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Home My WebLink About195-032ORIGINATED TRANSMITTAL DATE: 5/8/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5419 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5419 2T-23 50103202160000 Perf Record 27-Apr-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 195-032 T40395 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.08 13:13:12 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, March 26, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2T-23 KUPARUK RIV UNIT 2T-23 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/26/2025 2T-23 50-103-20216-00-00 195-032-0 N SPT 5766 1950320 2500 930 2700 2660 2650 20 20 20 20 OTHER P Austin McLeod 2/12/2025 CMIT TxIA. Cemented IA. Sundry # 324-040. 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 2T-23 Inspection Date: Tubing OA Packer Depth 1000 2650 2570 2535IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250212182731 BBL Pumped:2.6 BBL Returned:2.5 Wednesday, March 26, 2025 Page 1 of 1 9 9 9 9 9 9 9 99 999 9 9 9 2LOSURGXFHU CMIT TxIA. James B. Regg Digitally signed by James B. Regg Date: 2025.03.26 11:05:16 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, March 26, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2T-23 KUPARUK RIV UNIT 2T-23 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/26/2025 2T-23 50-103-20216-00-00 195-032-0 N SPT 5766 1950320 2500 950 2670 2550 2520 20 20 20 20 OTHER P Austin McLeod 2/12/2025 MITT. Cemented IA. Sundry # 324-040. 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 2T-23 Inspection Date: Tubing OA Packer Depth 980 1000 1000 1000IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250212182228 BBL Pumped:0.5 BBL Returned:0.4 Wednesday, March 26, 2025 Page 1 of 1 9 9 9 9 9 9 9 9 99 999 99 9 9 2LOSURGXFHU MITT. James B. Regg Digitally signed by James B. Regg Date: 2025.03.26 11:02:15 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: IA Cement 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 12977'feet None feet true vertical 6116' feet 12560' feet Effective Depth measured 12977'feet 9297', 10277'feet true vertical 6116' feet 4546', 4897' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 2-7/8" x 3-1/2" L-80 12424' MD 5781' TVD Packers and SSSV (type, measured and true vertical depth) 9297' MD 10277' MD N/A 4546' TVD 4897' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 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: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 324-040 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 320 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker FH Retrvbl Packer Packer: Baker FHL Retrvbl Packer: SSSV: None Katherine O'Connor Katherine.OConnor@conocophillips.com 263-3718Senior Well Interventions Engineer 12506-12526', 15551-12569' 5828-5840', 5854-5865' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 80 Gas-Mcf MD 1250 Size 121' 1200 1100700 80 230600 265 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-032 50-103-20216-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025548 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2T-23 Plugs