patch, which would include slightly adjusting the length so the packers are set in different locations, would an additional 10 -403 need to be submitted? Following the newly installed patch, a witnessed MITIA would be scheduled and a 10 -404 submitted to show the adjustments. If diagnostics indicate an additional leak, it is ConocoPhillips intention to submit a 10 -403 for the additional patch if needed. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 From: NSK Well Integrity Proj Sent: Tuesday, November 15, 2011 11:34 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)' Cc: NSK Problem Well Supv Subject: KRU Injection Well 3K -30 (PTD 197 -113) Tom, KRU Injection Well 3K -30 (PTD 197 -113) was reported to have suspected TxIA communication. ConocoPhillips intends to leave the well on injection until a diagnostic MITIA can be completed later this week. Additional diagnostic and repair (with the appropriate 10 -403) or AA plans will follow pending the outcome of the 11/28/2011 • • Page 2 of 2 diagnostic MITIA. Please let us know if you do not agree with this plan TIO and Schematic are attached and the well has been added to the Monthly injector report. MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 MJ's Cell (907) 943 -1687 11/28/2011 • MEMORANDUM To: Jim Regg ~ c P.I. Supervisor ~ ~ ~ ~~~ ~~ FROM: Chuck Scheve Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 20, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-30 KUPARtJK RIV UNIT 3K-30 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv 3~ Comm Well Name: KUPARUK RIV UNIT 3K-30 Insp Num: mitCS090515165212 Rel Insp Num: API Well Number: 50-029-22777-00-00 permit Number: 197-113-0 Inspector Name: Chuck Scheve Inspection Date: 5/15/2009 Packer Pretest Initial Depth 15 Min. 30 Min. 45 Min. 60 Min. WCi~ 3K-30~Type In,j. W-~ TVD p.T.DL971130 ' TypCTeSt SPT TCSt pSl _^ 6579-~ ~ 1644.75 r- IA j -100 OA 320 - 2220 _ 400 -- 2180 400 12 80 400 Interval aYRTST p~F r i Tubing z7oo 2700 2700 2700 NOteS• Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. Wednesday, May 20, 2009 Page 1 of 1 MEMORANDUM To: Jim Regg ~ ~ 4~Z(o P.I. Supervisor ~j >FItoM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: "Cuesday, April 07, 2009 SIJ II.JF,C:T: nfechanical Integrity Pests CONCX'OP}77LLJPS ALASKA fNCJ 3K-3n KUPARUKRIV lJN7T3K-30 tire: Inspector NON-CONFIDENTIAL Reviewed R,y~~ P.I. Suprv ., )p~-~- Comm Well Name• KUPARUK RIV UNIT 3K-30 Insp Num: mitI,G0903080 1 23 1 8 Rel Insp Num: API Well Number: so-o29-22777-00-00 Inspector Name: Lou cirimaldi Permit Number: t97-113-0 ' Inspection Date: 3-612009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - --- - - -- Well sx 3o a In ~' TVD ~ ~5~3 ~ 1 IA ~ r~J ~ z~~c, -~ ~~~w s~~w ~ T--- - ~ . _ _. P - -_, _ _ ~ _ .__. tv~J t >o sPT I Iv~w ~s d ~ ass ro ~ 7' ~ r~, I.-- '~P T. TypeTest _.....1 Tegt psJ ~ LOA __ _ - - -_.. _.Interv_al.__oTltl:}z _ P/F. P ~ Tubing.. ,J~ 22rxJ I . zzlxJ 2zaJ , ' NOtes: Initial test for post tubing patch instalation. Observed stable pretest conditions for 30 minuta~s to c~onfinn tubing to IA integrity. Good stable test. --'-~ 'I'uc~sday, April 07, 2009 Pa e 1 of ] g u • MAR ~ p 2009 STATE OF ALASKA Alaska Oil & Gas Cons. Commission ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. operations Performed: Abandon ^ Repair Well ^~ ~ Plug Perforations ^ Stimulate ^ Other ~ -}L~`p~n Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ ~@~`~~ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ /~Y" ' ` 2. Operator Name: 4. Current Well Status: 5. Permit to Dri11 Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 197-113 / ' 3. Address: Siratigraphic ^ Service^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22777-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 75' 3K-30 ' 8. Property Designation: 10. Field/Pool(s): ADL 25519 ALK 2555 Kuparuk River Field / Kuparuk Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 10375' • feet true vertical 6936' ~ feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SUR. CASING 5727' 7-5/8" 5802' 4108' PROD. CASING 9810' 5-1/2" 9885' 6581' PROD. CASING 468' 4-1/2" 10353' 6921' 2222 'pp'{{ jr~~ :: ~ ~/ tint Perforation depth: Measured depth: 10,026-10,046, 10,062-10,082, 10,084-10,104 "'`~ true vertical depth: 6683.3-6698, 6709.5-6723.9, 6725.4, 6739.8 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 9902' MD. TBG Patch FR 9834' - 9844' Packers &SSSV (type & measured depth) Baker GBH-22 Locator Seal Assembly and Sealbore 9884' SSSV=NIP SSSV= 500' '~ 12. Stimulation or cement squeeze summary: NA 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 Casin Pressure Tu in Pressure Prior to well operation NA Subsequent to operation NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^~ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: 309-029 ' Contact Brent Rogers/Martin Walters Printed Name Brent Ro rs Title Problem Well Supervisor Signature ~ ~ • Phone 659-7043 Date 3 ~ o ~, ~ ~u.- ,,., ~ -~ 4 „~„~ ~~ - e; ~ 1 ~ ~ 4 x ~ ~ ~ ,~,'~''~' ~~.: x~ r,~; F ~ ;/~I{st<i ~,-` Sub ~ i ~i Form 10-404 Revised 04/2004 6 7"' ~ • i~ ~~'</~f~ • 3K-30 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/29/2001 Summary i RAN A LDL TO DETERMINE LOCATION OF T X IA LEAK. ONLY ABLE TO ESTABLISH A LEAK OF APPROX. 0.05 BPM. RD SPINNER TOOLS AND RU FOR TECWELL LDL. LEAK DETECTED AT CMU SLEEVE LOCATED AT 9836'. SET LOWER PATCH ELEMENT AT 9844'. RAN TEST TOOL TO 9844' ELM. CMIT/ IA TO 2500#. ***PASS***. SET UPPER PATCH ASSY (ECLIPSE PACKER SER# 350082,7.4' SPACER PIPE & SNAP LATCH ASSY/ OAL= 12.18') Cad 9844' ELM, CENTER ELEMENT @ 9834' ELM. MITIA TO 2500#. ***PASS***. JOB COMPLETE CMIT TxIA passed -PRE T/I/0= 500/ 250/ 0. PRESSURE TBG TO 2000#. BGN T/I/O = 2175/ 0. 15 MIN T/I/O = 2390/ 2150/ 0. FINAL T/I/O = 2390/ 2150/ 0. MITIA passed -PRE-MITIA T/I/O = 500/ 250/ 0. PRESSURE IA TO 2550#. BEG T/I/O = 510/ 2550/ 0. END T/I/O = 510/ 2550/ 0. MITIA -PASSED. Initial T/I/O = 2150/500/390. Pressured up IA to 2700 psi with 1.5 bbl diesel. 15 min T/I/O = 2150/2640/390. 30 min T/I/O =2150/2640/390. Final T/I/O = 2150/500/390. State Witnessed MITIA Lou Grimaldi - assed. Post tubin atctY' Initial T/I/0= 2190/610/450. Pressured up the IA with 2 bbls diesel. T/I/0= 2190/2760/730, 15 min T/I/0= 2200/2700/720, 30 min T/I/0= 2200/2700/720. Bled IA. Final T/I/0= 2200/620/440 Set TBG Patch from 9834' to 9844' # • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: Conoco Phillips Alaska FIELD /UNIT /PAD: KRU 3K-30 DATE: 03/06/09 OPERATOR REP: Bates/ Hurley AOGCC REP: Lou Grimaldi Packer Depth Pretest Initial 15 Min. 30 Min. Well 3K-30 Type Inj. W TVD 6,581' Tubing 2190 2200 2200 2200 Interval O P.T.D. 1971130 T pe test P Test psi 1645.18 Casing 600 2760 2700 2700 P/F P Notes: Post Patch MIT-IA OA 455 730 720 720 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well T pe Inj. TVD Tubin Interval P.T.D. T pe test Test psi Casin P/F Notes: OA Well Type In'. TVD Tubing Interval P.T.D. T pe test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring 1=Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R = Intemal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT KRU 3K-30 03-08-09.x1s • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: February 13, 2009 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Casing Repair Petroleum Inspector KRU 3K-30 and 3K-10 ----~ CPA ~ ~~5~-~~~ PTD --- February 13, 2009: CPA Rep. John Arend told me about 2 surface casing repairs that he had going on 3K-30 and 3K-10. John offered me a chance to look them over. I accepted the offer. Summary: I found the two well to be next to each other. Both of them had the conductor pipe and cement removed. I found both wells to have what I would call moderate to heavy pitting on the upper half of the exposed casing. I saw one aprox. 3/8" hole in 3K-30. CPA KRU 3K-30 3K-10 5-22-08.doc • • Attachments: Hole in 3K-30 CPA KRU 3K-30 3K-10 5-22-08.doc • • I w ...~ ~ °. fit' - Bad pit in 3K-30 _~ y Sze I ~s ~` < ~, ;.~,, ~;. CPA KRU 3K-30 3K-10 5-22-08.doc '~' • CPA KRU 3K-30 3K-10 5-22-08.doc } .: Pitting on 3K-10 Confidential: CPA KRU 3K-30 3K-10 5-22-08.doc • S~G~~1 ~ OG ~~',i'~,G!,~Sf~i~l ALASS-A OIL A1~TD GAS CO1~T5ERQA7`IO1~T COMl-II5SIOI~T Brent Rogers Problem Well Supervisor ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510 • SARAH PALlN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~3 Iq'~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 3K-30 Sundry Number: 309-029 Dear Mr. Rogers: ' ~'_@ i' u'`- ~ F ~ " ~ ~ ~A~ 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. Sincerely, r~ Daniel T. Seamount, Jr. Chair DATED this ~ day of February, 2009 Encl. /O~ ~' STATE OF ALASKA ,~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~AN ~ ~ 2OO° '~ APPLICATION FOR SUNDRY APPROVAL ~-(~ 20 AAC 25.280 Alaska Uil & Gas ~c~ns. ~;oml~li~s~xw , 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver At~Or3(~~ Other 0 Alter casing ^ Repair well^ Plug Perforations ^ Stimulate ^ Time Extension ^ Patch Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 197-113 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22777-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO^ 3K-30 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): '~~*;~~~-• ADL 25519 ALK 2555 RKB 75' Kuparuk River Field /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): 10375' 6936' Casing Length Size MD ND Burst Collapse CONDUCTOR 121' 16" 121' 121 SUR. CASING 5727' 7-5/8" 5802' 4108.2 PROD. CASING 9810' S-1l2" 9995' 6580.6 PROD. CASING 468' 4-1/2" 10353' 6920.5 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,026-10,046, 10,062-10,082, 10,084-10,104 6683.3-6698, 6709.5-6723.9, 6725.4, 6739.8 3-1/2" I_-8~ 9902' Packers and SSSV Type: Packers and SSSV MD (ft) Baker GBH-22 Locator Seal Assembly and Sealbore 9884' SSSV= NIP SSSV= 500' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ~ ' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 01/27/09 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brent Rogers/Martin Walters Printed Name rent Rogers Title: Problem Well Supervisor Signature Phone: 659-7224 Date: 01/25!09 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness .~ o f = d~-9 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ ~S ~'~~ ~d~ Other: ~~~ .~f~ Subsequent Form Required: ~~~~ _~ ~~.• r ',; Af ,€ t~fi~ Approved by: COMMISSI N APPROVED BY H COMMISSION Date: Form 0 evised 06/20 ' ~( u~ in Du~l'icat ~,~ • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 JAN ~ ~~(? January 25, 2009 ~1~aska t7il & Gas ~,c~r~: ~ ~ . .,~ , Mr. Jim Regg Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Regg: Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. we113K-30 (PTD 197-113). The request is for approval to patch a tubing . leak above the top packer. Please call Martin Walters or myself at 659-7224 or M J Loveland / Perry Klein at 659- 7043 if you have any questions. Sincerely, /c~~Gu7fi`~ Brent Rogers Problem Well Supervisor Attachments • ConocoPhillips Alaska, Inc. Kuparuk We113K-30 (PTD 197-113) SUNDRY NOTICE 10-403 TUBING REPAIR 01/25/09 This Sundry is a request for approval to repair ConocoPhillips (CPA) Kuparuk We113K-30 (PTD 1971130) with a tubing patch. On November 16, 2008, the AOGCC was notified of suspected TxIA communication. Subsequent diagnostics have identified a tubing to IA leak at the CMD, 9836' MD. The plan is to set an 11' retrievable patch over the CMD. Following a successful MIT, the well will be returned to normal WAG injection. REPAIR PLAN 1. Set 11' 3.5" retrievable patch from 9833' - 9844' with center of the lower element at 9844'. 2. MIT as per AOGCC requirements (0.25 x TVD to packer). 3. Submit 10-404 post repair. NSK Problem Well Supervisor ~^, KUP ~ 3K-30 ~Ot'IOCOP •~j~~i~JS / Well Attributes Ma x An le 8 MD TD ,~ t\" Wellbore API/l1Wl Fla ld Noma Wa ll Status ProN1nJ Type Incl ( °) MD (ftKB) Act Btm (ftKB) 500292277700 KUPARUK RIVER UNIT INJ PWI 56.53 3,508.30 10,375.0 Comment H23 (ppm) Gb Annolatlon End Date K813rd (ftJ Rig Releaaa Data w.llcon : -3KJ0t2/30 iaizsAM SSSV:NIPPLE 0 7/1/2008 LastWO: 41.02 7/2711997 a5c. cat Annotntlon Depth (ftKB) End Deta Anmtation End Date Last Tag: SLM 10,061.0 924/2008 Rev Reason: SLEEVE LEAK 1230/2008 Casin Strin s String O D Stdng ID Sat Deplh Sat Depth (ND) Stdng Wt String Galnp Daacdptlon IIN linl Top (ftKB) (ftKB) (ftKB) pt»m) Grede Stdng Top Thrd CONDUCTOR 1 6 15.062 0.0 121.0 121.0 62.58 H-00 SURFACE 7S 8 6.750 0.0 5,802.0 4,108.2 29.70 L-80 PRODUCTION 51/ 2 4.653 0.0 9,885.0 6,580.6 15.50 L-SO PRODUCTION 41/ 2 3.833 9,885.0 10,353.0 6,920.5 12.75 L-80 cso PArcN, TUbin Strin s 70 SMng O D SMng ID Sat Depth Sat Depth (NO) String Wt String Tu01ng Descdption Ilnl IIN Top (ftKB) IftKBJ (ftKB) (loe/N) Grede Stdng Top Thrd TUBING 31/ 2 2.992 0.0 9,902.0 6,593.1 9.30 L-80 ABM-EUE Other In Hole A ll Jewel : Tubin Run & R etrievable Fish etc. Top Depth (ND) Top Incl CONDUCTOR. 121 Top (ftKB) (RKB) (°) bscdptlon Comment Run Deb ID (in) 10.0 10.0 -0.18 C SG PATCH SURFACE CFISING PATCH: 17 OAL 16" 6 2.5# API SL GR 6114/2008 7.625 B 500.0 499.5 6.55 N IPPLE Camco'DS' 7/1/1997 2.812 9,836.0 6,545.1 43.57 S LEEVE Baker'CMD ';iliding Sleeve w/Selective W -Profile 711/1997 2.812 (Completion documentation IDs sleeve as CMU; field testing NIPPLE, 500 10112/2008 ireiigtes CMD) ) 9,865.0 6,565.9 42.90 P LUG 2.69" WRP 10/1312008 0.000 e 9,884.0 6,579.9 42.98 S EAL Baker'GBH -27 Locator Seat Assembly 7/111997 3.000 9,902.0 6,593.1 43.05 S BE Baker SBE 7/1/1997 3.000 SURFACE,__ ~ ~ Perforations 5,802 Shot lop (ND) Bfm (ND) Dana Top (ftl(B) Blm (RKB) (RKB) (ftKB) Zona Data (sh... Type CommaM 10,026.0 10,046.0 6,683.3 6,698.0 A- 3, 3K-00 72711997 4.0 IPERF 2 1/8" EnerJet, 90 deg. pH 10,062.0 10,082.0 6,709.5 6,723.9 A- 2, 3KJ0 727/1997 4.0 IPERF 2 1/8" EnerJet, 90 deg. pH 10,084.0 10,104.0 6,725.4 6,739.8 A- 2, 3KJ0 726/1997 4.0 IPERF 2 1/8" EnerJet, 90 deg. pH; Oriented SLEEVE, 9,938 I ~ (+/-) 45 deg. FLSH Notes: General 8 Safe End Deta Annoletion 1229/2008 NO TE:.05 BBUMINUTE LEAK FOUND @ 9836' SLEEVE PLUG, 9,885 PRODUCTION, 9,985 SEAL, 9.881 SBE, 9,902 r~ IPERF, 10,028-10,048 IPERF, 10,082-10,092 p IPERF, 10,OBd-10,101 PRODUCTION, i, g{1 ~ •` 10,353 TD, 10,3]5 + ~/~LL L~ .