Junk measured Length Production Liner 6872' Casing 6096'12969' 4140' 121'Conductor Surface Intermediate 16" 9-5/8" 80' 4181' 2838' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:30 pm, Mar 19, 2025 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O= ConocoPhillips, OU=Wells Group, E= katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2025.03.19 13:14:15-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor RBDMS JSB 032725 DSR-3/28/25VTL 4/22/2025 DTTMSTART JOBTYP SUMMARYOPS 4/7/2024 ACQUIRE DATA (WC) OA NFT (COMPLETE) 7/15/2024 OPTIMIZE WELL PULL CATCHER @ 10243' RKB. PULL CA2 PLUG @ 10243' RKB. E-LINE UP NEXT FOR CIBP SET. 7/22/2024 OPTIMIZE WELL RUN 1: SET 2 7/8" COMPOSITE BRIDGE PLUG AT 9250' RKB RUN 2: TUBING PUNCH INTERVAL: 9242' - 9245' JOB COMPLETE, READY FOR SL PENDING PROCEDURE UPDATE 7/22/2024 OPTIMIZE WELL CIRC-OUT WELL PUMPED TOTAL 340 BBLS DIESEL DOWN TBG TAKING RETURN UP IA FOR CIRC-OUT, SEE LOG FOR DETAILS JOB COMPLETE 8/5/2024 OPTIMIZE WELL SET 2-7/8 SLIP-STOP CATCHER @ 8071' SLM. JOB IN PROGRESS 8/6/2024 OPTIMIZE WELL REPLACE GLV @ 8004' RKB W/ DMY. PULL GLV IN ST#2 @ 6233' RKB. JOB IN PROGRESS. 8/7/2024 OPTIMIZE WELL MAKE MULTIPLE UNSUCCESSFUL ATTEMTPS TO SET DMY IN STA # 2 @ 6233' RKB. PULL GLV FROM STA # 1 @ 3157' RKB. MAKE 2 MORE ATTEMPTS TO SET DMY IN STA # 2 @ 6233' RKB, IN PROGRESS... 8/8/2024 OPTIMIZE WELL BRUSH POCKET FOR STA # 2 @ 6233' RKB. SET DMV IN STA # 2 @ 6233' RKB. SET DMY IN STA # 1 @ 3157' RKB. PULL CATCHER FROM 8097' RKB. READY FOR CT. 11/8/2024 OPTIMIZE WELL RIGGED UP CTU-6 W/ 15,430' OF 1.75" CT (29.4 FUV). SET 2.19 FH CEMENT RETAINER @ 9231' RKB (UNABLE TO OBTAIN TEST ON RETAINER). JOB SUSPENDED. 11/9/2024 OPTIMIZE WELL RAN HOLE FINDER TO TOP OF CEMENT RETAINER @ 9230' RKB TO BEGIN TESTING. OBTAIN PASSING TEST ABOVE STATION #2 @ 6233' RKB. IN PROGRESS 11/10/2024 OPTIMIZE WELL SET CATCHER ON TOP OF CEMENT RETAINER @ 9230' RKB, PULLED AND REPLACE DMY IN STA # 2 @ 6233' RKB. RAN HOLEFINDER TO TOP OF CATCHER AND GOT A PASSING TBG TEST. PULLED CATCHER. READY FOR COIL 11/11/2024 OPTIMIZE WELL LOAD TUBING WITH DSL AND PRESSURE TEST TUBING TO 2000 PSI, RECORD RESULTS 11/15/2024 OPTIMIZE WELL TAG TOP OF RETAINER AT 9230' RKB. PAINT BLUE FLAG. MILLING WITH 2.29" OD BURN SHOE ON CEMENT RETAINER @ 9230' RKB. JOB IN PROGRESS. 11/16/2024 OPTIMIZE WELL BURN OVER CEMENT RETAINER @ 9230' RKB AND PUSH RETAINER DOWN TO TOP OF COMPOSITE BRIDGE PLUG AT 9249' RKB. RUN CEMENT RETAINER, TIE INTO FLAG AND SET RETAINER AT 9,225' RKB. GET GOOD 1000 PSI PRESSURE TEST ON RETAINER AND ESTABLISH CIRCULATION TO IA. PUMP 28 BBL OF CEMENT AND WHEN CEMENT HITS RETAINER, UNABLE TO PUMP ANY MORE. TRIP OUT OF HOLE WITH COIL FULL OF CEMENT. REACH SURFACE, BREAK OFF FH SETTING TOOL AND ABLE TO REESTABLISH CIRCULATION THROUGH COIL OUT TO TANKS. JUNK CEMENT TO TANKS AND WASH ACROSS TREE VALVES AND BOPS. JOB IN PROGRESS. 2T-23 IA Cement Summary of Operations 11/17/2024 OPTIMIZE WELL STING INTO RETAINER @ 9225' RKB. CIRCULATE DIESEL CT X IA TO CONFIRM COMMUNICATION THRU CEMENT RETAINER. PT RETAINER = 1000 PSI. CALLOUT CEMENTERS. PUMP CEMENT THROUGH RETAINER TAKING RETURNS OFF IA. PUMP 25 BBL 15.8 PPG CEMENT THROUGH RETAINER. UNSTING FROM RETAINER AND LAY IN 1 BBL ON TOP OF RETAINER. CONTAMINATE CEMENT IN TUBING DOWN TO 9050'. PUMP DIESEL COIL DISPLACEMENT DOWN BACKSIDE HOLDING 300 PSI TUBING PRESSURE WHILE POOH. ESTIMATED TOC IN IA AT 8,460'. 