~ ~ _ Tl4A/1/~111~/1~l;4L ~: ,., ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907J 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following 1] 2] Signed Print Name: i/l ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C ~ :rte r~; ~ E ~Y ~ r Anchorage, AK 99518 ~ ~ vY~r ~ ~ ~ ~~ ~ ~ ~l ~ ~s Fax: (907j 245-8952 LeakDetection - WLD 29-Dec-OS 3K 30 1 Color Log / EDE 50-029-22777-00 (~) la-~~l ~3 ~"1 X333 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (807)245-88952 E-MAIL: pc~sara~Yaor~ic~ecC~~rrsernor~lor~.corr' WEBSITE:~~vwjN~rr=~t~aos•~~c,rorra C:\Documenls and Settings\Owner\Desktop\'hanxtnit_Conoco.docx / \ / 1 I i " 1 ' I, `! _ A 1~ pp NO. 5005 Schlumberger -DCS • • 2525 Gambell Street, Suite 400 ~,~nr Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 s, ~° ~ j~:,~~~ /-~$~`°{ Attn: Christine Mahnken ATTN: Beth ~ ° ~°~' `'" "'`"~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date Bl. Color CD 12/17/08 2X-10 11978476 PRODUCTION PROFILE / - ~ 08/17/08 1 1 2V-09 12100460 PRODUCTION PROFILE (p 11/16/08 1 1 1Y-06A 12100461 PRODUCTION PROFILE 11!17/08 1 1 2X-12A 12100464 PRODUCTION PROFILE 9 ~ 11/21/08 1 1 2U-08 12096574 PRODUCTION PROFILE - 11/28/08 1 1 3K-108 12100466 USIT 11/23/08 1 1 3K-30 12097433 LDL .. / 'y 11/28/08 1 1 30-01 12097434 LDL - ~ '} 11 /29/08 1 1 1 E-04 12097436 LDL '1' 11/30/08 1 1 3A-04 12097432 INJECTION PROFILE ~ - 11/27/08 1 1 iH-16 12096581 PRODUCTION PROFILE ~ - 12/05/08 1 1 3A-06 12114994 BAKER LOWER STRADDLE PACKER 11/26/08 1 1 2U-14 12096578 INJECTION PROFILE ~ - j 12/02/08 1 1 1 G-06 12096580 INJECTION PROFILE 12/04/08 1 1 2V-10 12096582 PRODUCTION PROFILE 12/06/08 1 1 3F-01 12086694 PRODUCTION PROFILE - 12/07/08 1 1 2W-14 12086695 INJECTION PROFILE 12/08/08 1 1 1J-102 12086701 INJECTION PROFILE ~ 12/14/08 1 1 i D-07 12114999 USIT _ ~ 12/15/08 1 1 3C-02 12114997 INJECTION. PROFILE ~ 3 12/13/08 1 1 2T-18 12086703 INJECTION PROFILE ~ 12/17/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • 1/V~~L. ~~i.~ ___ ,,, ,.. ~f ~/'f/~-~f 1f~/VI~~Le ProActive Diagnostic 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(Cafiper/ MTT] 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 ,,~; ~~~f 4~~~~ `° Suite C Anchorage, AK 99518 Fa~c (907j 245-8952 1 ] Caliper Report 12-Dec-0B 3K 35 1 Report / EDE 2] Caliper Report 13-Dec-0B 3K 30 1 Report / EDE ~~z~ ~~~- ll3 # l'~~~ Signed Prtint Name: U~'~~~-s ~,,D ~Q ~~ _ 50-029-22775-00 50029-22777-00 Date PROACtIYE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)24b-8951 FAX: (907)245-88952 s--. E-MAIL::~t3sa~cs~ar~ge(a2rsa~rr:®r~tloy,~~raa WEBSITE:~n,rv=~t,rres~t~r~1®c~:~~aa~ .-_~ C:~Doc~nnen6 and Settings\pwnetlDesk[op\Tm~~smit_C~oco.docx III • Memory Multi-i=roger Caliper Log Resins Summary Company: ConocoPhillips Alaska, Inc. Well: 3K-30 Log Date: December 13, 2b08 Field: Kuparuk Log No.: 7286 State: Alaska Run No.: 1 API No.: 50-029-22777-00 Pipe Desc.: 3.5" 9.3 Ib. L-80 ABM-EUE Top Log Intvl.: Surface Pipe Use: Tubing Bot. Log Intvi_: 9,857 Ft. (MDj ~ ~ Inspection Type : Corrosive & Mechanical Damage Inspection ' GOMMENTS This log is tied into the Baker 'CAID' Sliding S/e~eve ~ 9,83'6' (Driller's Depth). 1 This lag was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damage. The caliper recordings indicate that the interval of 3.5" tubing logged is in good to poor condition, with a maximum recorded wall penetration of 52% in joint 279 (8,733'}, An intermittent line of pits, along with scattered pitting, is recorded on the low side of the tubing throughout the deviated interval of the 3.5" tubing logged. Other damage appears as isolated pitting close to surface, and spreads into scattered pitting as depth increases, occasionally broadens into general corrosion. No significant areas of cross-sectional wall loss (> 7%) or LQ. restrictions are recorded throughout the 3.5" tubing logged. MAXIMUM RECORDED WALL PENETRATIONS Line of Pits w/Scattered Pitting (52%) Jt. 279 ~ 8,733 Ft. (MD) Line of Pits w/ Scattered Pitting (50%} Jt. 277 @ 8,661 Ft. (MD) Scattered Pitting (50°k) Jt. 293 @ 9,172 Ft. (MD) Line of Pits w/Scattered Pitting (46%) Jt. 211 (~ 6,610 Ft. (MD) Scattered Pitting (45%) Jt. 175. ~ 5,474 Ft. {MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-.sectional wall toss (> 7%) are recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS No significant LD. restrictions are recorded throughout the interval logged. 4~~~~ JQ~ _ 2d0 Field Engineer: Wm. McCrossan Analyst: HY, Yang Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc, F.O. Bor: 1369; Stafford; Tx 77497 Phone: (281} or (888) 565-9085 Fax: (281) 565-1369 Ei-mail: PDS;~umemoryiog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 v~ ~9~-i 13 ~1~3a~- Correlation of Recorded Daman Pipe 1 3.5 in (9.4' - 9847.1') Well: Field: Company: Country: Survey Date: • ;e to Borehole Profile 3K-30 Kuparuk ConocoPhillips Alaska, Inc. USA December 13, 2008 ^ Approx. Tool Deviation ^ Approx. Borehole Profile 1 ~ .. 13 40 ~ _~ ~; 1259 8(1 2501 120 3756 16th 5003 ~ ~ v Y Z 200 6247 -~ c ' Q. a, o 240 7492 2 £3U 8739 315 9847 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 31 S • • PDS Report Overview ~ s,~ Body Region Analysis Well: 3K-30 Survey Date: December 13, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of I-fingers: 24 Anal st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 ABM-EUE 2.992 ins 3.5 ins 6.0 ins 0.0 ins Penetration and Metal Loss (%wall) ~ penetration body metal loss body 50 2 200 150 100 5 0 0 0 l0 1 to 10 to 1°/, 10% 2U°/, 20 to 40 to over 40% 85% 85% Number of ~oints anal se d total = 322 pene. 0 47 45 loss 74 248 0 221 9 0 0 0 0 Damage Configuration (body ) 300 2 50 200 150 10O 50 0 Isola usi general line ring hole /pons pitting corrosion corrosion corrosion ible hale Number of 'oints dama ed total = 2 71 266 5 0 0 0 Damage Profile (°~ wall) ~ penetration body metal loss body 0 50 0 96 Bottom of Survey = 315 100 196 296 Analysis CNerview page 2 i PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 ABM-EUF Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: ELATION SHEET 3 K-30 Kuparuk ConocoPhillips Alaska, Inc USA December 13, 2008 joint No. Jt. Depth (Ft.) I'~•n. UI~s~~) (In,.l Pen. Body (Ins.) P~~n. % :'vt~•lal I oss ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 9 O .01 5 t) 2.91 PUP 1 13 t~ 0.02 7 2.93 1.1 45 i) 0.01 6 ~' 2.95 PUP 1.2 56 i i 0.02 i3 I 2.95 PUP 2 62 t) 0.01 b I 2.96 3 93 t ~ 0. 1 ~ 2.96 4 124 U 0.03 1 t) I 2.95 5 156 U 0.02 1 2.95 6 187 U 0.02 i I 2 92 7 217 U 0.02 8 ~ 2.93 8 249 U 0.0 i 1 .95 9 280 l) 0.02 t3 2.95 10 312 t) 0.0 7 Z 2.95 11 344 l) 0.02 is _' 2.94 1 375 U 0.02 ii I 2.95 13 407 t) 0.01 o I 2.94 14 438 a 0.02 I 2.93 1 .1 470 (1 0.02 7 I 2.96 PUP 1 .2 475 U 0 0 t ~ 2.81 Camco DS Ni le 4.3 477 t) 0.0 7 I 2.93 PUP 15 483 t) 0.02 i 2.94 16 514 t ~ 0.02 I 2.95 17 546 a 0.02 7 I 2.94 18 578 t) 0.02 ~~ ? 2.95 19 609 t? .96 20 638 n 0.02 I 2.94 21 669 O 0.02 23 .96 22 700 U 0.02 7 1 2.95 3 732 l) 0.02 ti 1 2.95 24 762 i ~ 0.01 ~ I 2.95 25 79 a 0.02 t3 2.94 26 823 t) 0.03 1u I 2.94 27 855 tt 0.03 I s I 2.93 Shallow ittin . 28 887 U 0.02 7 ~ 2.95 9 918 U 0.0 7 I 2.93 30 950 a 0.01 (> I 2.95 31 981 U 0.02 7 I 2.95 32 1013 t) 0.03 12 _' 2.96 33 1043 r ~ 0.02 I 2.94 34 1074 a 0.02 I 2.94 35 110 a 0.09 37 2.96 Isolated ittin . 36 1136 t) 0.06 2~1 I 2.96 Isolated ittin . 37 1167 O 0.02 I 2.93 38 1197 l) 0.03 1(I I 2.95 39 12 9 t ~ 0.02 1 2.95 40 1259 i) 0.03 II I 2.95 41 1288 t) 0.03 1 2.95 Shallow ittin . 42 1320 n 0.02 ti I 2.95 43 1350 ~ ; 0.08 3U I 2.94 Isolated ittin . 44 1379 ~ ~ 0.02 i I 2.93 Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINTTABI, Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 3 K-30 Kuparuk ConocoPhillips Alaska, Inc USA December 13, 2008 Joint No. )t. Depth (Ft.) I'~•n. l Il sc•i (Irn.i Pen. Body (Ins.) Pe•n. `% ~1c~t.~l I „~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 45 1410 i~ 0.03 I ~ 2.95 Shallow ittin . 46 1442 tt 0.06 _'_ 2.95 Isolate itti 47 1472 i) 0.09 i-1 2.94 Isolated ittin . 48 1504 a 0.08 33 2. 5 Isolated 'ttin . 49 1535 a 0. 7 1~~ 2.96 Isolated ittin . 50 1567 t~ 0.07 ~'~~ 2.95 Isolated ittin . 51 1598 l~ 0.08 ~ 1 2.96 Isolated ittin . 5 1629 a 0.02 ~~ 2.96 53 1659 U 0.08 ~ I 2 96 Isolated ittin . 54 1690 U 0.06 < ~ 2.95 Isolated i ti 55 17 0 ~) 0 £; i 2.95 56 1752 t~.Ut, 0.05 'u I 2.94 Shallow ittin . 57 1783 ti .OS 3U ~ .96 Isolated ittin . 5 1815 t ~ 0.02 7 I 2.95 59 1847 U 0.07 _'7 _' .94 Isolated itti 60 1878 t> 0.03 I ~' ~' 2.94 Shallow ittin . 61 1910 t t 0.04 17 2.95 Shallow ittin . 6 1940 t ~ 0.03 I ? I 2.9 63 1972 t~ 0.06 24 i 2.95 Isolated i tin . 64 2001 tt 0.04 15 2.96 Sallow ittin . 65 2032 a 0.05 ~?t) 2.94 Shallow ittin . 66 2064 U 0.09 >3 2.95 Isolated ittin . 67 2094 t~ 006 2.1 _' 2.96 Isol ted ittin . 68 2125 t ~ 0.07 ' 7 2.96 Isolated ittin . 69 2154 ~ ~ 0.03 1 ~ .96 Shallow ittin . 70 2186 t~ 0.08 3U 2.96 Isolated ittin . 71 2217 a 0.07 2£3 2.96 Isolated ittin . 72 2249 t t 0.03 1 1 I 2.95 73 2280 U 0.06 ~-t I .95 tatter d ittin . 74 2312 O 0.05 2'1 1 2.96 Scattered ittin . 5 2344 tI 0.06 22 I 2.95 Sca ered i ~n . 76 2375 ti 0.07 2£3 ~' 2.95 Scattered ittin . 77 2407 ti 0.07 2£i s 2.94 Scattered ittin . 78 2438 it 0.07 2c3 2.96 Scattered ~ttin . 79 2470 t1 0.05 18 I 2.95 Shallow ittin . 80 2501 U 0.07 26 2.96 Scattered ittin . 81 2533 U 0.05 ' 1 I 2.93 Scattered ittin . 82 2563 tt 0.05 ~t1 2.95 Scattered ittin . 83 2595 n.u5 0.06 ~~ 2.95 Scattered ittin . 84 2626 i ~ 0.05 ' i 2.93 Scattered ittin . 85 2658 a 0.06 ' ' i 2.95 Scattered ittin . 86 2689 tl 0.05 1t~ 2.94 Shallow ittin . 87 2721 tt 0.06 2~ ~ 2.94 Scattered ittin . 88 2752 U 0.07 29 ~ 2.95 Scattered 'ttin . 89 2784 a 0.06 ~4 ~' 2.95 tattered ittin . 90 2816 ll 0.05 1 ~) I 2.94 Shallow ittin . 91 2847 t) 0.06 ?2 I 2.95 Scattered ittin . 92 2879 l).(16 0.05 1 E9 2.95 Shallow ittin . 93 2910 li 0.05 1 2.95 Scattered ittin . 94 2942 +~ 0.07 ?~ 2.95 Scattered ittin . _ Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • -LATION SHEET 3 K-30 Kuparuk ConocoPhillips Alaska, Inc. USA December 13, 2008 Joint No. )t. Depth (Ft) I'c~n. lJpsc•t (In;.) Pen. Body (Ins.) Neon. % Meta) Ions "'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 95 2971 it 0.06 2.3 2.95 Scattere ittin . 96 3003 U 0.07 29 ' 2.93 Line of its w scattered ittin . 97 3034 it 0.06 2a ~ 2.95 Line of its w scattered ittin . 9 3066 a 0.08 > I ? 2.94 Line of its w scattere ittin . 99 3 98 l) 0.07 ~(~ ~' 2.96 Line o its w scattered ittin . 100 3129 0 0.06 24 2 2.93 Line of its w scatt red ittin . 101 3161 U_Ob 0.07 _'i ? 2.94 Line of its w scattered ittin . 102 3192 U 0.07 _'ff ? 2.95 Line of its w scattered ittin . 103 3223 (t 0.07 27 2.96 Line of its w scattered ittin . 104 3255 11 0.08 >U 2 2.96 Line of its w scattered ittin . 105 3286 U 0.08 3U ! 2.93 Line f its w s attered ittin . 106 3318 t 0.06 2~; ? 2.93 Line of its w scattered ~ttin . 107 3350 0 0.08 t(t ? 2.93 Line of its w scattered ittin . 108 3381 O.OFi 0.07 2ti 2.92 Line of its w scattered ittin . 109 3411 U.t)6 0.07 't~ 2.95 L'ne of its w scattered ittin . 110 3443 U 0.07 2b _' 2.95 Line of its w scattered ittin . 111 3473 U 0.06 25 _' 2.94 Line of its w scattered it in . 112 3505 U 0.06 ~'<' 1 2.94 ine of its w scattered ittin . 113 3536 0 0.06 24 1 2.94 Line of its w scattered ittin . 114 3567 tt 0.06 2 1 2.95 Line of its w scattered ittin . 115 3598 tt 0.05 20 ? 2.95 Line of its w sca tered i tin . 116 3629 U 0.06 23 2.95 Line of its w scattered ittin . 117 3661 t1 0.05 2U ~ .94 Line of its w scattered ittin . 118 3692 (t 0.07 27 1 2.94 Line of its w scattered ittin . 119 724 it .0 ?;~ I .94 i e f ~ w sc ter ittin . 120 3756 0 0.06 24 2 2.94 Line of its w scattered ittin . 1 1 3786 U 0.07 2t3 l 2.94 Line f its w sc ttered ittin . 122 3818 0 0.06 25 ? 2.93 Line of its w scattered ittin . 123 3 9 tt 0.06 24 1 2.94 Line of ~ w scattered ittin . 124 3880 It 0.05 20 ~ 2.94 Line of its w scattered ittin . 125 391 1 U 0.06 Z4 _' 2.92 Line of its w scattered ittin . 126 3941 U 0.08 3t) 2.93 Line of its w scattered ittin . 127 3973 (t 0.07 2b 2.94 Li a of its w scattered itti 128 4005 U 0.07 2(~ ? 2.93 Line of its w scattered ittin . 129 4035 0 0.06 Z4 1 2.92 Scattered itti 130 4064 U 0.05 20 2.94 Scattered ~ttin . 131 4096 tt 0.08 ~1 > .94 Scatered ittin . 132 4127 tt 0.05 2~) 2.94 Line of its w scattered ittin . 133 4159 tt 0.09 t(, .94 Line of its w scattered ittin . 134 4190 Ct 0.06 1:3 I 2.94 Line of its w scattered ittin . 135 4221 a 0.06 24 ~ .93 Line f its w scattered ittin . 136 4252 l) 0.06 24 2 2.93 Scattered ~ttin . 137 4282 ~ 0.05 2U 2 2.95 Shallow ittin . 138 4313 it.tt5 0.06 _' ~ 2 2.94 Scattered itti 139 4344 U 0.06 ~'_' 1 2.94 Scattered ittin . 140 4376 t~ 0.06 ~ 3 3 2.95 Scattered ittin . 141 4407 tt 0.06 24 2.94 Scattered ittin . 142 4439 ! t 0.06 Z-1 s 2.93 Scattered ittin . 14 4470 0.07 29 _' 2.94 Scattered ittin . 144 4502 ~ 0.06 i 2.96 Scattered ittin . _ Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L$0 ABM-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: ELATION SHEET 3 K-30 Kuparuk ConocoPhillips Alaska, Ins USA December 13, 2008 Joint No. Jt. Depth (Ft.) I'~~n. UI,SC~t (Irn.) Pen. Body (Ins.) I'c~n. % '~1c~t.~l Lois °-~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 145 4533 (1 0.06 24 _' 2.94 calf red ittin . 146 4565 U 0.06 22 _' 2.93 Scattered ittin . 147 4596 tl 0.05 2tl ,' 2.94 Shallow ittin . 148 4628 U 0.06 2 7 ? 2.95 Scattered itti 149 4659 U 0.06 24 2.92 Scattered ittin . 150 4691 U 0.07 27 3 Z. 5 Scatte ed ~ttin . 151 4722 t) 0.05 ~' 1 ? 2.91 Scatt red ittin . 152 4754 (1 0.06 24 2 2.94 S tiered ittin . 153 4786 t) 0.07 27 1 2.93 Scattered ittin . 154 4817 l) 0.07 Z6 2 2.93 Scattered ittin . 155 49 1) 0.07 26 ' 2.94 tattered ittin . 156 4879 t) 0.06 2;3 2.93 Scattered ittin . 157 4910 (1 0.06 22 _' 2.94 Line of its w scattered ittin . 158 4941 t~ 0.05 ~ I 1 2.95 Line of its w scattered ittin . 159 497 a 0.07 26 _' 2.94 Line of its w scat ered ittin . 160 5003 l~ 0.06 22 ! 2.94 Line of its w scattered ittin . 161 5035 O.U6 0.06 24 2 2.95 Corro ion. 162 506 (~ 0.08 33 ' 2.94 Line of its w sc tiered ittin . 163 5097 O 0.05 19 _' 2.94 Shallow ittin . 164 5128 U 0.08 31 _' .93 Scattered ittin . 165 5158 t~ 0.06 24 2.94 Scattered ittin . 166 5189 t~ 0.07 27 2.94 Line of its w scattered ittin . 167 5221 U 0.07 27 _' 2.94 Scattered ittin . 168 5250 tl 0.06 24 _' 2.95 Scattered ittin . 16 8 (~ 07 2£3 ~ .92 Sc tiered itti 170 5313 U 0.05 21 ~' 2.95 Scattered ittin . 171 5345 t) 0.06 24 2 2.95 Scattered ittin . 172 5375 t) 0.07 213 2.94 Scattered ittin . 173 5407 U 0.08 ~ 1 ? 2.92 Scattered ittin . 174 5438 t) 0.07 2U ~ 2.94 Scattered ittin . 175 5470 a 0.12 45 2.94 Scattered ittin . 176 5501 U 0.05 20 I 2.94 Scattered ittin . 177 5533 a 0.06 2 ~ 2.93 Scattered itt n . 178 5564 a 0.05 2U ~ 2.93 Shallow ittin . 179 5595 t~ 0.06 25 2.95 Scattered ittin . 180 5626 ~~ 0.06 22 2.94 Scattered ittin . 181 5657 i~ 0.07 213 2.93 calf red ittin . 182 5688 11.05 0.06 22 2.94 Scattered ittin . 183 5719 l) 0.05 211 2.96 Sallow ittin . 184 5751 t) 0.05 1 ~) 2.95 Shallow ittin . 185 5782 t1 0.07 3U 2.94 Scattered ittin . 186 5813 U 0.06 22 ~ 2.95 Scattered ittin . 187 5845 t1 0.05 21 1 2.94 Scattered ittin . 188 5875 U 0.07 27 ? 2.94 Scattered ittin . 189 5907 t) 0.06 24 ~ 2.9 Scatt red ittin . 190 5938 11 0.04 17 _' 2.94 Shallow ittin . 191 5969 11 0.06 22 _' 2.95 S altered ittin . 192 6000 1) 0.07 ~(~ _' 2.95 Scattered ittin . 193 6031 U 0.05 ;' 7 _' .9 Scsittcred ittin ~. 194 6061 t1 0.09 _' 2.94 Sc.ittcred ittin ' Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 3 K-30 Kuparuk ConocoPhillips Alaska, Inc USA December 13, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Ul,tic~( (Irn.) Pen. Body (Ins.) Pen. % fvlc~t,,l I ~>s~ °<, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 195 6092 O 0.07 2t3 2.93 Scattered i tin . 196 6123 a 0.06 24 _' 2.93 Scatt ed ittin 197 6155 t) 0.06 25 _> 2.93 catte ed ittin . 198 61 6 t~.u ; 0.06 _'=1 1 2.95 Scattered ittin . 199 6215 U 0.06 24 ? 2.93 Sca eyed ittin . 200 6247 l) 0.05 ~ 1 ~' 2.95 Scattered ittin . 201 6278 l) 0.04 1 i ? 2.95 Shallow ittin . 202 6309 t) 0.07 2f3 2.94 line of its w scattered ittin . 203 6340 l) 0.06 22 _' 2.95 S ttered "ttin . 204 6372 O 0.05 19 2.94 Shallo ittin . 205 6403 O 0.06 Z2 _' .95 ine of its w sc ttered ittin . 206 6435 0 0.07 26 .94 Line of its w scatter d i ti 207 6465 t) 0.0 _'d 2.95 Line of its w s attered ittin . 208 6497 I) 0.05 ~ 1 2.94 Line of its w scattered ~ttin . 209 6528 O .06 '< ! .93 Line of its w scattered ittin . 210 5 9 U 0.05 ' 1 2.92 Line of its w scatte ed ittin . 211 6591 t) 12 4i, .94 Line of its w scatte ed ittin . 21 6622 U 0.08 3 I 2.94 Scat ered ittin . 213 6654 t) 0.05 21 _' 2.94 Scattered ittin . 214 6685 i) 0.06 24 I 2.94 Scattered i in 215 6717 t).i)5 0.07 28 2.94 S ttered ittin . 216 6746 U 0.07 17 2.94 Line f its w scattered ittin . 217 6778 U 0.09 35 t 2.93 Line of its w scattered ittin . 218 6809 U 0.06 Z"~ _' 2.95 Scattered ittin . 2 6 4 U 0.07 £3 2. S ter itt~n . 220 6871 i).O5 0.06 2~1 _' 2.95 Scattered ittin . 221 6901 i) 0.05 21 2.9 Scattered ittin . 222 6933 U 0.06 24 I 2.93 Scattered ittin . 223 6963 tl 0.0 2U 2.96 Scattered ittin . 224 6995 t) 0.08 > 1 2.94 Line of its w scattered ittin . 25 0 6 t) 0.05 1 ~~ I 2.93 Shall w ittin . 226 7058 (I 0.07 Zt3 _' 2.95 Scattered "ttin . 227 7088 l) 0.08 i I 2.95 Line of its w scattered ittin . 228 7120 U 0.08 31 I 2.93 Scattered ~ttin . 229 7151 tl .06 24 I 2.92 Scattered ittin . 230 7183 t) 0.06 2 3 _' 2.93 Scattered 'ttin . 231 7213 (~ 0.08 3(1 ~' .93 c tter ittin . 232 7244 a 0.05 1') I 2.93 Shallow ittin . 233 7276 n 0.05 1 S) _' 2.93 Shallow ittin . 234 7308 i) 0.05 ZU 2.94 Shallow ittin . 235 73 t) 0.07 i .94 Scatt ed ittin . 236 7370 U 0.06 24 _' 2.94 Scattered ittin . 2 7 7399 t) 0. 6 2a I 2.94 Scattered ittin . 238 7430 t~ 0.06 22 .' 2.94 Scattered ittin . 239 7462 t) 0.07 ~" 2 2 94 Scattered it "n . 240 7492 U 0.05 19 2 2.92 Shallow ittin . 241 7524 a 0.07 29 _' 2 9 Line of its w scattered ittin . 242 7554 t) 0.06 22 2.94 Scattered ittin . 243 7585 t) 0.07 213 2.95 Sc~ilered ittin ~. 244 7617 n 0.07 26 2.94 S<~atte>rcd >ittin ~. Penetration Body Metal Loss Body Page 5 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 ABM•EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~ LATI O N SHEET 3 K-30 Kuparuk ConocoPhillips Alaska, Inc USA December 13, 2008 Joint No. Jt. Depth (Ft.) I'E~n. Ul~se t (Im.) Pen. Body (Ins.) I'c~n. %, Mct,il I oss `% Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 245 7647 (~ 0.09 34 2 2. 3 Scattered ittin . 246 767 a 0.05 2U 2 2.93 Scattered ittin . 247 7710 t) 0.05 ~i) ~' 2.93 Scattered ittin . 248 7743 U 0.05 't1 I 2.93 S ttered ittin . 249 7774 l) 0.06 1_i _' 2.94 Scattered ittin . 50 7805 ~) 0 D7 2U 2.94 Scattered ittin . 251 78 7 t) 0.05 1 Y3 1 2.93 Shallow it in . 25 7869 a 0.06 24 ~' 2.93 Scattered ittin . 53 7899 l) 0.10 at3 _' .95 Line of 'ts scattered ittin . 54 7930 t) 0.0 at> 2.93 Lin of its w sc ttered ittin . 255 796 ~ 0.0 ~~~ ~' 2.93 ine of its w s attere ittin . 256 7993 U 0.08 ~ 1 2 .95 Line f its w scattered ittin . 257 8025 t) 0.05 'U 2.95 hallow ittin . 258 8055 t) 0.08 SU _' 2.95 Line of its w scattered ittin . 259 8087 U 0.07 16 2.95 ine of its w scattered itti 260 8118 U 0.07 3O _' 2.95 Scattered ittin . 261 8150 U 0.10 X11 ; 2.95 Line of its w scattered ittin . 262 8181 U 0.0 2U 2.94 Shallow itti 263 8212 U.t)h 0.07 2B 7 2.95 Scattered ittin . 264 8244 i) 0. 6 1~1 2.94 Scattere i tin . 265 8275 a 0.05 ? 1 I 2.94 Line of its w scattere ittin . 266 83 t) 0.07 26 2.94 Line of it w scattered it in . 267 8337 t) 0.07 2E: 2.93 Line of its w scattered ittin . 268 8368 l) 0.08 a 1 2.93 Line of its w scattered ittin . 9 8400 U 0.08 3t) .' .9 in f ~ts w scat ere ittin . 270 8429 t) 0.08 i2 ? 2.95 Scattered ittin . 271 8458 t) 0.05 ~' 1 ~ 2.94 Scattered ittin . 272 8489 t).t)t~ 0.06 1~ 2.94 Scattered ittin . 273 8519 U 0.06 ?4 2.93 Scattered ~ tin . 274 8551 t) 0.09 >5 2.95 Line of its w scattered ittin . 27 8582 t) 0.0 ~' 3 2.94 Line of its w scattered ittin . 276 8614 U 0.07 >t) _' 2.93 Line of its w scattered ittin . 277 8645 U 0.13 5U ~' 2.95 Line of its w scattered ttin . 278 8677 U 0.08 32 ~' 2.94 Line of its w scattered ittin . 279 8708 U 0.13 52 7 2.96 Line of its w scattered ittin . 280 8739 l) 0.09 3' _' .93 Line of its w scattered ittin . 281 8771 t).U6 0.06 2 i ? 2.96 Line of its w scattered ittin . 282 8800 U 0.09 3; 2.91 Line of its w scattered ittin . 283 8831 ! ~ 0.08 } I 2.94 Line of its w scattered ittin . 284 8863 U 0.09 3i 2.94 Scattered ittin . 285 8894 U 0.08 i l 2.93 Scattered ittin . 286 8926 U 0.09 3t~ 2.95 Scattered ittin . 287 8958 U 0.07 2~) ~ 2.96 Scattered ittin . 288 8989 O 0.07 Z7 Z 2.94 Scattered ittin . 89 9020 U 0.09 35 ~' 2.93 Scattered ittin . 290 9052 t~ 0.05 21 _' 2.95 Scattered ittin . 291 9083 t? 0.06 ~-1 _' 2.95 Scattered ittin . 292 9114 ~ ~ 0.10 a I ~ 2.94 Scattered ittin . 293 9146 U 0.13 i 2.92 Scattered ittin . 294 9177 a 0.08 ~ 2.94 Scattered ittin . Penetration Body Metal Loss Body Page 6 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Body Wall: 0.254 in Upset Wall: 0.254 in Nominal I.D.: 2.992 in Well: 3 K-30 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: December 13, 2008 Joint No. Jt. Depth (Ft.) I'~~n. U~~s~~i (Irn.) Pen. Body (Ins.) Pen. %~ Mci~~l L~~~~ ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 295 9207 t) 0.06 2 2.93 Scattered ittin . 296 9239 U 0.07 26 ! 2.94 Scattere ittin . 297 9270 c~ 0.06 25 2.93 tattered ittin . 298 9302 U 0. 6 22 .94 Scattered itti 299 9331 U_l15 0.09 a4 i 2.94 Line of i w scattered ittin . 30 9363 ~~ 0.07 Z6 2.95 Line of its w scattered ittin . 301 9393 ~ ~ 0.1 1 -15 2.93 Line of its w scattered ittin . 302 9425 a 0.07 - 2.95 Scattered ittin . 303 9456 U 0.06 23 2.95 Scattered ittin . 304 488 U 0.08 31 ~ 2.93 Scattered ittin . 305 951 l~ 0.09 i ~ 2.93 Scattered ittin . 306 9549 (~ 0.08 SC! - 2.96 Line of its w scattered ittin . 307 9580 ~~ 0.08 ~ i 2.93 Line of its scattered ittin . 308 9611 ~~ 0.08 ~~~ 2.95 Line of its w sc ttered ittin . 309 9642 U 0.10 4(1 2. 6 Lin of its w scattered ittin 310 9673 i ~ 0.0 ~ i .94 Line of its w scattered ittin . 311 9704 ii 0.0 35 _' .95 Line of its w scattered it in . 312 9735 U 0.08 3U 2.93 Line of its w scattered ittin . 13 9767 ~~ 0.11 43 -1 .94 Line f its w scattered ittin . 314 9798 t~ 0.08 1 ~ 2.94 ine f its w scattered ittin . 314.1 9830 a 0.02 6 _' 2.95 PUP 314.2 9836 l1 0 O ~~ 2.81 Baker'CMD' Slidin Sleeve 3 4.3 9841 ~~ 0.02 - 2.94 PUP 315 9847 a 0.08 ~ ~ 2.95 Line of its w scattered ittin . ,_ Penetration Body Metal Loss Body Page 7 ~~ y ~~I;..~ PDS Report Cross Sections Well: 3K-30 Survey Date: December 13, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 ABM-EUE____ _ _ _ _ Analyst: HY. YanR Cross Section for Joint 2 79 at depth 8732.934 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 94 Tool deviation = 64 ° Finger 3 Penetration = 0.132 ins Line of Pits 0.13 ins. = 52% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 ~-~u ~~. PDS Report Cross Sections Well: 3K-30 Survey Date: December 13, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f _L-80 ABM-EUE Analyst: HY. Yan>? Cross Section for Joint 2 77 at depth 8661.32 ft Tool speed = 44 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 98 Tool deviation = 52 ° Finger 3 Penetration = 0.126 ins line of Pits 0.13 ins. = 50% Wall Penetration HIGH SIDE = UP i • Cross Sections page 2 ARCO Alaska, Inc.A GKA 3K-30 atc~o API: 500292277700 Well T e: INJ An le TS: 44 de 9838 SSSV Type: Camco'DS' Nipple Orig Completion: An le ® TD: 43 deg ~ 10375 Annular Fluid: Last W/O Rev Reason: Tag fill by Imo Reference Lo Ref Log Date: Last Upd ate: 10!25/99 NIP (504501 Last Ta : 10106 TD: 10375 ftKB , OD:3 500) Last Tag Date: 8/13/99 Max Hole An le: 57 deg 3508 . CBS In Strin -CONDU CTOR TUBING asso2 Size To Bottom TVD Wt Grade Thread ( 16.000 0 121 121 62.58 H-00 OD:3.500, ID 992 2 Cas in Strin -SURFA CE : ) . Size To Bottom TVD Wt Grade Thread PROD. 7.625 0 5802 4108 29.70 L-80 CASING Casin Strin -PRODU CTION (49885' OD 5 500 Size To Bottom TVD Wt Grade Thread : . , 15 5 5.500 0 9885 6581 15.50 L-80 Wt . 0) 4.500 9885 10353 6920 12.75 L-80 Tubin Strin -TUBIN G Size To Bottom TVD Wt Grade Thread 3.500 0 9902 6593 9.30 L-80 ABM-EUE Perforations Summar SLEEVE Interval TVD Zone tatu Fee P Date T e Comment (~~~ 10026 - 10046 6683 - 6698 A-3 20 4 7/27/97 IPERF 90 deg. hasin 2 1/8" EnerJet 5 10062 - tOD82 6709 - 6724 A-2 20 4 7/27197 IPERF 90 de .phasin g; 2 1/8" EnerJet OD 4. 00) I I 10084 - 10104 6725 - 6740 A-2 20 4 !26/97 IPERF 90 deg. phasing; Oriented (+/_) 45 deg. FLSH; 2 1/8" EnerJet Other lu s e ui .etc. -JEWELRY De th TVD T e Descri tion ID 500 500 NIP Camco'DS' 2.812 9836 6545 SLEEVE Baker'CMU' Slidin Sleeve w/ Selective Profile 2.812 9884 6580 SEAL Baker'GBH-22' Locator Seal Assembl 3.000 9902 6593 SBE Baker 3.OOD SEAL 98849902 ( , OD:4.000) Pert (10026.10046) PROD. CASING (9885.10353, OD 4.500, Wt:12.75) Per( (10062-10082) Per( (1008410104) 3K-30 (PTD 197-113) Report Of TxIA Communication Page 1 of 1 • • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, November 16, 2008 2:30 PM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF3 Prod Engrs; CPF3 DS Lead Techs; Glessner, Dana ;Maunder, Thomas E (DOA) Subject: 3K-30 (PTD 197-113) Report Of TxIA Communication Attachments: 3K-30 Wellbore Schematic.pdf; 3K-30 TIO Plot.ppt ~ Jim, f Kuparuk injector 3K-30 (PTD 197-113) was discovered to have TxIA communication in the course of setting a plug for 3K- 103 drilling proximity. The well has been shut in since 9/24/08 and is currently secured with a plug installed at 9,865'. It will be added to the Monthly Failed MIT Report. ConocoPhillips plans to inject water as necessary to diagnose the nature of the communication and will submit a 10-403 or 10-404 to repair as appropriate or an application for administrative approval to continue injection. Attached are an updated 90 day TIO plot and Wellbore schematic. «3K-30 Wellbore Schematic.pdf» «3K-30 TIO Plot.ppt» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 11 /28/2008 dwal~a~oy~ o ~°n o ~° o M M ~- ~ °- fi i O M 0 a 4 H dl 0 -- - ~ °o © °o ~ - o ~n o ,~ N r- ~ 00 0 0 Z 0 00 O i U ~ ~ Q r 0 00 0 a a~ 0 ISd "- .. KUP 3K-30 s ~~~~~~(~~~~~~ ~ ~ I P !Well Attributes _ - ~.- ~ _ _ _ - WeNbore AP{IUWI Fleltl Name 'Weh Slalu. F aJ,:..I LY.II Incl l'I ~.~U (It .F:/ STD (mu)Itt... 500292277700 KUPARUK RIVER UNIT INJ 56.53 3,508.30 10,375.0 Comment H25 (ppm) Date Annotation End Data KB-Grd (N) Rig Relesae Dele ~~~ lszoos SSSV: NIPPLE 0 7/1/2008 Last WO: 41.02 7/27/1997 _ _ ~_ ~~~_ ~-~.~~. ( ____ Annotation Depth (NKB) Entl Dste Annotation End Date Last Tag: SLM 10,061.0 9/24Y2008 Rev Reason: SLEEVE NOTE __ 11/14/2008 !i Casing SVings String OD String ID Set Depth Set Depth (ND) String Wt String Casing DeacripNon tin) (in) Top (NKB) (NKB) (NKB) (Ibs/it) Gretle String Top ThrO ~, CONDUCTOR 16 15.062 0.0 121.0 121.0 62.58 H-00 SURFACE 75/8 6.750 0.0 5,802.0 4,108.2 29.70 L-80 ~ PRODUCTION 51/2 4.653 0.0 9,885.0 6,580.6 15.50 L-80 csGPATCH. -:j PRODUCTION 4 1/2 3.833 Tubin Strings 9,885.0 10,353.0 6,920.5 _ 12.75 L-80 10 . ,g uL t ulriug ID Sat Lwpu. u t Dsplh (ND) String WI String ~ Tubing Desoiptlon On) ~ I tin) Top (NKB) (ftK8) I (NKB) Qba/N) Grade I String Top Thrd ITUBING 31/2 2.992 0.0 9,902.0 6,593.1 9.30 L-80 ABM-EUE ~ Other I n Hote (AII Jewelry: Tubing Run & Retrievable, Fish, etc.) __.. .. .., 1 T pD plh (ND) ToP CONDUCTOR, 121 { Top (NKB) (ftK8) Inel (°) Deacription Comment Run Date ID (in) NIPPLE, SLEEVE, 9,836 PLUG, 9,865 I 1 ?~ -~ ~- ~: I r~, yll~, i. ~. PRODUCTION, ! -- 9,885 REAL. 9,884 ~ t~ fr 88E, 9,902 IPERF, 10,026-10,046 IPERF, 10,062-10,082 IPERF, 10.084-10.104 (Completion documentation IDs sleeve as CMU; field testing 10112/2008 indicates CMD) Perforations Top (ND) Btm (ND) Top (NKB) I Btm INKeI I (NKB) (kKB) I Zone Shot Dens Date lah... (+/-) 45 deg. PRODUCTION, 10,353 TD, tU,3]5 ~ ~ STATE OF ALASKA a~~s!