11/21/2024 OPTIMIZE WELL RIH WITH 2.29" 3 BLADE JUNK MILL. DRY TAG CEMENT AT 9,178'. MILL TO CEMENT RETAINER AT 9209'. MILL OUT RETAINER AND CONTINUE MILLING TO 9231'. POOH CHASING 3 BBL GEL SWEEP TO SURFACE. FREEZE PROTECT COIL & TUBING. PREP FOR WEEKLY BOP TEST. JOB IN PROGRESS. 11/22/2024 OPTIMIZE WELL WEEKLY BOP TEST. RIH WITH 2.23" BUTTON MILL TO 9207'. MILL RETAINER JUNK AND COMPOSITE BRIDGE PLUG STARTING @ 9207' TO 9240' BREAK THRU DEPTH. CONTINUE MILLING TRASH WHILE DRIFTING TUBING TO, AND OUT, END OF TUBING TO 12,430'. READY FOR SLICKLINE. 11/23/2024 OPTIMIZE WELL CHANGE PACKOFFS. RDMO. 12/20/2024 OPTIMIZE WELL BRUSH & FLUGH TBG DOWN TO 9500' RKB, SET 2.313" PX PLUG IN X NIPPLE @ 9347' RKB. READY FOR E LINE 12/28/2024 OPTIMIZE WELL LRS PERFORM MIT-IA (PASS) LOG CBL W/ READ'S TOOLS FROM 9300'-7000', READ UNABLE TO MAKE TOC FIELD PICK LOG SENT IN FOR PROCESSING 2/12/2025 ACQUIRE DATA (SW) STATE WITNESSED (AUSTIN MCLEOD) MIT T TO 2670 PSI (PASSED) CMIT T X IA TO 2700 PSI (PASSED) 2/15/2025 OPTIMIZE WELL MAKE TWO RUNS W/ 2.25'' BAILER TO ST#1 @ 3157' RKB (RECOVER 1'' X 3/4'' METAL DEBRIS POSSIBLY FROM COIL MILL OP), RUN TANDEM X-MAGNETS SWEEPING MANDRELS TO ABOVE PX PRONG @ 9342' RKB (RECOVER APPROX 1/4 CUP OF METAL DEBRIS CHUNKS POSSIBLY FROM COIL MILL OP), JOB IN PROGRESS 2/16/2025 OPTIMIZE WELL MAKE MULTIPLE RUNS OF 2-7/8 BLB W/ X-MAGNET & SWEEP MANDRELS TO PX PLUG @ 9342' RKB (RECOVER APPROX 2 CUP METAL SHAVINGS & 1/4 CUP OF SMALL METAL DEBRIS POSSIBLY FROM COIL MILL OP), PULL DMY VLV IN ST#3 @ 8004' RKB, JOB IN PROGRESS 2/17/2025 OPTIMIZE WELL SET OV IN ST#3 @ 8004' RKB, REPLACE DMY W/ GLV IN ST#1 @ 3157' RKB (GOOD TBG TEST & IA DDT), RUN 10' X 2.0 PUMP BAILER TO TOP OF PX PRONG @ 9342' RKB (RECOVER 1'' X 3/4'' METAL CHUNK & 3/4 CUP METAL SHAVINGS FROM COIL MILL OP), JOB IN PROGRESS 2/18/2025 OPTIMIZE WELL CONTINUE BAILING DOWN TO TOP OF PX PRONG @ 9342' RKB, RUN MAGNETS TO CLEAN OUT TOP OF FISHNECK, PULL PRONG AND EQUALIZE TBG... IN PROGRESS 2/19/2025 OPTIMIZE WELL USE BAILER AND MAGNETS TO CLEAN METAL DEBRIS FROM TOP OF PLUG, PULL PLUG FROM 9347' RKB, TAG FILL IN PERFS @ 12,562' RKB... JOB COMPLETE 2/26/2025 ACQUIRE DATA (WC/SUB) TIFL PASSED. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 12,562.0 2T-23 2/19/2025 raineg Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Install New GLV Design / Pull TTL plug 2T-23 2/20/2025 raineg Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for OA x Formation 5/3/2018 zembaej NOTE:WORKOVER 2/2/2014 haggea Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.68 40.9 4,181.1 2,837.6 40.00 L-80 BTC PRODUCTION 7 6.28 33.2 12,968.7 6,096.5 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.7 Set Depth … 10,275.7 Set Depth … 4,896.6 String Max No… 2 7/8 Tubing Description Tubing – Production Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE 8RD ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.6 