_ o ~ 20~~ ALASKA OIL AND GAS CONSERVATION COMMISSION 8 ~3 (~i~ ~~~ C~}, ~Ol~'i~ ~t~81t:361 REPORT OF SUNDRY WELL OPERAT~~VS A~~ ~; ~~~~ 1. Operations Performed: Abandon ^ Repair Well ~ ~ Plug Pertorations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ 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 ^ 197-113 / 3. Address: Stratigraphic ^ Service /^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22777-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 75' • 3K-30 8. Property Designation: 10. Field/Pool(s): ADL 25519 ALK 2555 Kuparuk River Field /Kuparuk Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 10375' ~ feet true vertical 6936' feet Ptugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SUR. CASING 5727' 7-5/8" 5802' 4108' PROD. CASING 9810' 5-1/2" 9885' 6581' PROD. LINER 468' 4-1/2" 10353' 6920' Perforation depth: Measured depth: Intervals between 10026 - 10104' ~~~,NRI~® JUL :~ ~ 200$ true vertical depth: Intervals between 6683 - 6740' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 9902' MD. Packers &SSSV (type & measured depth) Baker GBH-22 Locator Seal Assembly and Sealbore 9884' SSSV=NIP SSSV= 500' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volume s used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation na na na na na Subsequent to operation na na na na na 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ ' Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ 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 if C.O. Exempt: 306-408 Contact Perry Klein / M.J. Loveland T Printed Name M.J. velan Title WeII Integrity Project supervisor ~.•''~~ ~ ..`y Signature j''~/ ~ ~~/ ~ ,, t Phone Date ~ ~ - nf !Y~ d '" ~ ~Cl JUL. 1 t LUUf} ' Form 10-4 4 Revised 04/2004 ~ ~ ~ ^ ~ ~ [~y ~ Submit Origina~~, y~--/'~y}~ • 3K-30 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 5/19/2008 Nitrogen purge IA @30 cfu,OA@70 cfu.Cut and removed 12' of conductor, chip out cement. 5/22/2008 Notified State man (Noble) to witness damage to SC 6/12/2008 6/18/2008 6/19/2008 SC patch weld -Complete. Purge nitrogen while welding 5' SC patch -used 8" .500 wall X65 pipe for collars & 9 5/8" .395 for sleeve. Top of patch ties into Mandrel Hanger. Patch Welded as per M.E. SPECS. Installed IA VR Plug and normal annulus jewelry w/2000# & 4000# gauges.MITOA- PASSED.Initial T/I/0=0/0/0. Pressure up SC to 1800.T/I/O=0/0/1800. START T/I/O/=0/0/1800.15 min T/I/0=0/0/1700, 30 min T/I/0=0/0/1680, 45 min T/f/O=0/0/ 1660, 60 min T/I/0=0/0/1660.Final T/1/0=0/0/0. Wrapped SC in DENSO TAPE. Installed new Conductor ,12' of 16" 62.5# API 5L GR B Conductor casing.Removed heater hose from excavation. 6/23/2008 Pum ed 1.7 bbls. of class G 15.8 PPG cement in conductor w/in 6" of surface. 6/25/2008 To ed off conductor casin with 2 allons RG-2401 sealant. T/I/O = SI/5/20. r.' ~, ~ a ~ y7 1 ~ 9'd~ tyy ~.. -#~ ,~~r ,5 dip: - ~ . :.. .. ~p ~ ~ . - ~ y .. ~j lk f y°y~~ .., y .~+: ~ ~ . , 1 r -rte •~I...fis .. A,4z '~''(+OriOCO~hllh~ls .-~l~lS~.i1, I11C This photo is copyright by ~'onocoPhillips _~laska, Inc. and callllot be released or published «~ithout elpress «~rittell ~ ~:~ntiCllt ~:~t { +~:~Il~?C~:~~~1lllllp~ _~l~-t`~~~~1 "~ 5 a 3 i ~: ~ ~ € i F • • ~~%_ #~`.. ~r _ • .~~ .4.. h r* ='onc~~oPhillips _alask~, Ins 1S 1)llOtO is LC)p~'1'l~llt ~~- (_'c~11c~~c~F'hillips Alaska, Ills. ~l LallllOt bz l~lzaszd Ol ptlb11s11zCl ~z"ltllOllt z11)lzss lttZll LOllszllt Of ~_~~~110COP1111111)s ~las~a MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '~~r~ ~j~,~~,~~ DATE: May 30, 2008 P. I. Supervisor ;, , 1 ,: FROM: Bob Noble SUBJECT: Surface Casing Repair Petroleum Inspector ~ KBU 3 C~-10 (PTD~-163) KRU 3K-30 (PTD 197113 CPAI Mav 30, 2008: CPA Rep. John Arend told me about 2 surface casing repairs that he had going on 3K-30 and 3K-10. John offered me a chance to look them over. I accepted the offer. Summary: I found the two wells to be next to each other. Both of them had the conductor pipe and cement removed. I found both wells to have what I would call moderate to heavy ~' pitting on the upper half of the exposed casing. I saw one approximately 3/8" hole in 3K-30. Attachments: photos (4) ~HE~ JUh ~ ~ 2008 • • @(RlJ 3K~10, 3FC~30 (CPAI) Sunt'ace using C®~°~®s~®n Photos by Bob Noble IVlay 22, 2008 Hole in Surface Casing -KRU 3K-30 Bad Pit in Surface Casing -KRU 3K-30 :7 Pitting on Surface Casing -KRU 3K-30 Pitting on Surface Casing -KRU 3K-10 . . SARAH PALIN, GOVERNOR AI4ASIiA. OIL AND GAS CONSERVATION COMMISSION MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~ql' t 1:3 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3K-30 Sundry Number: 306-408 Dear Ms. Loveland: (9~C'4~É~r~Eùj 'J¡ ",~) ('0 i) 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. Sincerely, DATED this ,;(day of December, 2006 Encl. . ~/ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 25,2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find the 10-403 Applications for Sundry Approval for ConocoPhillips Alaska, Inc. wells 3K-30 (197-113) and 3K-22A (200-026). The request is for approval to excavate, inspect and repair the surface casings for external corrosion. Please call Jerry Dethlefs or me at 659-7043 or Marie McConnell or Perry Klein at 659- 7224 if you have any questions. ...-r.........' ;;~' WL~ Problem Well Supervisor Attachments · OF.> 14'2.7/. RECEIVED STATE OF ALASKA Q(;)"I __ ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 2 6 2006 APPLICA TION FOR SUNDRY APPROV A~aska Oil & Gas Cons. COOlmission 20 MC 25.280 Anchoraae 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 197-113 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, AnchoraQe, Alaska 99510 50-029-22777-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes 0 No 0 3K-30 9. Property Designation: 10. KB Elevation (ft): 11. Field/PooI(s): ADL 25519 ALK 2555 RKB 75' Kuparuk River Field / 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): 10375' 6936' Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121 SUR. CASING 5727' 7-5/8" 5802' 4108 PROD. CASING - 9810' 5-1/2" 9885' 6581 PROD. CASING 468' 4-1/2" 10353' 6920 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Intervals between 10026 - 10104' Intervals between 6683 - 6740' 3-1/2" L-80 9902' Packers and SSSV Type: Packers and SSSV MD (ft) Baker GBH-22 Locator Seal Assembly and Sealbore 9884' SSSV= NIP SSSV= 500' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: March 1, 2006 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 G/NJ 0 WINJ 0 WDSPL 0 Commission Representative: /' 18. 'h,,,,by œrt'" th" th, to""o'"" i, true eo' oo~ow"'" Contact: MJ Loveland/Jerry Dethlelfs Printed Name MJ Loveland L Title: Well Integrity Project Supervisor Signature ~/ ~ Phone 659-7043 Date 12/25/06 ,. /1 v Commission Use Onlv ( sund~mber: ð Conditions of approval: Notify Commission so that a representative may witness ~ I/ok4{) Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other:\-JcV\~ ~~<:.-\C~-{fj\-C)~~\~~~ \ð ~,\-~~"> ~~<>-~ (~ ~~~\-, .S,b"q,,,tFonn Reo""'" 40 \.-~ -..0 I I \ ~C5':>~ ",~\A() "- <::f:ç ~ ()~1'c [~\r:,. - - - R8DMS BFt 271UO'~:I I I ~Á APPROVED BY Date: 12-1-:)..-/;b Approved by: ~./ oÇl),IVIMIS£ONER THE COMMISSION Form 10-403 Revised 06/2006 l) tm -¡ I' ~__ Submit ill Duplicate . . ConocoPhillips Alaska, Inc. KuparukWe1l3K-30 (PTD 197-113) SUNDRY NOTICE 10-403 APPROVAL REQUEST December 25, 2006 This application for Sundry approval for Kuparuk we1l3K-30 is for the repair of a surface casing ) leak. The well is an injector, completed in July 1997. On December 07, 2006 fluids were observed at the conductor top by the Operator and the suspected surface casing leak was reported to AOGCC. Subsequent testing indicated a near surface leak in the surface casing. With approval, repair of the surface casing will require the following general steps: 1. Safe-out the well with plugs and load the tubing and IA with seawater and diesel freeze protection cap. 2. Excavate wellhead location. 3. Install nitrogen purge equipment. 4. Cut away the conductor casing and remove cement around surface casing leak for inspection. . 5. Notify AOGCC Field Inspector of repair operation so they may witness the event. 6. Repair damaged surface casing to return the casing to operational integrity. Repair options include sleeve patch, seal weld, lap patch, deposition weld and will be determined after inspection of the casing damage. 7. QA/QC the repair welds and MIT -OA to verify integrity 8. Install anti-corrosion coating on exposed surface casing. 9. Patch the conductor and top off the conductor void with cement and waterproof sealant. 10. Backfill gravel around the wellhead. 11. Remove plugs and return the well to :Injection. 12. Submit 10-404 report of repair operations to AOGCC. 'CIWlICAL INTEGRITY REPOR. KRU 3'1'...- 9-' -(f3 SPUD DATE: .fó/22..19'7 OPER & FIELD A I? C 0 -r(27/97 t..TELL NUMBER RIG RELEASE: WELL DATA T'D: to, "3 '1'51ID 69., " Casing :~ (5. 5' l,.. Shoe: , 88.5" MD Liner: 't.%. fZ.T$' 1.- Shoe: iO, '3.1"3 MD Tubíng:j'~ Packer 988rMD Hole Size 6~~c and TVD J PBTD: 10(2.8'7 MD .6B1'2... TVD TVD J DV: MD ·TVD TVD J TOP: ~8a511D TVD J Set at 9'0 g TVD J Perfs {ð. 06 ~ to (Ð, 104- MECHANICAL INTEGRITY - PART #1 Annulus Press Test: IP , 15 min ; 30 min Comments: ",- MECHANICAL INTEGRITY - PART #2 Cement Volumes: Amt. Liner ~y~ t7~~:,OI~1 Cmt vol to cover perfs ''iL f,4(... _ / ) /.f. 8 Lf:-7 I f.'"f :/¿J"2..3 (ltJ~353-{Of'291 .0731 +{~'2.).'Z.("t3 ~~lt 6'~l{ -, (11' Theoretical TOC ; Csg ZS'o So.. J DV ~ 3'Lft '3 ,. L O. ~ S""3 -Co. 06 2.) I £(79 :;. 43. B IfJ, 062. - CC'2S"o- 4~ "> ~ .~n, ] :: 831S- Cement Bond Log (Yes or No) tj.e.? ,In AOGCC File V~ ¿qI..1.1 CBL Evaluation, zone above perfs &j)-gJd. Þ9;'td¡'¡t:f 1:D"'8'U' Produc.tion Log: Type J Evaluation CONCLUSIONS: Par t #1: Part #2: M( I~~ ~if"n-.Jo1. r c..C Î'-C>....J r~ .. a3~ 1rl{(d(9.,.- rev. OS/20/87 ,,& r, '/'}l/{ \ ') /.._ ¡i'"") r /r J..:- ' d ') '-..-' Y C.028 KE: JK-JU {Pi U 1f l'JI-i1J) t'roaucea water lllJecIOr - KequesL lOr '" Tom, We had not planned to place it on monthly reporting at this time. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 ~~.§..:~.?~ìC;g.~.?'~.'?'p"þ'~}}.~:P?'.:.S;g.~~ SCANNED DEC 2 62006 -----Original Message----- From: Thomas E Maunder [mailto:tom maunder@admin.state.ak.us] S en t : Sunday, De c emb e r 2 ·4";·""~Ù5Ö"6·"4"';··¡i"··PM·........····m...................m.mm.....................m............................. To: NSK Problem Well Supv Cc: ~j im regg(f.yadmin. E3tate. a1\:.. "lJS Subject-;--·-R~-3K-30 (PTD # 197-113) Produced water injector - Request for permission to resume injection Perry, It appears that integrity has been restored. It is acceptable to return the well to service with the additional monitoring that you plan. Is there a plan to have the well information reported on the monthly monitoring report? Tom Maunder, PE AOGCC Original Message From: NSK Problem Well Supv <n161.7@conocophill.:Lpf:3.cC!n>. Date: Sunday, December 24, 2006 2:28 pm Subject: 3K-30 (PTD # 197-113) Produced water injector - Request for permission to resume injection To: Thomas Maunder <tom maunder@admin.state.ak.us> C c: j_i~~~' e.~l~~~ a. (~~~ i Yl ~ 's"t"a~'t'e'-~"'aj{~"~"~~l-smh' . mm.m......................___.... m.......h..___ .......--...--...... Tom, CPAI would like approval to resume injection of produced water into 3K-30 PTD # 197-113. 3K-30 has a suspected shallow surface casing leak, reported 12/10/06. A successful OA cement shoe was pumped on 12/13/06to prevent the annulus from charging via the open OA shoe. The well has two competent barriers, tubing and production casing, that were verified with a passing MITIA on 12/17/06. Additionally a passing MITOAwas performed to 1800 psi after the OA cement job. The MIT informationis attached. If approved, injection would be limited to water only, no gas. IA pressure not to exceed 2000psi, and OA pressure not to exceed 0 psi. A pit liner is installed in the well to contain any fluids that may escapethe conductor. The well will be monitored daily for signs of communication. Any indication of T X IA or IA by OA communication wouldtrigger CPAI to immediately secure the well and notify the AOGCC. CPAI is actively pursuing repairs on this well. A 10-403 has been submitted to dig and repair the well. Work is scheduled for Q1 2007. 12/26/2006 8:05 AM . . RECEIVED DEC 2 6 20015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Operations Performed: REPORT OF SUNDRY WELL OPERA TION~ Abandon 0 Repair Well 0 Plug Perforations 0 Stimulat~/ 0 OtherAncho~e ().~W- Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiv~r 0 Time Extension D ~~ Change Approved Program 0 Opera!. ShutdownO Perforate 0 Re-enter Suspended Well 0 M#"(V/ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 197-113/306-391 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22777-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 75' 3K-30 . 8. Property Designation: ADL 25519 ALK 2555 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Total Depth measured 10375' 6936' feet feet Plugs (measured) Junk (measured) true vertical Effective Depth measured feet true vertical feet Casing Structural CONDUCTOR SUR. CASING PROD. CASING PROD. CASING Length Size MD TVD Burst Collapse 121' 5727' 9810' 468' 16" 7-5/8" 5-1/2" 4-1/2" 121' 5802' 9885' 1 0353' 121' 4108' 6581' 6920' Perforation depth: Measured depth: Intervals between 1 0026 - 1 01 04' iCANNED JAN () 8 Z007 true vertical depth: Intervals between 6683 - 6740' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 9902' MD. Packers & SSSV (type & measured depth) Baker GBH-22 Locator Seal Assembly and Seal bore 9884' SSSV= NIP SSSV= 500' 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-Met Water-Bbl Casin Pressure Tubin Pressure NA NA 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 0 Development 0 Service 0 16. Well Status after proposed work: Oil 0 GasO WAG 0 GINJO WINJ 0 WDSPLO 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 306-391 Contact ,. Title Phone 659-7043 Problem Well Supervisor Date "Ø:J.OEC. C)~ .,40 ,. ~.07 it \/'1 Sub~inal Only ~--'~Ø? Printed Name Signature ORfGJNþJ . 3K-30 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 12/12/2006Obtained verbal 10-403 approval for cement shoe #306-391 12/13/2006 Pumped 29 bb115.9 ppg "Tail" OA cement shoe with diesel displacement. Placement for 1000' cement column at base of OA. Pencil sized stream from conductor on initial diesel and water stages, plugged up when cement pumped. About 2 gallons total from conductor during job. Final OA pressure (stable) post cementing 1000 psi. 12/17/2006 MITOA - passed, MITIA - passed, Initial T/I/O= S1/0/450, Pressured up the OA to 1800 psi. with 1 bbl of diesel, T/I/O= S1/0/1800, 15 min. T/I/O= SI/0/1720, 30 min. T/I/O= SI/0/171 0, Bled down the OA, T/I/O= SIIOIO, Pressured up the IA to 3000 psi. with 1.5 bbls of diesel, T/I/O= S1/300010, 15 min. T/I/O= S1/298010, 30 min. T/I/O= S1/298010, Bled down the IA. Final T/I/O= SI/OIO r. . SARAH PALIN, GOVERNOR AlASKA OIL AND GAS CONSERVATION COlVIlVlISSION j 333 W. 7" A VENUE, SUITE lOO ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276- 75423 Marie McConnell Problem Well Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3K -30 Sundry Number: 306-391 1"'\\~ .\0\ Dear Ms. McConnell: C' oj: e: ~~Î ," <t.,.+ 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. Sincerely, DATED this£' day of December, 2006 Encl. RECEIVED ALASKA Oil AND GAS CONSERVATION COMMISSION DEC 1 3 Z006 APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Alaska Oil & Gas Cons. Commission . OTS Jz(I1-/Þ (I} ì~--.h STATE OF ALASKA 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 waiAnch@e Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Remedial cmt - Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 197-113 . 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22777-00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes 0 No 0 3K-30 - 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Kuparuk River Unit RKB 75' Kuparuk River Field 1 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): 10375' 6936' Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121 SUR. CASING 5727' 7-518" 5802' 4108 PROD. CASING 9810' 5-1/2" 9885' 6581 PROD. CASING 468' 4-1/2" 10353' 6920 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Intervals between 10026 - 10104' Intervals between 6683 - 6740' 3-1/2" L-80 9902' Packers and SSSV Type: Packers and SSSV MD (ft) Baker GBH-22 Locator Seal Assembly and Sealbore 9884' SSSV= NIP SSSV= 500' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 12/13/06 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: 12/~ WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: Tom Maunder . 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: McConnell 1 Klein Printed Name Marie McConnell ~ Title: Problem Well Supervisor Signature ;#jð/// ;Ø) ~~'1 '/~/. Phone: 659-7224 Date: 12/11/06 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness r!flQ-311 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test çg Location Clearance 0 k\\O~ Other: Subsequent Form Required: '-\O~ RBDMS 8Fl DEC ] á ZOO6~:2')f'r) ~ - )I~ I APPROVED BY Date: J",¡t'"ð6 Approved by: ~ COMM)SSIONER THE COMMISSION Form 10-403 Revised 06/2006 o R1 3ffl A[ Gbmit in Duplicate ¡¿It.., ~ It.· I ~.Dt,. /t. .. . . ConocoPhillips Alaska, Inc. Kuparuk Well 3K-30 (PTD 1971130) SUNDRY NOTICE 10-403 REQUEST 12/11/06 The purpose of this Sundry Notice is to notify the AOGCC of Co no coP hill ips Alaska, Inc., intent to pump a cement shoe in the surface casing of Kuparuk water injection well3K-30. The cement shoe is required to stop a fluid leak to surface through an apparent hole in the surface casing into the conductor casing. ../ - ---~- 3K-30 was drilled in 1997 and has been on injection since that time. A surface casing cement shoe was not pumped at the time of original completion. On December 7,2006, Operations personnel reported finding standing fluids on the conductor cement top. The fluids were cleaned up and the conductor cement top was monitored over the next few days to determine the source ofthe fluids. On December 10, 2006, it was confirmed that the fluids were seeping up from the v cement rather than running down rrom a leak on the wellhead above. A near surface, surface casing leak from the OA to the conductor was suspected and reported to AOGCC. The leak is a slow seep dripping into a spill containment catch drum. The Outer Annulus (OA) sustains approximately 300 psi due to the open surface casing shoe. Isolating the surface casing rrom the formation pressure at the open shoe with cement will allow the OA to be depressured to stop the leak. The proposed plan includes pumping a cement shoe to shut-off the pressure support and leak to the surface. Subsequent diagnostics will be completed to verify well integrity and confirm the existence, depth and severity of the leak in the surface casing. If the surface casing leak can be repaired, a subsequent repair plan will be submitted for AOGCC approval. With approval, the OA cement shoe will require the following general steps: 1. SI well 2. Bleed IA to < 100 psi 3. Pump 25 bbls of Dowell "Tail" system 15.8 ppg cement into the OA. 4. Displace cement with 79 bbls of water and diesel freeze protection for a calculated cement top at 4802' MD. 5. Wait 48 hrs on cement 6. MITOA to 1800 psi. 7. Submit 10-404 to AOGCC. NSK Problem Well Supervisor 12/1112006 Re: 3K-30 (PTD 1971130) Report ofSC leak - Request for verbal a... . . Marie, Thanks for the infonnation. Fill in the verbal box and send it in by mail. Tom NSK Problem Well Supv wrote, On 12/11/20062:11 PM: Tom, Thanks for the prompt reply. Just finished up the 10-403. I could either fax it over this afternoon or send it in the US mail with the verbal approval box completed depending on your preference. The slow drip became evident yesterday morning (12/10/06) when a drum and downspout was installed on the conductor. Operations noticed fluids on the conductor cement top on 12/7/06. The fluids were cleaned up and conductor top was monitored for a few days to determine if the fluids drained into the conductor top from a source above or if they were coming up the conductor from below the cement top. Marie From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, December 11, 2006 11:52 AM To: NSK Problem Well Supv Cc: James Regg Subject: Re: 3K-30 (PTD 1971130) Report of SC leak - Request for verbal approval for OA cmt shoe. Marie, Your request seems appropriate, although a sundry application is still needed according to the "matrix". How long has the slow drip been evident? I will look forward to the sundry. Keep us advised. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 12/10/20067:38 PM: Tom & Jim, 3K-30 water injection well appears to have a small surface casing leak due to a slow drip of the OA freeze protection fluids seeping up from the conductor cement. The OA has an open shoe and maintains about 300 psi. Spill containment has been installed on the conductor to contain the seeping fluid. lof2 12/14/20069:12 AM Re: 3K-30 (PTD 1971130) Report ofSC leak - Request for verbal a... . . Verbal approval is requested to pump an OA cement shoe so the OA can be bleed to zero to stop the seep. The job is tentatively being planned as soon as cementing equipment is available, tentatively Wed or Thurs this week. Once the cement shoe is pumped. additional diagnostics will be performed to determine the leak depth and evaluate for excavation repair. Marie McConnell Problem Well Supervisor (907) 659-7224 n1617(Q>.conocophillips.com «3K-30.pdf» «3K-30 90 day TIO plot 12-10-06.gif» 2 of2 12/14/20069:12 AM • • - ConocoPhillps Alaska, Inc, NIP (500-50 OD:3 Sa TURIN (0-990 OD:3.50 ID:2.99 PROI CASIN (0-988 OD:5.50 Wt15.5 SLEEK (9836-98: OD 4 5( SE (9884-99 OD:40 PR( CASI (9885-103 OD:4.5 Wt:12. f 10026-10C 10062-10f 10084-10 KRU 3K-30 3K-30 90 day TIO plot 12-10-06.gif (G1F Image, 1238x767 pixels) mailbox:///F~/email/default/Mail/ancmail l .state.ak.us/Inbox?number=249314053&part=l.3... • I of ] 12/ 1 1 /2006 12:04 PM l~l~lVIUKANDUM ') State of Alaska ') Alaska Oil and Gas Conservation Commission TO: Jim Regg 1"'0 I I P.I. Supervisor 'J\i't'f b 14- G5' DATE: Wednesday, May 25, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPIDLLIPS ALASKA INC 3K-30 KUPARUK. RIV UNIT 3K-30 \.<\1-,\\3 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: ,~llL P.I. Suprv --.JD'i Comm Well Name: KUPARUK RIV UNIT 3K-30 Insp Num: mitCS050521160236 ReI Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-22777-00-00 Permit Number: 197-113-0 Inspector Name: Chuck Scheve Inspection Date: 5/21/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-30 Type Inj. w I TVD 6580 I IA 250 2100 2070 I 2070 P.T. 197 Il30 TypeTest SPT Test psi 1645 lOA 200 460 460 460 Interval 4 YR TST PIF P Tubing 2850 2850 2850 2850 Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. (~ '1 ?J}Û~ SCÄNNEO J\~t . ~ Wednesday, May 25,2005 Page 1 of 1 ') ) " . .\;£",.:::2, ~u.rr·t'U 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; and Jim_Regg@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. SCANNED MAY 2 ß 200~ FIELD I UNIT I PAD: Kuparuk I KRUI 3K DATE: 05121 105 OPERATOR REP: Arend I Sauvageau - AES AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. Well\3K-02 I Type Inj I S I T.V.D. 6421 I Tubing I 27501 27501 27501 2750lnterval 4 P.T.D. 1861020 Type Test P Test psi 1605 Casing 1100 2000 1950 1950 P/F P Notes: OA: 500 I 550 I 550 I 550 well3K.04 I Type Inj I S I T.v.D·1 6431 I Tubing I 30001 30001 30001 3000 I Interval I 4 P.T.D. 1861040 Type Test P Test psi 1608 Casing 1000 2100 2040 2040 P/F P Notes: OA: 250 I 350 I 350 I 350 well3K.05 I Type Inj I S I T.V.D.\ 6341 I Tubing I 27501 27501 27501 2750\lnterval 4 P.T.D. 1861230 Type Test P Test psi 1585 Casing 1400 2100 2070 2070 P/F P Notes: OA: 880 I 940 I 940 I 940 we1l13K.07 I Type Inj I S I T.V.D·I 6565 1 Tubing I 29501 29501 295°1 29501 Interval \ 4 P.T.D. 1861250 Type Test P Test psi 1641 Casing 450 2100 2040 2040 P/F P Notes: OA: 220 I 340 I 340 I 340 we1l13K-12 I Type Inj I S I T.V.D. 6644 I Tub~ng I 28501 28501 28501 2850\ Interval 1 0 P.T.D. 1861650 Type Test P Test psi 1661 Casing 400 2040 2000 1980 P/F P Notes: MIT IA done early to get on pad cycle OA: 200 I 480 I 480 I 480 well3K.13 I Type Inj I S I T.V.D. 6376 I Tub~ng I 28501 28501 28501 2850 I Interval I 4 P.T.D. 1861360 Type Test P Test psi 1594 Casing 550 2110 2050 2050 P/F P Notes: OA: 400 I 600 I 600 I 600 well3K.15 I Type Inj I S I T.v.D·1 6448 I Tubing I 28501 28501 28501 285Ollnterval 4 P.T.D. 1861380 Type Test P Test psi 1612 Casing 500 2070 2000 1980 P/F P Notes: OA: 300 I 450 I 450 I 450 well3K.18 I Type Inj I S I T.v.D. I 6605 I Tubing I 22001 22001 22001 2200 Interval 4 P.T.D. 1861510 Type Test P Test psi 1651 Casing 100 2800 2750 2740 P/F P Notes: OA: 440 I 560 I 560 I 560 well3K.19 I Type Inj I S I T.V.D. 6331 I Tub~ng I 27501 27501 27501 275Ollnterval 4 P.T.D. 2011080 Type Test P Test psi 1583 Casing 1000 2130 2130 2130 P/F P Notes: OA: 460 I 620 I 620 I 620 well3K.25 I Type Inj I N I T.v.D. I 6552 I Tub~ng I 27~l 2751 2751 275lnterval 4 P.T.D. 1980810 Type Test P Test psi 1638 Casing 2140 2120 2120 P/F P Notes: OA: 300 I 600 I 600 I 600 well3K-26 I Type Inj I S I T.v.D·1 6656 I Tubing I 27501 27501 27501 2750 I Interval I 4 P.T.D. 1970770 Type Test P Test psi 1664 Casing 900 2180 2160 2160 P/F P Notes: OA: 720 I 780 I 780 I 780 well3K-30 I Type Inj I S I T.V.D. 6580 I Tub~ng I 28501 28501 28501 2850 I Interval I 4 P.T.D. 1971130 Type Test P T est psi 1645 Casing 250 2100 2070 2070 P/F P Notes: OA: 200 I 460 I 450 I 450 well3K-31 I Type Inj I S I T.V.D. 6117 I Tub~ng I 285~1 28501 28501 2850\lnterval 4 P.T.D. 1980820 Type Test P Test psi 1529 Casing 2140 2120 2120 P/F P Notes: OA: 300 I 600 I 600 I 600 well3K-34 I Type Inj I S I T.v.D. I 6285 I Tub~ng I 285°1 28501 285°1 285Ollnterval 4 P.T.D. 1980770 Type Test P Test psi 1571 Casing 300 2140 2140 2140 P/F P Notes: OA: 400 I 650 I 650 I 650 Test Details: TYPE INJ codes TYPE TEST Codes INTERVAL Codes F = Fresh Water Inj M = Annulus Monitoring I = Initial Test G = Gas InJ P = Standard Pressure Test 4 = Four Year Cycle S = Salt Water Inj R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey Test during Workover D = Differential Temperature Test o = Other (describe In notes) M1T Report Form 5/24/2005 Revised: 05/19/02 MIT KRU 3K 05-21-05.xls THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03 2001 M E PL W ATE IA L U N D ER TH IS M ARK ER C:LOKIhMFILM.DO C PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS 97-113 NGP-MD ~5812-10375 97-113 NGP-T~qD ~14-6936 97-113 8077 ~SPERRY GR/ROP 97-113 MWD SRVY ~PERRY 0-10375 97-113 DIR SRVY ~/SPERRY 0-10375 97-113 CMT MAP ~/9800-10252 Page: 1 Date: 07/19/99 RUN RECVD FINAL 08/20/97 FINAL 08/20/97 2 08/20/97 08/29/97 08/14/97 FINAL 10/15/97 lO-~O7 ,a'/6OMPnmTZON DaT~ ~ ~1~?1~?1 DAnnY wmnn OPS R @ ~/~1¢71 TO ~ Iq Y Are dry ditch samples required? yes ~--'~d received? Was the well cored? yes ~_Analysis & description received? Are well tests required? ;yes ~_~Received? Well is in compliance Initial COMMENTS T D BOX .... ARCO Alaska, Inc. Post Office Box 1003bu Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August12,1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3K-30 (Permit No. 97-113) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3K-30. If there are any questions, please call 265-6206. Sincerely, Drilling Superintendent Kuparuk Development MZ/skad ORIGINAL STATE OF ALASKA ALAbKA OIL AND GAS CONSERVATION ~,OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection 2. Name of Operator ARCO Alaska Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1147' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 260' FSL, 176' FWL, Sec. 25, T13N, R9E, UM At total depth 516' FSL, 442' FWL, Sec. 25, T13N, R9E, UM 12. 17. 22. 