36.6 0.00 HANGER 6.000 FMC TUBING HANGAR FMC 2.990 518.0 518.0 0.47 NIPPLE 3.690 CAMCO "DS" LANDING NIPPLE CAMCO "DS" Nipple 2.312 3,157.4 2,497.8 69.65 GAS LIFT 4.750 CAMCO KBMG-M GLM CAMCO KBMG- M 2.376 6,233.8 3,502.9 70.91 GAS LIFT 4.750 CAMCO KBMG-M GLM CAMCO KBMG- M 2.376 8,004.0 4,099.1 69.86 GAS LIFT 4.750 CAMCO KBMG-M GLM CAMCO KBMG- M 2.376 9,211.7 4,515.4 69.11 GAS LIFT 4.750 CAMCO KBMG-M GLM CAMCO KBMG- M 2.376 9,266.6 4,535.0 69.12 LOCATOR 3.460 BAKER LOCATOR BAKER 80-32 2.380 9,267.1 4,535.1 69.12 SEAL ASSY 3.230 SEAL ASSY "Space-Out" BAKER 80-32 2.390 9,274.2 4,537.7 69.16 PBR 5.470 BAKER 80-32 Polish Bore Receptacle BAKER 80-32 PBR 2.440 9,297.2 4,545.8 69.28 PACKER 5.970 BAKER FH RETRIEVABLE PACKER BAKER FH Packer 2.420 9,347.6 4,563.6 69.54 NIPPLE 3.690 HES "X" NIPPLE HES "X" Nipple 2.313 10,243.4 4,885.0 68.87 NIPPLE 3.690 CAMCO "D" NIPPLE CAMCO "D" Nipple 2.250 10,255.3 4,889.3 68.94 XO Increasing 3.500 Crossover Pup Joint 2 7/8", 6.5# x 3 1/2" L-80, 8rd 2.992 10,262.9 4,892.1 68.98 LOCATOR 3.460 BAKER LOCATOR BAKER 2.380 10,263.9 4,892.4 68.99 SEAL ASSY 3.230 Rerun 3 1/2" SEAL ASSY from last tally with no seals BAKER 2.390 Top (ftKB) 10,263.7 Set Depth … 12,388.5 Set Depth … 5,760.2 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-abm ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,263.7 4,892.3 68.98 PBR 5.000 BAKER 80-40 PBR BAKER 80-40 3.000 10,277.0 4,897.1 69.06 PACKER 5.960 BAKER FHL RETRIEVABLE PACKER BAKER FHL 3.030 10,327.6 4,915.1 69.19 NIPPLE 4.500 CAMCO DS NIPPLE CAMCO DS 2.812 12,366.0 5,747.1 54.57 SEAL ASSY 4.490 BAKER SEAL ASSY w/NO GO LOCATOR BAKER 2.940 12,368.3 5,748.5 54.57 PBR 5.880 BAKER 80-40 PBR 3.000 12,388.0 5,759.9 54.57 ANCHOR 4.750 BAKER K-ANCHOR 3.000 Top (ftKB) 12,386.0 Set Depth … 12,424.1 Set Depth … 5,780.8 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUEABM ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 12,397.9 5,765.6 54.57 PACKER 5.687 BAKER SABL-3 PERMANENT PACKER 3.250 12,414.1 5,775.0 54.57 NIPPLE 4.500 CAMCO 'D' LANDING NIPPLE 2.750 12,423.2 5,780.2 54.57 SOS 3.625 BAKER SHEAR OUT SUB 2.375 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,214.0 4,516.2 69.10 LEAK - CASING CSG LEAK IDENTIFIED WITH ACOUSTIC LDL AT 9214' RKB (0.5 BPM, 2300 PSI) 7/28/2023 6.280 9,242.0 4,526.2 69.07 TUBING PUNCH TBG PUNCH 9242' TO 9245' RKB (0 DEG PHASE, 4 SPF) 7/22/2024 2.441 2T-23, 3/17/2025 11:16:46 AM Vertical schematic (actual) PRODUCTION; 33.2-12,968.7 FISH; 12,560.0 APERF; 12,551.0-12,569.0 IPERF; 12,506.0-12,526.0 PACKER; 12,397.9 PACKER; 10,277.0 NIPPLE; 10,243.4 NIPPLE; 9,347.6 PACKER; 9,297.2 TUBING PUNCH; 9,242.0 GAS LIFT; 9,211.7 LEAK - CASING; 9,214.0 Remedial; 8,460.0 ftKB GAS LIFT; 8,004.0 GAS LIFT; 6,233.8 SURFACE; 40.9-4,181.1 GAS LIFT; 3,157.4 NIPPLE; 518.0 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) 41.49 RR Date 4/7/1995 Other Elev… 2T-23 ... TD Act Btm (ftKB) 12,977.