7. Permit Number 97-113 8. APl Number 50-029-22777 9. Unit or Lease Name Kuparuk River Unit 10, Well Number 3K-30 11. Field and Pool Kuparuk River Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Rig RKB 41', Pad 34' _ .._1 ADL25519, ALK2555 Date Spudded6/22/97 13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'[15' Water depth' if °ffsh°re ]16' N°' °f C°mpleti°ns6/28/97 7/27/97 N/A MSL/ One Toi~l De'l~th (M'D+T~'~)~ 18. Plug Back Depth (MD+TVD)I19. Directional Survey,20. Depth where SSSV set~l. Thickness of Permafrost 10375' 6936 FT~ 10287 6872 FT~ []Yes [] NoI N/A MDI 1565' (Approx.) Type Electric or Other Logs Run GR/CCL/CMT 23. CASING S~ZE --¢7.625" i 4.5" V~. PER FT. GRADE 12.75# 151.5# X-65 29.7# L-80 15.5# L-80 L-80 CASING, LINER AND SETTING DEPTH i HOLE ' TOP BO'FrOM ~ ....SIZ_E___ Surf. 121' j___30" _ Surf. 5802' l 9__:_8 ~5_'_'___ Sud. 9885'i 6.75"_ __ 9885' 10353' / 6.75" 1 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) MD TVD 10062'-10082' 6709'-6724' 4 spf 10026'-10046' 6683'-6698' 4 spf 10084'-10104' 6725'-6740' 4 spf MD TVD CEMENTING RECORD CEMENTING RECORD AMOUNT PULLED 130 SX ASI 431 sx ASIIILW, 513 sx 'G', 60 sx ASI 250 sx Class G tapered string 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9902' ?6. ACID FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production iMethod of Operation (Flowing, gas lift, etc.) i _ Water Inj_ection Date of Test Hours Tested I PRODUCTION FOR I OIL-BBb GAS-MCF ITEST PERIOD' I Flow TubingiCasing Press u re[-(~-~LC~-~TF_~----~ ' I-(~il_:~3L_ GAS-MCF iP.r.,ess'. i ..... ,~-HOURBATE I 28. CORE DATA WATER-DEL CHOKE SIZE GAS-OIL RATIO WATER-DEL OIL GRAVITY-APl (CORR) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic M .... ;rs 30. Formation Tests -- Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kuparuk C 9838' 6547' Annulus left open - freeze protected with diesel· Bottom Kuparuk C 9897' 6590' Top Kuparuk A 10008' 6670' Bottom Kuparuk A 10176' 6792' I I 31. Li~{ of Attachments I .. Summary of Daily Drilling Reports, Surveys ........................................................................................ Signed d~.~//~ -RUe b~ ~ ___~~'~ ___Dat_e___ 8.~] ,__! !_~__? ............. i Prep~rC.d By ~t'~me/Number: · , INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data 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 Rev. 07-01-80 Date: 7/25/97 ARCO ALASKA INC ~% WELL SUMMARY REPORT' Page: 1 WELL:3K-30 RIG:PARKER 245 WELL ID: AK8749 TYPE: AFC:--AK9849 AFC EST/UL:$ 1240M/ 1488M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:06/22/97 START COMP: WI: ....~,~5~%~ECURITY:0 API NUMBER: 50-029~22777-00 FINAL:06/30/97 06/22/97 (D1) TD: 186' (186) SUPV: DCL DAILY: $ 06/23/97 (D2) TD: 4328' (4142) SUPV: DCL DAILY: $ 06/24/97 (D3) TD: 5812' (1484) SUPV: DEB DAILY: $ 06/25/97 (D4) TD: 5812' ( 0) SUPV: DEB DAILY:$ 06/26/97 (D5) TD: 7411' (1599) SUPV:DEB DAILY:$ 06/27/97 (D6) TD: 9442' (2031) SUPV:DEB DAILY:$ 06/28/97 (D7) TD:10375' ( 933} SUPV:DEB DAILY:$ 06/29/97 (D8} TD:10375' ( 0) SUPV:DEB DAILY:$ MW: 0.0 VISC: 82 PV/YP: 20/23 APIWL: 8.8 DRILLING Move rig from 3K-35 to 3K-30. Accept rig at 1700 hrs. 6/22/97. NU diverter system. Function test diverter. Clean out conductor to 121' Drilling from 121' to 186' 61,600 CUM:$ 61,600 ETD:$ 71,303 EFC:$ 1,230,297 MW: 9.2 rISC: 60 PV/YP: 20/16 APIWL: 8.8 DRILLING Drilling from 186' to 4328'. 77,395 CUM:$ 138,995 ETD $ 345,540 EFC:$ 1,033,455 MW: 9.3 rISC: 49 PV/YP: 19/16 APIWL: 7.2 RUNNING 7-5/8" SURFACE CASING Drilling from 4328' to 5812'. RU to run 7-5/8" surface casing. 71,908 CUM:$ 210,903 ETD:$ 444,974 EFC:$ 1,005,929 MW: 9.3 rISC: 40 PV/YP: 9/ 5 APIWL: 8.8 RIH W/BHA %3 TO DRILL OUT Hold prejob safety meeting. Run 7-5/8" surface casing. Cement casing to surface in 2 stages. NU BOPE. Test BOPE to 300/3000 psi. RIH to drill out ES cementer. 193,581 CUM:$ 404,484 ETD:$ 444,974 EFC:$ 1,199,510 MW: 8.9 riSC: 48 PV/YP: 10/20 APIWL: 9.2 DRILLING @ +/- 8400' Drill out 5' of cement, plug, & ES cementer. Drill out cement and float equipment. Drill 20' of new hole to 5832' Test formation, had leak-off 15.44 ppg EMW. Drill from 5832' to 7411' 73,775 CUM:$ 478,259 ETD:$ 708,114 EFC:$ 1,010,145 MW: 9.8 VISC: 52 PV/YP: 19/24 APIWL: 4.5 DRILLING @ +/- 9700' Drill from 7411' to 9442' Perform open hole leak-off test. 86,200 CUM:$ 564,459 ETD:$ 1,042,346 EFC:$ 762,113 MW: 9.9 VISC: 47 PV/YP: 15/18 APIWL: 4.0 RUNNING 5.5" X 4.5" CASING Drill from 9442' to 10375' Circulate lo/hi visc sweeps around. 82,184 CUM:$ 646,643 ETD:$ 1,195,885 EFC:$ 690,758 MW: 9.9 VISC: 51 PV/YP: 19/17 APIWL: 4.0 RD TEST TOOLS/RU TO RUN TBG Pre-job safety meeting on running casing. Run 5.5" x 4.5" production casing string. Cement casing. CIP @ 2300 hrs. 182,558 CUM:$ 829,201 ETD:$ 1,195,885 EFC:$ 873,316 Date: 7/25/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 06/30/97 (D9) TD:10375' ( SUPV:DEB o) DAILY:$ MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 LAYING DOWN DRILL PIPE Install packoff. Test packoff to 3000 psi for 15 min., OK. Hold pre-job safety meeting on running tubing. Run 3.5" completion assembly. Land tubing. Test tubing to 3500 psi for 10 min., OK. 154,111 CUM:$ 983,312 ETD:$ 1,195,885 EFC:$ 1,027,427 07/01/97 (D10) TD: 10375' ( 0) SUPV: DEB DAILY:$ MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Pressure tubing and annulus to 3500 psi and test 5.5" x 4.5" casing for 30 minutes, OK. ND BOPE. NU tubing head adapter and lower master valve. Prepare rig for move. Release rig @ 1200 hrs. 7/1/97. 37,923 CUM:$ 1,021,235 ETD:$ 1,195,885 EFC:$ 1,065,350 End of WellSummary for Well:AK8749 KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(3K-30(W4-6)) WELL JOB SCOPE 3K-30 PERFORATE, PERF SUPPORT DATE 07/26/97 DAILY WORK PERFORATE A SANDS DAY OPERATIONCO~-~m I SUCCESSFUL 3 NO I YES _. Initial Tbg Press I Final Tbg Press [ Initial Inner Ann 0 PSI! 0 PSII 0 PSI DAILY SUMMARY JOB NUMBER 0716971739.2 UNIT NUMBER SWS-PAWLUK JORDAN Final Inner Ann Initial Outer Ann Final Outer Ann 0 PSI 250 PSI 250 PSI PERFED A2 AT 10,084'-10,104' PER PROCEDURE. RDFN. TIME LOG ENTRY 13:00 MIRU SWS E LINE-J. PAWLUK. TGSM. PT BOP, LUB 3500 PSI OK. 15:00 RIH W/20' X 2-1/8" EJ, DP CHARGES, 90 DEG PHASING, ORIENTED +/- 45 DEG FLSHTIE IN AND SHOOT A2 AT 10,084'- 10,104'. HELD INITIAL TBG PRESS 300 PSI / DROP TO 0 PSI AT SHOT. 19:00 RDFN KUPARUK RIYER UNIT WELL SERVICE REPORT Kl(3K-30(W4-6)) WELL JOB SCOPE 3K-30 PERFORATE, PERF SUPPORT DATE DAILY WORK 07/27/97 2 1/8" EJ PERF DAY 4 OPERATION COMPLETE YES Initial Tbg Press 0 PSI ISUCCESSFUL YES DAILY SUMMARY 1 Final Tbg Press ] Initial Inner Ann 0 PSI I JOB NUMBER 0716971739.2 UNIT NUMBER 8337 I KEY PERSON SUPERVISOR SWS PAWLUK JORDAN Final Inner Ann I Initial Ou'ter Ann [ Final Outer'Ann 0 PSI 0 PSII 250 PSII 250 PSI PERFED FROM 10082' TO 10062' WITH 2 1/8" PH EJ 4 SPF WITH FIRST GUN ANDPERFED FROM 10046' TO 10026' WITH THE SECOND GUN.TUBING PRESS~ REMAINED 0 AFTER EACH GUN. TIME LOG ENTRY 08:00 MIRU SWS 8337-PAWLUK. TGSM. PT 3000~. 10:00 RIH WITH GUN #2 20' 2 1/8" 4 SPFEJ PH DP, CCL,WEIGHT. 11:00 TIED IN GUN 1 WITH CMT DATED 7/21/97 AND PERFORATED FROM 10082' TO 10062'. POOH. 12:30 RD GUN #2. 13:30 RIH WITH GUN #3 20' 2 1/8" EJ PH 4 SPF,CCL WEIGHT. 15:00 TIED INTO CMT DATED 7/21/97 AND PERFORATED FROM 10046' TO 10026'. POOH. 16:30 RI)MO. SPE] -SUN DRILLING SERVICES ANCHOP~AGE ALASKA PAGE ARCO ALASKA INC KUPARUK RIVER UNIT / 3K-30 500292277700 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 .00 -75.30 121.00 121.00 45.70 271.00 271.00 195.70 360.00 359.99 284.69 463.06 462.88 387.58 COURS INCLN DG MN 0 0 0 0 0 15 1 15 5 0 COURSE DIRECTION DEGREES DATE OF SURVEY: 062397 MWD SURVEY JOB NUMBER: AK-MW-70186 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC DLS TOTAL RECTANGULAR COORDINATES DG/100 NORTH/SOUTH EAST/WEST N .00 E .00 .00N .00E N .00 E .00 .00N .00E N 4.00 W .17 .33N .02W N 79.00 E 1.40 .71N .92E N 85.97 E 3.65 1.24N 6.50E VERT. SECT. .00 .00 .20 1.15 5.71 558.01 557.17 481.87 8 19 650.61 648.44 573.14 11 8 741.07 736.77 661.47 13 48 831.58 824.08 748.78 16 45 925.16 912.82 837.52 20 12 N 77.86 E 3.63 2.97N 17.35E S 88.90 E 3.87 4.21N 32.85E N 82.07 E 3.64 5.53N 52.28E N 84.23 E 3.32 8.33N 75.95E N 87.53 E 3.85 10.38N 105.52E 15.01 27.49 42.98 62.64 86.24 1016.37 997.38 922.08 23 48 1106.85 1079.41 1004.11 26 2 1196.10 1158.77 1083.47 28 21 1292.79 1243.03 1167.73 30 22 1385.76 1321.93 1246.63 33 27 S 89.61 E 4.13 10.94N 139.67E S 89.21 E 2.48 10.54N 177.80E S 89.26 E 2.58 10.00N 218.59E S 87.96 E 2.20 8.83N 265.97E S 88.26 E 3.32 7.21N 315.10E 112.31 140.74 171.07 205.97 241.87 1474.70 1395.77 1320.47 34 16 1566.54 1471.36 1396.06 34 58 1658.96 1546.62 1471.32 35 58 1749.40 1619.80 1544.50 36 0 1842.28 1693.71 1618.41 38 32 N 89.46 E 1.70 6.70N 364.65E N 84.56 E 3.12 9.44N 416.73E N 80.84 E 2.58 16.28N 469.89E N 77.39 E 2.24 26.31N 522.06E N 74.74 E 3.24 39.89N 576.63E 278.83 319.82 364.33 410.19 460.20 1934.20 1764.11 1688.81 41 28 2027.23 1832.26 1756.96 44 19 2119.35 1897.28 1821.98 45 53 2213.23 1962.48 1887.18 46 7 2305.77 2026.29 1950.99 46 40 N 71.04 E 4.10 57.32N 633.07E N 69.08 E 3.38 78.94N 692.57E N 68.84 E 1.71 102.37N 753.47E N 67.04 E 1.40 127.74N 816.06E N 66.03 E .99 154.42N 877.54E 514.15 573.17 634.43 698.23 762.07 2400.82 2091.11 2015.81 47 2492.32 2152.69 2077.39 48 2583.04 2212.49 2137.19 49 2675.32 2272.19 2196.89 49 2768.99 2331.71 2256.41 51 19 5 26 57 9 N 63.04 E 2.40 184.31N 940.27E N 60.65 E 2.11 216.25N 999.93E N 57.37 E 3.10 251.38N 1058.38E N 54.01 E 2.83 291.05N 1116.50E N 49.86 E 3.65 335.65N 1173.41E 828.96 894.89 962.01 1031.87 1104.07 2861.63 2388.82 2313.52 52 43 2953.82 2443.32 2368.02 54 47 3231.86 2605.05 2529.75 54 4 3508.30 2762.39 2687.09 56 31 3782.27 2914.58 2839.28 55 58 N 46.86 E 3.06 384.12N 1227.90E N 44.80 E 2.87 435.94N 1281.22E N 44.04 E .34 597.45N 1439.51E N 43.63 E .90 761.36N 1596.87E N 43.46 E .21 926.49N 1753.81E 1177.00 1251.24 1476.73 1703.09 1929.94 ORIGINAL RECEIVED AUG 29 199 AJaska Oil & Gas Cons~ Commi~sk~ SPE~ -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC KUPARUK RIVER UNIT / 3K-30 500292277700 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 062397 MWD SURVEY JOB NUMBER: AK-MW-70186 KELLY BUSHING ELEV. = 75.30 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 4062.57 3073.85 2998.55 54 45 N 43.21 E .44 1094.23N 1912.08E 4341.16 3236.89 3161.59 53 35 N 42.87 E .43 1259.32N 2066.26E 4614.29 3401.97 3326.67 52 1 N 43.25 E .59 1418.29N 2214.80E 4892.86 3566.99 3491.69 55 19 N 45.25 E 1.32 1578.95N 2371.42E 5168.78 3726.40 3651.10 54 5 N 44.36 E .52 1738.71N 2530.11E 2159.52 2384.26 2600.73 2824.39 3049.03 5446.43 3893.22 3817.92 52 2 N 42.88 E .85 1899.30N 2683.21E 5728.37 4064.02 3988.72 53 22 N 41.88 E .55 2064.99N 2834.37E 5961.97 4203.63 4128.33 53 13 N 43.17 E .45 2203.02N 2960.96E 6245.96 4373.29 4297.99 53 24 N 42.52 E .20 2369.99N 3115.82E 6525.97 4541.66 4466.36 52 39 N 42.90 E .29 2534.39N 3267.56E 3270.00 3492.87 3679.02 3905.53 4127.98 6801.79 4710.59 4635.29 51 47 N 44.05 E .45 2692.60N 3417.56E 7078.84 4877.02 4801.72 54 20 N 43.94 E .92 2851.89N 3571.34E 7355.07 5040.69 4965.39 52 58 N 44.16 E .50 3011.80N 3726.04E 7635.33 5209.94 5134.64 52 43 N 45.72 E .45 3169.91N 3883.81E 7908.01 5373.95 5298.65 53 19 N 45.41 E .24 3322.42N 4039.35E 4345.05 4565.68 4787.40 5010.25 5227.74 8184.71 5537.89 5462.59 54 0 N 46.15 E .32 3477.87N 4199.10E 8554.08 5758.69 5683.40 52 34 N 45.17 E .44 3684.77N 4410.86E 8741.30 5868.44 5793.14 55 39 N 44.78 E 1.65 3792.06N 4518.04E 9016.15 6026.54 5951.24 54 6 N 44.98 E .56 3951.35N 4676.66E 9292.96 6191.26 6115.96 52 50 N 45.57 E .49 4107.89N 4834.69E 5450.32 5745.94 5897.25 6121.52 6343.53 9571.90 6364.50 6289.20 50 20 N 45.39 E .90 4261.11N 4990.52E 9666.91 6426.61 6351.31 48 0 N 47.12 E 2.81 4310.83N 5042.43E 9760.36 6490.77 6415.47 45 15 N 47.53 E 2.96 4356.88N 5092.37E 9850.70 6555.47 6480.17 43 14 N 46.39 E 2.40 4399.89N 5138.45E 9943.33 6622.97 6547.67 43 13 N 45.39 E .74 4444.05N 5184.00E 6561.70 6633.52 6701.42 6764.42 6827.78 10034.32 6689.07 6613.77 43 35 N 45.34 E .41 4487.98N 5228.49E 10125.30 6754.92 6679.62 43 40 N 45.81 E .37 4531.92N 5273.33E 10214.83 6819.72 6744.42 43 34 N 46.25 E .36 4574.81N 5317.79E 10317.83 6894.53 6819.23 43 15 N 46.58 E .38 4623.62N 5369.07E 10375.00 6936.17 6860.87 43 15 N 46.58 E .00 4650.55N 5397.52E 6890.19 6952.87 7014.57 7085.30 7124.45 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7124.67 FEET AT NORTH 49 DEG. 15 MIN. EAST AT MD = 10375 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 48.81 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 10,375.00' MD SPE[ -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC KUPARUK RIVER UNIT / 3K-30 500292277700 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 062397 JOB NUMBER: AK-MW-70186 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -75.30 .00 N .00 E 1000.00 982.36 907.06 10.96 N 133.15 E 2000.00 1812.64 1737.34 72.28 N 674.90 E 3000.00 2469.95 2394.65 462.71 N 1307.80 E 4000.00 3037.75 2962.45 1056.99 N 1877.10 E .00 17.64 17.64 187.36 169.72 530.05 342.70 962.25 432.20 5000.00 3627.95 3552.65 1640.98 N 2433.99 E 6000.00 4226.40 4151.10 2225.23 N 2981.79 E 7000.00 4831.05 4755.75 2805.76 N 3526.90 E 8000.00 5428.88 5353.58 3374.22 N 4091.90 E 9000.00 6017.07 5941.77 3942.09 N 4667.41 E 1372.05 409.80 1773.60 401.56 2168.95 395.34 2571.12 402.17 2982.93 411.81 10000.00 6664.21 6588.91 4471.34 N 5211.66 E 3335.79 352.86 10375.00 6936.17 6860.87 4650.55 N 5397.52 E 3438.83 103.05 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE1 -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC KUPARUK RIVER UNIT / 3K-30 500292277700 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 062397 JOB NUMBER: AK-MW-70186 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -75.30 75.30 75.30 .00 175.30 175.30 100.00 275.30 275.30 200.00 375.32 375.30 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .00 N .00 E .00 .00 .35 N .02 W .00 .00 .77 N 1.34 E .02 .02 475.54 475.30 400.00 576.34 575.30 500.00 678.02 675.30 600.00 780.86 775.30 700.00 885.37 875.30 800.00 1.34 N 7.65 3.46 N 20.05 4.27 N 38.33 6.81 N 62.12 9.67 N 92.30 E .24 .22 E 1.04 .81 E 2.72 1.68 E 5.56 2.84 E 10.07 4.51 992.34 975.30 900.00 1102.28 1075.30 1000.00 1214.88 1175.30 1100.00 1330.46 1275.30 1200.00 1449.92 1375.30 1300.00 10.94 N 130.19 10.57 N 175.79 9.88 N 227.50 8.16 N 285.39 6.57 N 350.70 E 17.04 6.97 E 26.98 9.93 E 39.58 12.60 E 55.16 15.58 E 74.62 19.46 1571.35 1475.30 1400.00 1694.40 1575.30 1500.00 1818.85 1675.30 1600.00 1949.21 1775.30 1700.00 2087.78 1875.30 1800.00 9.71 N 419.47 19.59 N 490.45 36.16 N 562.63 60.61 N 642.51 94.19 N 732.33 E 96.05 21.42 E 119.10 23.05 E 143.55 24.46 E 173.91 30.35 E 212.48 38.57 2231.73 1975.30 1900.00 2377.49 2075.30 2000.00 2526.35 2175.30 2100.00 2680.16 2275.30 2200.00 2839.40 2375.30 2300.00 132.94 N 828.34 176.53 N 924.99 228.97 N 1021.94 293.23 N 1119.49 372.14 N 1214.96 E 256.43 43.95 E 302.19 45.76 E 351.05 48.86 E 404.86 53.81 E 464.10 59.24 3009.28 2475.30 2400.00 3181.16 2575.30 2500.00 3351.57 2675.30 2600.00 3531.71 2775.30 2700.00 3712.07 2875.30 2800.00 468.09 N 1313.15 567.94 N 1410.97 667.14 N 1506.89 775.50 N 1610.34 884.25 N 1713.79 E 533.98 69.88 E 605.86 71.87 E 676.27 70.42 E 756.41 80.14 E 836.77 80.36 3890.81 2975.30 2900.00 4065.08 3075.30 3000.00 4237.37 3175.30 3100.00 4405.89 3275.30 3200.00 4570.95 3375.30 3300.00 991.78 N 1815.69 1095.72 N 1913.49 1198.10 N 2009.42 1297.51 N 2101.70 1393.41 N 2191.39 E 915.51 78.74 E 989.78 74.27 E 1062.07 72.30 E 1130.59 68.52 E 1195.65 65.06 SPEi -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC KUPARUK RIVER UNIT / 3K-30 500292277700 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 062397 JOB NUMBER: AK-MW-70186 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4735.41 3475.30 4907.46 3575.30 5081.65 3675.30 5252.15 3775.30 5417.30 3875.30 3400 3500 3600 3700 3800 .00 .00 .00 .00 .00 1487.98 N 2281.39 1587.40 N 2379.95 1688.25 N 2480.77 1786.98 N 2577.32 1882.47 N 2667.58 E 1260.11 64.46 E 1332.16 72.05 E 1406.35 74.18 E 1476.85 70.50 E 1542.00 65.15 5579.87 3975.30 5747.28 4075.30 5914.66 4175.30 6081.68 4275.30 6249.34 4375.30 3900 4000 4100 4200 4300 .00 .00 .00 .00 .00 1976.40 N 2754.80 2076.29 N 2844.50 2175.38 N 2935.03 2272.94 N 3026.55 2371.99 N 3117.65 E 1604.57 62.57 E 1671.98 67.41 E 1739.36 67.38 E 1806.38 67.02 E 1874.04 67.66 6416.56 4475.30 6581.43 4575.30 6744.72 4675.30 6906.42 4775.30 7075.90 4875.30 4400 4500 4600 4700 4800 .00 .00 .00 .00 .00 2470.67 N 3208.35 2566.69 N 3297.58 2660.37 N 3386.37 2751.70 N 3474.73 2850.16 N 3569.69 E 1941.26 67.23 E 2006.13 64.87 E 2069.42 63.29 E 2131.12 61.70 E 2200.60 69.48 7246.46 4975.30 7412.55 5075.30 7578.14 5175.30 7743.23 5275.30 7910.28 5375.30 4900 5000 5100 5200 5300 .00 .00 .00 .00 .00 2949.59 N 3665.63 3044.73 N 3758.01 3138.14 N 3851.23 3229.85 N 3945.28 3323.70 N 4040.65 E 2271.16 70.57 E 2337.25 66.09 E 2402.84 65.59 E 2467.93 65.09 E 2534.98 67.04 8078.23 5475.30 82-48.36 5575.30 8416.87 5675.30 8581.55 5775.30 8753.46 5875.30 540O 5500 5600 5700 5800 .00 .00 .00 .00 .00 3418.19 N 4136.97 3513.54 N 4236.23 3607.95 N 4333.58 3700.20 N 4426.37 3799.19 N 4525.12 E 2602.93 67.95 E 2673.06 70.13 E 2741.57 68.51 E 2806.25 64.68 E 2878.16 71.92 8928.74 5975.30 9099.32 6075.30 9266.53 6175.30 9431.86 6275.30 9588.72 6375.30 59O0 6000 6100 6200 6300 .00 .00 .00 .00 .00 3901.26 N 4626.60 3999.01 N 4724.29 4093.14 N 4819.65 4185.31 N 4913.66 4270.14 N 4999.73 E 2953.44 75.28 E 3024.02 70.58 E 3091.23 67.21 E 3156.56 65.33 E 3213.42 56.86 9738.24 6475.30 6400.0 9877.92 6575.30 6500.0 10015.31 6675.30 6600.0 10153.48 6775.30 6700.0 10291.42 6875.30 6800.0 4346.20 N 5080.73 4412.75 N 5151.94 4478.76 N 5219.16 4545.49 N 5287.28 4611.18 N 5355.92 E 3262.94 49.52 E 3302.62 39.67 E 3340.01 37.39 E 3378.18 38.18 E 3416.12 37.94 SPEi -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 ARCO ALASKA INC KUPARUK RIVER UNIT / 3K-30 500292277700 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 062397 JOB NUMBER: AK-MW-70186 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10375.00 6936.17 6860.87 4650.55 N 5397.52 E 3438.83 22.71 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES Page 1 KUPARUK RIVER UNIT DS 3K 3K30 (F) JUNE 23, 1997 AK-MW-70186 MEASURED ANGLE DIRECTION DEPTH DEG DEG VERTICAL LATITUDE DEPTH FEET DEPARTURE VERTICAL DOG FEET SECTION LEG 0.00 0.00 0.00 121.00 0.00 0.00 271.00 0.25 356.00 360.00 1.25 79.00 463.06 5.00 85.97 0.00 0.00 121.00 0.00 271.00 0.33 N 359.99 0.71 N 462.88 1.24 N 0.00 0.00 0 .O0 0.00 0.00 0.00 0.02 W 0.20 0.17 0.92 E 1.15 1.40 6.50 E 5.71 3.65 558.01 8.32 77.86 650.61 11.14 91.10 741.07 13.80 82.07 831.58 16.75 84.23 925.16 20.20 87.53 557.18 2.97 N 648.45 4.21 N 736.78 5.53 N 824.08 8.33 N 912.82 10.38 N 17.35 E 15.01 3.63 32.85 E 27.49 3.87 52.28 E 42.98 3.64 75.95 E 62.64 3.32 105.52 E 86.24 3.85 1016.37 23.81 90.39 1106.85 26.05 90.79 1196.10 28.35 90.74 1292.79 30.38 92.04 1385.76 33.46 91.74 997.38 10.94 N 1079.42 10.54 N 1158.80 10.00 N 1243.06 8.83 N 1321.96 7.21 N 139.67 E 112.31 4.13 177..81 E 140.74 2.48 218.60 E 171.08 2.58 265.99 E 205.98 2.20 315.11 E 241.88 3.32 1474.70 34.28 89.46 1566.54 34.97 84.56 1658.96 35.98 80.84 1749.40 36.00 77.39 1842.28 38.55 74.74 1395.81 6.70 N 1471.40 9.44 N 1546.67 16.28 N 1619.86 26.31 N 1693.76 39.89 N 364.67 E 278.84 1.70 416.74 E 319.83 3.12 469.92 E 364.35 2.58 522.09 E 410.22 2.24 576.66 E 460.23 3.24 1934.20 41.47 71.04 2027.23 44.32 69.08 2119.35 45.89 68.84 2213.23 46.13 67.04 2305.77 46.68 66.03 1764.17 57.32 N 1832.32 78.94 N 1897.34 102.37 N 1962.54 127.74 N 2026.36 154.43 N 633.10 E 514.18 4.10 692.60 E 573.19 3.38 753.51 E 634.46 1.71 816.10 E 698.26 1.40 877.58 E 762.10 0.99 2400.82 47.32 63.04 2492.32 48.09 60.65 2583.04 49.44 57.37 2675.32 49.96 54.01 2768.99 51.16 49.86 2091.19 184.32 N 2152.77 216.26 N 2212.57 251.39 N 2272.27 291.06 N 2331.79 335.66 N 940.32 E 829.00 2.40 999.98 E 894.93 2.11 1058.44 E 962.06 3.10 1116.55 E 1031.92 2.83 1173.47 E 1104.12 3.65 2861.63 52.73 46.86 2953.82 54.79 44.80 3231.86 54.07 44.04 3508.30 56.53 43.63 3782.27 55.98 43.46 2388.90 384.13 N 2443.40 435.95 N 2605.14 597.47 N 2762.50 761.41 N 2914.69 926.53 N 1227.96 E 1177.05 3.06 1281.27 E 1251.29 2.87 1439.56 E 1476.78 0.34 1596.95 E 1703.18 0.90 1753.89 E 1930.03 0.21 4062.57 54.76 43.21 4341.16 53.60 42.87 4614.29 52.02 43.25 4892.86 55.32 45.25 5168.78 54.09 44.36 3073.97 1094.28 N 3237.01 1259.38 N 3402.10 1418.35 N 3567.12 1579.01 N 3726.55 1738.78 N 1912.17 E 2159.61 0.44 2066.35 E 2384.36 0.43 2214.90 E 2600.85 0.59 2371.52 E 2824.52 1.32 2530.23 E 3049.16 0.52 ORI iNA SPERRY-SUN DRILLING SERVICES KUPARUK RIVER UNIT DS 3K 3K30 (F) MEASURED ANGLE DIRECTION VERTICAL LATITUDE DEPTH DEG DEG DEPTH FEET DEPARTURE FEET 5446.43 52.04 42.88 3893.39 1899.40 N 5728.37 53.38 41.88 4064.20 2065.10 N 5961.97 53.22 43.17 4203.81 2203.13 N 6245.96 53.41 42.52 4373.47 2370.11 N 6525.97 52.66 42.90 4541.84 2534.50 N 2683.34 E 2834.51 E 2961.10 E 3115.97 E 3267.72 E 6801.79 51.80 44.05 4710.78 2692.72 N 7078.84 54.34 43.94 4877.23 2852.03 N 7355.07 52.98 44.16 5040.92 3011.96 N 7635.33 52.72 45.72 5210.17 3170.07 N 7908.01 53.33 45.41 5374.18 3322.59 N 3417.71 E 3571.53 E 3726.23 E 3884.01 E 4039.55 E 8184.71 54.00 46.15 5538.13 3478.03 N 8554.08 52.57 45.17 5758.95 3684.95 N 8741.30 55.65 44.78 5868.69 3792.24 N 9016.15 54.11 44.98 6026.80 3951.54 N 9292.96 52.85 45.57 6191.53 4108.09 N 4199.30 E 4411.07 E 4518.26 E 4676.88 E 4834.93 E 9571.90 50,34 45.39 6364.80 4261.33 N 9666.91 48.01 47.12 6426.91 4311.05 N 9760.36 45.26 47.53 6491.07 4357.10 N 9850.70 43.24 46.39 6555.78 4400.12 N 9943.33 43.22 45.39 6623.27 4444.27 N 4990.77 E 5042.69 E 5092.63 E 5138.71 E 5184.26 E 10034.32 43.59 45.34 6689.38 4488.20 N 10125.30 43.68 45.81 6755.22 4532.15 N 10214.83 43.58 46.25 6820.03 4575.04 N 10317.83 43.26 46.58 6894.84 4623.85 N 10375.00 43.26 46.58 6936.47 4650.78 N 5228.75 E 5273.59 E 5318.05 E 5369.33 E 5397.79 E Page 2 JUNE 23, 1997 AK-MW-70186 VERTICAL DOG SECTION LEG 3270.16 0.85 3493.04 0.55 3679.21 0.45 3905.71 0.20 4128.17 0.29 4345.25 0.45 4565.91 0.92 4787.65 0.50 5010.51 0.45 5228.00 0.24 5450.58 0.32 5746.22 0.44 5897.53 1.65 6121.81 0.56 6343.84 0.49 6562.04 0.90 6633.85 2.81 6701.76 2.96 6764.76 2.40 6828.12 0.74 6890.54 0.41 6953.22 0.37 7014.92 0.36 7085.65 0.38 7124.80 0.00 THE DOGLEG SEVERITY IS IN DEGREES PER 100.00 FEET THE VERTICAL SECTION WAS COMPUTED ALONG 48.81° (TRUE) BASED UPON MINIMUM CURVATURE TYPE CALCULATIONS. THE BOTTOM HOLE DISPLACEMENT IS 7125.01 FEET, IN THE DIRECTION OF 49.25° (TRUE) 10/14/97 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11439 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1E-32 ~"~' ..~ ;..,~- CBL 970828 I 1 3 K- 26 '~1~'7" ()'"~ '"-'1 CEMENT MAPPING TOOL 970722 I 1 3 K-30 ~"? I I ,.~ CEMENT MAPPING TOOL 970721 I 1 SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: Rb ,C,E VEE OCT 15 '1997 0 F! I I--I--I I~i G SE FI~.JI C E S August 26, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re' MWD Survey 3k-30 Dear Sir/Madam, Enclosed is two hard copy of the above mentioned File(s). Well 3k-30 Tie in point 0.00' and interpolated depth at 10,375.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments. RECEiVED AUG 2~ 1997 Oi~ & Gas C~.,n s. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc, Company August 26, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Dear Sir/Madam, Re: MWD Survey 3k-30 9'7- l! ~ Enclosed is two hard copy of the above memioned file(s). Well 3k-30 Tie in point 0.00' and interpolated depth at 10,375.00'. ¢ _ RECEiVED AUG 2{t 1997 Alasl(a Oil & Gas (;ohs. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I:::! I I--I-- I I~ I~S S ~: I:!~./I C I~ S WELL LOG TRANS~HTTAL _- -- To: State of Alaska August 20, 1997 Alaska Oil and Gas Conservation Comm. Attn.' LOft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 '(~ RE: MWD Formation Evaluation Logs 3K-30, AK-MW-70186 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention off Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3K-30: 2"x 5"MD Gamma Ray Logs: 50-029-22777-00 2"x 5" TVD Gamma Ray Logs: 50-029-22777-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company I~ I~! I I_1_ I I~ (::S S I~:: F! ~J I r- I~ S WELL LOG TRANSMITTAL To: State of Alaska August 20, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 3K-30, AK-MW-70186 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ynm Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22777-00 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 -- - A Dresser Industries, Inc. Company TONY KNOWLE$, GOVEt~NOR ~kLASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 13. 1997 Mike Zanghi Drill Site Develop. Supv. ARCO Alaska. [nc. PO Box 100360 Anchorage. AK 99510-0360 Re: Kupamk River Unit 3K-30 ARCO Alaska. Inc. Permit No. 97- I 13 Sur. Loc.: 1147'FSL.316'FWL.SEC 35.TI3N.R09E.UM Btmholc Loc: 560'FSL.368'FWL.SEC 25.T13N.R09E.UM Dear Mr. Zaughi: Enclosed is thc approved application for permit to drill thc above referenced xvcll. Thc 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 arc made. Approval for annular injection is contingent on thc operator's submittal of an Application for Sundry Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement. cementing, and any diagnostic logs that xvcrc mn. The documentation submitted should include a CQL or a x'alid LOT to assure thc Commission that an adequate seal has bccn attained and that thc well has been cased and cemented according to regulation. Thc blowout prevention equipment (,BOPE) must bc tested in accordance with 2() AAC 25.035: and the mechanical integrity (MI) of thc injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). SulTicicnt notice (approximately 24 hours) of thc MI test before operation, and of thc BOPE test performed before drilling below thc surface casing shoe. must bc given so lhat a representative of the Commission may witness thc tests. Notice may bc gix'cn by contacting thc Commission petroleum · David.W. Johnston \ - ~ Chairn~..._ ) ~ BY ORDER OF MISSION dlf"enclosures Depamnent of Fish & (htme. l labitat Suction w o encl. i)epartment o1' l';nvintmm~cnt (_'onscrTation v.- o cncl. STATE OF ALASKA ALASk,-, OIL AND GAS CONSERVATION COMMISSIC. , PERMIT TO DRILL 20 AAC 25.005 la. Typo of Work Drill X Redrill [] I lb ~xploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []I q Servicey Development Gas [] Single Zone X Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Rig RKB 41', Pad 34' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25519, ALK 2555 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1147' FSL, 316' FWL, Sec. 35, T13N, RDE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 398' FSL, 214' FWL, Sec. 25, T13N, RDE, UM 3K-30 #U-630610 At total depth 9. Approximate spud date Amount 560' FSL, 368' FWL, Sec. 25, T13N, RDE, UM 6/1 9/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3K-10 10385' MD 214 @ Target feet 11.2' @ 375' feet 2560 6941' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 53.91 o Maximum surface 2428 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 9.875" 7.625" 29.7# L-80 LTC 5735' 41' 41' 5776' 4101' 1620 Sx Arcticset III & HF-ERW 380 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOE; 9878' 41' 41' 991 9' 6586' 130 Sx Class G HF-ERW 6.75" 4.5" 12.8# L-80 EUE8rdM 466' 9919' 6586' 10385' 6941' Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth' measured feet Junk (measured)~ true vertical feet ' Casing ConductorStructural Length Size Cemented ' Surface Intermediate /i'ti 70 Production LinerORIGINAL'- · , .-' Perforation depth: measured '~J~l~_~ 01],~ true vertical ~'ic~_o_ra~ 20. Attachments Filing fee X Property plat [-] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby cer~fy that the foregoing is true and correct to the best of my knowledge / Signed },~ // { Title Drill S,te Develolo. Supv. Date H\" ~"~ For questions, please call Denise Petrash ~_,~- '~ Commission Use Only Per_mit Number ! I~Pl number .... ~ Approval dater ..i,.~_~.~ I see cover 'etter for ~;~','~"///.~ ~,/r5o- ~::~,.~;~- ~ ~ .~' "'77 I (.~ other requirements Conditions of approval Samples required [--~ Yes J~' No Mud Icg required C] Yes ~ No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ~ Yes ~ No Required working pressure for BOPE ~ 2M ~ 3M ~ 5M ~ 10M ~ 15M Other: by order of David W, JohnstonCommissioner the commission Date Approved by Form 10-401 Rev. 7-24-89 tril GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3K-30 1. Move in and rig up Parker #245. 2. Install diverter system. 3. Drill 9-7/8" hole to 7-5/8" surface casing point (5,776')according to directional plan. 4. Run and cement 7-5/8" casing, using stage collar placed at least 200' below the base of the permafrost, and light weight lead cement. 5. Install and test BOPE to 3000 psi. Test casing to 2000 psi. 6. Drill out cement and 10' of new hole. Perform leak off test, maximum pressure allowed 16.0 ppg EMW. 7. Drill 6-3/4" hole to total depth (10,385') according to directional plan. 8. Run open hole evaluation logs or LWD tools as needed. 9. Run and cement 5-1/2" x 4-1/2" tapered casing string with polished seal bore as part of XO. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) 10. Pressure test 5-1/2" x 4-1/2" casing to 3500 psi. 1 1. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. 1 2. ND BOPE. NU tubinghead & master valve and upper tree assembly. Note: As a dedicated injector, cased hole cement bond logs (SLT-J or CBT) will be run to establish isolation. 13. Shut in and secure well. 14. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 3K-30 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 3O-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.6 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes- Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2428 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3K-30 is 3K-10. As designed, the minimum distance between the two wells would be 11.2 @ 375'. Drilling Area Risks- Risks in the 3K-30 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #2 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.6 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 3K-30 Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr)in pumping operations. The 3K-30 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3K-30 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. 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 3K surface casing shoes will be set +200' vertical below the base of the West Sak into the heart of the shales, The maximum volume of fluids pumped down the annulus of this well will not exceed~...~ ~ r~ 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range, cf~'t~ diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the r~¢-~%'k''' '~ ~%~, spe.cified maximum pumping pressure of 1500 psi, the maximum pressure at the"~. ~e casing shoe is estimated by: ~-... ,,,k~..'c.~ - Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi ~,.. Max Pressure = 4059 psi ~~,~ The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 7.625 29.7 L-80 3 LTC 4790 4072 6890 5857 5.500 15.5 L-80 3 LTC-M 4990 4242 7000 5950 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (g) (1) & (2). 3K-30 Proposed Injector Completion Surface Csg: 7-5/8" 29.7# L-80 BTCMod 3-1/8" 5M FMC tubing hanger with 3-1/2" L-80 EUE 8rd pin down F. 3-1/2", 9.3#, L-80 EUE 8rd Mod tbg to surface E. 3-1/2" CAMCO 'DS' landing nipple with 2.812" ID No-Go profile set at +/- 500' MD. 6' L-80 handling pup made-up on top and 6' L-80 flow coupling on bottom D. 3-1/2", 9.3#, L-80 EUE 8rd Mod tubing Top of cement 500' min above top Campanian 5-1/2" 15.5# L-80 LTCMod 17' PBR, 4" x 5" w/Iocator in top XO _+100' above top of any potential pay sands C.~/3-1/2" Baker 'CMU' sliding sleeve w/2.812 Baker ~N sel,e, ctive profile (ran in closed position). 6' L-80 handling pul:) installed on top and 4 on bottom B. 1 joint 3-1/2", 9.3#, L-80 EUE 8rd Mod tbg A. GBH-22 seal assembly w/50' stroke and Iocator; 6' x 3-1/2" L-80 pup made up on top of the seal assembly Bowsprings on 5-1/2" casing; ROTCO turbulators on 4-1/2" casing Future Thru-Tubing Perfs 4-1/2" 12.75# L-80 EUEMod DKP 6/6/97 ARCO ALASKA, [nc. Pad 3K 3O slot #30 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM D I STANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 30 Version #2 Our ref : prop1787 License : Date printed : 18-Mar-97 Date created : 22-Aug-96 Last revised : 18-Mar-97 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 25 48.667,w149 45 49.2 Slot location is n70 25 59.947,w149 45 39.927 Slot Grid coordinates are N 6008140.712, E 529307.388 Slot local coordinates are 1147.00 N 316.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PGMS <O-9843'>,,18,Pad 3K PGMS <O-9584'>,,17, Pad 3K PGMS <0-9038'>,,16,Pad 3K PGMS <0-9275'>,,15,Pad 3K PGMS <0-8960'>,,14,Pad 3K PGMS <0-8580'>,~13,Pad 3K PGMS <0-7770'>,,12,Pad 3K PGMS <0-7853'>,,11~Pad 3K PGMS <O-7300'>,,10,Pad 3K PMSS <5275 - 7443'>,,9,Pad 3K PGMS <0-7580'>,,9A,Pad 3K PGMS <0-8500'>,,8,Pad 3K PGMS <0-8500'>,,7~Pad 3K PGMS <0-8100'>,~6,Pad 3K PGMS <0-8140'>,~5,Pad 3K PGMS <0-8980'>,,4,Pad 3K PGMS <0-8900'>,,3,Pad 3K PGMS <0-9960'>,,2,Pad 3K 3K-35IE Version #1,,IE,Pad 3K 3K-22D Version ~3,,22D,Pad 3K L Version #1,,l,Pad 3K E Version #2,,E,Pad 3K ID Version #1,,ID,Pad 3K H Version #2,,H,Pad 3K G Version #3,,G,Pad 3K Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 10-0ct-96 188.0 20.0 20.0 10-0ct-96 162.0 20.0 20.0 10-0ct-96 138.0 20.0 20.0 10-0ct-96 113.0 20.0 20.0 10-0ct-96 87.0 20.0 300.0 10-0ct-96 63.0 20.0 20.0 10-0ct-96 37.4 375.0 375.0 10-0ct-96 12.0 20.0 350.0 10-0ct-96 11.2 375.0 375.0 10-0ct-96 87.0 20.0 20.0 10-0ct-96 87.0 20.0 20.0 10-0ct-96 112.0 20.0 375.0 10-0ct-96 137.0 20.0 2400.0 10-0ct-96 162.0 20.0 350.0 10-0ct-96 185.3 525.0 525.0 10-0ct-96 212.0 20.0 20.0 10-0ct-96 221.7 3800.0 3800.0 10-0ct-96 262.0 20.0 20.0 25-Feb-97 125.0 280.0 280.0 25-Feb-97 225.0 375.0 400.0 26-Feb-97 125.0 350.0 2400.0 26-Feb-97 200.0 550.0 9180.0 26-Aug-96 25.0 300.0 300.0 8-0ct-96 150.0 280.0 2750.0 26-Feb-97 175.0 450.0 3700.0 3K-N Version #2,,N,Pad 3K PGMS <O-9150'>,,1,Pad 3K 32 Version #2,,32,Pad 3K 33 Version #5,,33,Pad 3K 27 Version #2,,27,Pad 3K 34 Version #2,,34,Pad 3K 26-Feb-97 10-0ct-96 5-Mar-97 4-Mar-97 28-Feb-97 5-Mar-97 150.0 287.0 50.0 74.0 100.0 100.0 280.0 20.0 300.0 280.0 280.0 300.0 280.0 20.0 300.0 7340.0 2375.0 300.0 ARCO ALASKA, Inc. Structure : Pad 3K Well : 30 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> crated by ~.,~ For: D PETRASH 600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 Date p/atte~: 18-1~or-g7 J I I I I I I I I I I I I I I I I I I I I I I Roi: Reference is 30 Version i!2. T~,r''l/"~r-T ''~'~--~' ""' TD / I Co0rcfinat~orelnleatrefere~cesloti¢3a. I I ~On' CC. O~a' ~. I Base Kup Sands~ F~°uu ~ ~ ' ' , mp um[ uk ~ / / J ~~ J TARGET K- 1 Marker~ l J ~ WD=6675 Begin Angle Drop/Base HRZ k 4200 J I~ J TMD=lO037 Cam~anian T Sands ~ J NORTH 4531 EAST 5178 ~ ~3600 / -lb ~60' FSL, ~68' F~L 48.81 DEG AZ Z ***~,on~ o~ ~ro~oso,*** 7 5/8 Casing?~ Base West Sak SandsZ/ ' 500 o IRKB EL~ATIoN: 75' ~ I K0P ~D=300 TMD=a00 DEP=0 ~ b ~oo ~ ~ aa / I 1~~9J~' Z~& I ~ soo % 33.00 k X ~o ~ BEGIN TURN TO TARGET ~D=1528 1MD=1633 DEP=336 / ~SO0 ~ ~;~67.~. B/ PERMAFROST ~D=~640 TMD=~78~ DEP=4~ L ~00 ~~ ~2.13 ~ 44.21 ~ 2000 ~ 4~.84 '~' ~ 49.92 X UMAN ~B/ W SAK SNDS ~D=3901 TMD=5436 DEP=5231 4 500 V sooo 5500 HRZ ~D=6204 TMD=g546 DEP=637g ~ ~ ~/Z X4 tZ OSA. T/ UNIT B WD=6586 TMD=9919 DEP=6805 ~e-/* BLS: 2.00 deg per 100 ft 6500 TARGET ANGLE ~=o~4~ ?~=~oa ~gv=7~oa vooo 40 DEG i i i i i i i i i i i i i i i i i i i i i ii i i i i I i i I i 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 7~oo Vertical Section (feet) -> Azimuth 48.81 with reference 0.00 N, 0.00 E from slot ICreoted by f{nch For: D PETRASH] Date plotted: 18-Mor-97 Plot Reference Is ;~0 Version #2. Coordinetea ore in feet reference alot ~30. True VerUc~l Dep[b~~ RKB (Porker 160 140 120 100 ~0 ARCO ALASKA, Inc. ska Structure ' Pod 5K Well : 50 Field · Kuporuk River Unit Location : North Slope, Ale East (feet) -> 20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 500 520 340 560 580 I I I I I { 1 t I I I I I I I I I I I I I I I I I I I I I I I I I I I i I I 1200 .................... ~9~ ............................ 2~oo ............. ~:: ..... ~ ....... - - ........ Y~b- .......................... ..... ~ .... ~ ....... ~oo ~oo ................................. ~7o0 ....... T~ ........... Ri3 4500 9OO 2500 _2700 20 2500I ~2900 ~--t~!~oo ~,~ \ ....... ~oo 40 ~ 500- ~ ........... 2000 ~.._ \~1oo .......... .......... \ ..... ..2'~oo .,. 800 ..... ~--.. 900 .......... ~°-~ ,,~oo -~oo ,,,oo~" - ....... _.,.ooo ...... ~..o.o ~e~o ........... ..~ lOO .............. %-....% ................ i i i i i i i i i i t i i i i i i 20 0 20 40 60 80 1 O0 120 140 160 180 200 220 240 260 280 ,300 520 540 560 Eesf (feet) -> 160 140 120 38O 100 80 60 40 Z 0 20 o 10o 80 60 ,6 , 5 13 5/8" 5000 PSiSTACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THATACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. I II 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8"- 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7.TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSi HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMSAND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE ~1/2" TO ~1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. KdPARUK RIVER UNI'I 20" DIVERTER SCHEMATIC 6 4 I HCR 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOLWITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 WELL PERMIT CHECKLISToo. ANY ~iEL~ ~ ~oo~, ..... Z'/_~.O/O0 INIT CLASS ... /~ ~ j~/7~ GEOL AREA PROGRAM: exp[] dev [] redrl[] serv~wellbore seg[] ann dtsp para re~ ~:'~4~5 UNIT" ///~ ON/OFF SHORE c~ ADMINISTRATION 1. Permit fee attached ................... 2. Lease number appropriate ................ 3. Unique well name and number ............... 4. Well located in a defined pool ............. 5. Well located proper distance from drlg 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 ........ REMARKS ENGINEERING APPR DA~E ].4. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ '~ N O~'""~'~' ~"J ~,~'N~"' ~ ~~:%~ ~ ~'~ /-- ~ - "~ //'~ ~ ~ '/~ 16. CMT vol adequate to circulate on conductor & surf csg. .Y~ N 17. CMT vol adequate to tie-in long string to surf sag . . . Y ~ 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ ~ N ~/~_ 21. If a re-drill, has a 10-403 for abndnmnt been approved..-T~-~5~Z~/% 22. Adequate wellbore separation proposed .......... ~,~ N 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~~> psig~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... .(=,Y/ N 29. Is presence of H2S gas probable ........... ~ N GEOLOGY APPR D~TE/ 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y//N 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ /Y N / ' 34. Contact name/phone for weekly progress reports . . . //. Y N [exploratory only] ~t GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/dlf - A'\FORMS\chekhst rev 01197 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Fri Aug 15 17:06:27 1997 Reel F~=m=~ Service name ............. LISTPE Date ..................... 97/08/15 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 ..................... 97/08/15 Origin ................... STS Tape Name ................ UNKNOg~ Continuation Number ...... 01 Previous Tape Name ....... UN~qOW~' Com.ments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER ~JPARUK RI~R UNIT MWD/¥~cD LOGS WELL N~ME: API Nbzm4BER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 2 AK-MW-70186 P. SMITH DON BREEDEN ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 3K-30 500292277700 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 15-AUG-97 35 13N 9E 1147 316 .00 75.80 34.30 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REFJ~RKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 7.625 5802.0 6.750 10375.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. ~f~D RUN 2 IS DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP/SGRD) UTILIZING SCINTILLATION TYPE DETECTOR. 4. GAMNLA RAY DATA BELOW 9964'MD, 6638'TVD IS REALTIME DATA, DUE TO LOSS OF RECORDED MEMORY LOG. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CO~ERSATION BETWEEN DENISE PETRASH OF ARCO ALASKA, INC. AND ALI TURKER OF SPERRY-SUN DRILLING SERVICES ON 07/18/97. 6. THIS WELL Rw~ACHED A TOTAL DEPTH (TD) OF 10375'MD, 6936' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Con~uent Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMPULRY PBU TOOL CODE START DEPTH STOP DEPTH GR 5751.0 10311.5 ROP 5812.0 10374.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE I~WD $ EQUIVALENT UNSHIFTED DEPTH ...... BIT RUN NO MERGE TOP MERGE BASE 2 5812.0 10375.0 REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down O~t~ca~ log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP I~WD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 5751 10374.5 8062.75 9248 5751 ROP 7.7504 600.991 215.13 9126 5812 GR 27.3743 545.321 109.396 9122 5751 Last Reading 10374.5 10374.5 10311.5 First Reading For Entire File .......... 5751 Last Reading For Entire File ........... 10374.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Nun%her ........... 1.0.0 Date of Generation ....... 97/08/15 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 ....... 97/08/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NU~,~ER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 5751.0 ROP 5812.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWA~,E VERSION: DOWNHOLE SOFTWARE VERSION: 5.74 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINatION (DEG MINI~-CJMANGLE: MAXI[~JMANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): ~,~JD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OPff4M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: M~JD CAKE AT MT: STOP DEPTH 10311.5 10374.5 28-JUN-97 ISC 5.06 CIM 5.46/DEP 2.042/SPC MEMORY 10375.0 5812.0 10375.0 43.2 55.6 NEUTRON TOOL MATRIX: M_~_T RIX DENSITY: HOLE CORRECTION (IN): TOOL NUMBER NGP 320 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 6.750 6.8 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 LSND 188.50 19.0 9.0 50O 4.5 .000 .000 .000 .000 56.1 .0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 I 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DE?T 5751 10374.5 8062.75 9248 5751 ROP 7.7504 600.991 215.13 9126 5812 GR 27.3743 545.321 109.396 9122 5751 Last Reading 10374.5 10374.5 10311.5 First Reading For Entire File .......... 5751 Last Reading For Entire File ........... 10374.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... i.0.0 Date of Generation ....... 97/08/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/08/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNO?~ Comments ................. STS LiS Writing Library, Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/08/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File