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032021600 Wellbore Status PROD Max Angle & MD Incl (°) 72.38 MD (ftKB) 4,666.70 WELLNAME WELLBORE2T-23 Annotation Last WO: End Date 2/17/2014 H2S (ppm) 53 Date 12/13/2012 Comment SSSV: NIPPLE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 12,560.0 5,859.6 54.57 FISH 2.5" GU adapter pin retainer ring. .625" x 6" 6/26/2020 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,157.4 2,497.8 69.65 1 GAS LIFT GLV BK 1 1,398.0 2/17/2025 CAMCO KMBG- M 0.250 6,233.8 3,502.9 70.91 2 GAS LIFT DMY BK 1 0.0 11/10/2024 CAMCO KMBG- M 0.000 8,004.0 4,099.1 69.86 3 GAS LIFT OV BK 1 0.0 2/17/2025 CAMCO KMBG- M 0.250 9,211.7 4,515.4 69.11 4 GAS LIFT CEME NTED BK 1 0.0 7/8/2023 CEMEN TED CEMEN TED 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 12,506.0 12,526.0 5,828.3 5,839.9 A-3, 2T-23 9/28/1995 4.0 IPERF 2 1/8" Enerjet; Orient (+/-) 90 deg 12,551.0 12,569.0 5,854.4 5,864.8 A-2, 2T-23 12/24/2001 6.0 APERF Enerjet, 0 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,460.0 9,297.0 4,257.0 4,545.8 Remedial 25 BBL 15.8 PPG CLASS G CEMENT PUMPED INTO IA. ESTIMATED TOP AT 8,460'. 1 BBL CLASS G CEMENT LEFT ABOVE RETAINER IN TUBING. ESTIMATED TOP AT 9050'. 11/17/2024 2T-23, 3/17/2025 11:16:46 AM Vertical schematic (actual) PRODUCTION; 33.2-12,968.7 FISH; 12,560.0 APERF; 12,551.0-12,569.0 IPERF; 12,506.0-12,526.0 PACKER; 12,397.9 PACKER; 10,277.0 NIPPLE; 10,243.4 NIPPLE; 9,347.6 PACKER; 9,297.2 TUBING PUNCH; 9,242.0 GAS LIFT; 9,211.7 LEAK - CASING; 9,214.0 Remedial; 8,460.0 ftKB GAS LIFT; 8,004.0 GAS LIFT; 6,233.8 SURFACE; 40.9-4,181.1 GAS LIFT; 3,157.4 NIPPLE; 518.0 CONDUCTOR; 41.0-121.0 KUP PROD 2T-23 ... WELLNAME WELLBORE2T-23 C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\204-12-28_23059_KRU_2T-23_RadialCementBondLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 23059 KRU 2T-23 50-103-20216-00 Redial Cement Bond Log 28-Dec-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM 195-032 T39913 1/6/2025 ORIGINATED TRANSMITTAL DATE: 7/24/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4947 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4947 2T-23 50103202160000 Plug Setting Record 22-Jul-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 195-032 T39273 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.24 11:28:42 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com tom.osterkamp@conocophillips.com 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: IA Cement 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12977'12560' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 263-3718 Well Intervention Engineer KRU 2T-23 6116' 10243' 4885' 10243' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: katherine.oconnor@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 9297' MD and 4546' TVD 10277' MD and 4897' TVD 12398' MD and 5766' TVD N/A Katherine O'Connor STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025548 195-032 P.O. Box 100360, Anchorage, AK 99510 50-103-20216-00-00 Kuparuk River Field Kuparuk River Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst 12424' MD 121' 2838' 121' 4181' 6096'12969' 16" 9-5/8" 80' 4140' 12506-12526', 12551-12569' 6872' 5828-5840', 5854-5865' 7" Perforation Depth TVD (ft): 2-7/8" x 3-1/2" Packer: Baker FH Rtvbl Packer Packer: Baker FHL Rtvbl Packer Packer: Baker SABL-3 Perm Packer SSSV: None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 2/19/2024 By Samantha Carlisle at 3:04 pm, Jan 29, 2024 324-040 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O= ConocoPhillips, OU=Wells Group, E= katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2024.01.29 12:15:30-09'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor X VTL 03/04/2024 SFD 3/4/2024 X , ADL 0025569 SFD DSR-2/22/24 Run and review results of CBL with AOGCC after operation and as soon as available. State witnessed CMIT-TxIA to 2500 psi and MIT-T to 2500 psi 3287 10-404 *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.03.05 09:28:45 -09'00'03/05/24 RBDMS JSB 030524 Date: 1-29-34 Subject: 2T-23 IA Cement Prepared by: Katherine O’Connor (214) 684-7400 Well History 2T-23 is a gas li,ed producer that has a casing leak at 9214’ KB. Due to consistent low produc1on rates (<50bopd), an IA cement job is planned to return this well to produc1on and mi1gate the risk of further leaks downhole. The well does not meet economic metrics for a RWO. IA cement top planned is 8500’ RKB. Notes: Inclina1on Max: 73 deg @ 4666’ Min ID: 2.312” @ 518’ Last SBHP: 06/25/20 || 3907 psi || 5706’ TVD Casing leak at 9214’ KB LLR = 0.5 bpm @ 2300 psi MIT-T passed to 2500 psi 7/7/23 Calculaons Procedure: Slickline 1. Pull catcher and plug from 10243’ KB Eline & Fullbore 1. Set CBP @ ±9250’ RKB 2. Punch tubing @ ±9240’ KB 3. Circulate tubing and IA to diesel – 341 bbl volume Coiled Tubing 1. RIH with one trip cement retainer, set @ ±9225’ 2. Pump the following schedule down CT, taking returns up the IA: a. 5 bbl FW spacer b. ±23.4 bbls 15.8 ppg cement bringing TOC to ±8500’ RKB (IA vol from tubing punch to 8500’ is 22.4 bbls) c. CT volume freshwater d. This should put TOC in the IA at ~8500’ KB. Top Bottom Size ID bbls/ft ft volume ft/bbl notes 2-7/8" Tubing 0 10264 2.875" 6.5# 2.441" 0.0058 10264 59.4 172.8 lower packer depth 2-7/8" x 7" Annulus 0 9297 2.875" 6.5# x 7" 26# 6.28" x 2.875" 0.0303 9297 281.5 33.0 upper packer depth Annular Cement 8250 9297 2.875" 6.5# x 7" 26# 6.28" x 2.875" 0.0303 1047 31.7 33.0 3. Once cement has gained a minimum of 500 psi of compressive strength, mill through cement, retainer, and CBP. Push remnants to boKom Slickline & Fullbore 1. Set TTP in nipple at 9347’ KB 2. CMIT-TxIA to 2500 psi and MIT-T to 2500 psi 3. Run CBL from ±9297’ KB – 8000’ KB to locate TOC 4. Pull plug from tubing. Leave well shut in. CBL must be reviewed with AOGCC before bringing well online TOC est. 8500’ KB C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-07-28_22554_KRU_2T-23_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22554 KRU 2T-23 50-103-20216-00 LeakPoint Survey 28-Jul-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 195-032 T37906 Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.31 14:40:26 -08'00' C~ ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16th, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: • ~~.~~ ~. ~~ zoo alt~ska t~l ~ Gas Cep. Cssian Ancttarage 195 ° a~- a~-,~.3 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRiJ). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped July 11th, 12th, 13th 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/16/10 2T. 3H PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2T-22 50103202240000 1950860 8" Na 8" n/a 3.8 7/12/2010 2T 23 50103202160000 1950320 8" n/a 8" Na 2.1 7112/2010 2T-27A 50103202170100 2090900 7" n/a 7" Na 1.7 7/12/2010 2T-32 50103202180000 1950490 36" n/a 36" n/a 11.9 7/12/2010 2T 37 50103202270000 1951010 22" n/a 22" n/a 2.5 7/11/2010 2T-38A 50103202290100 1972050 8" n/a 8" Na 1.7 7/11/2010 2T-203 50103205200000 2051970 22" n/a 22" Na 5.1 7/13/2010 2T-208 50103205180000 2051870 13" Na 15" n/a 2.5 7/13/2010 2T-210 50103202730000 1982030 18" Na 18" Na 5.1 7/12/2010 2T-217A 50103203340100 2000740 8" Na 8" n/a 1.7 7/12/2010 3H-13A 50103200890100 1961970 SF n/a 22" n/a 3.8 7/11/2010 ( I( Howard Gober Wells Engineer Drilling & Wells ConocJP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4220 September 9, 2005 l"'; t:;' /'""'\ .. ..~ ¡~ g It r::. ...,.. ,~ '\¡¡'''/:'- i'''-'''\\ ''- ~#!Io. ~ Vf il..,," i " '''''\. ...; ,'. ' , ~ L.~/ß ,')£P I ~JI Îpnc:¡ , ", .l,,) '_ ~~ Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ~(~ to, Go w; rl " "1'- ,..' . I,,,, ..tDí, Hí)'¡~"~"',I',"'. . '. ~''"I.,liq..,' Subject: Report of Sundry Well Operations for 2T-23 (195-032/305-195) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover on the Kuparuk well 2T -23. If you have any questions regarding this matter, please contact me at 263-4220. Sincerely, LIZ ~ Howard Go~er Wells Engineer CPA I Drilling and Wells S(~J\NNED SEP 122005 HGlskad { fC~~' E J' '\lE,:~J") STATE OF ALASKA...·, ~'''''''' ALASKA OIL AND GAS CONSERVATION COMMISSION SEP I 2 2005 . REPORT OF SUNDRY WELL OPERA TION~'(:7:' ,"',-. ~ 1. Operations Performed: Abandon D Repair Well 0 Plug Perforations D Stimulate D Other. "'·',.êr t/Orr11l111~~ti"h' Alter Casing D Pull Tubing 0 Perforate New Pool D Waiver D Time Extension el" Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 195-032/305-195 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20216-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', pad 81' 2T-23 8. Property Designation: 10. Field/Pool(s): ADL 25548, ALK 2662 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 12977' 6116' Effective Depth measured 12606' feet feet feet feet Plugs (measured) Junk (measured) true vertical true vertical Casing Structural CONDUCTOR SUR. CASING PROD. CASING Length Size MD TVD Burst Collapse 121' 4065' 12847' 16" 9-5/8" 7" 121' 4187' 12969' 121' 2855' 6112' Perforation depth: Measured depth: 12506'-12526',12551'-12569' true vertical depth: 5843'-5855', 5869'·5880' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 12424' MD. Packers & SSSV (type & measured depth) pkr= BAKER SABL-3 PERM.; Baker FHL Retriev. Pkr pkr= 12398'; 10277' Cameo 'OS' nipple 498' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none RBDMS BFL SEP 1 9 2005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinç¡ Pressure Tubinç¡ Pressure Prior to well operation SI Subsequent to operation 85 228 1013 296 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ D WDSPLD 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: Contact Printed Name Signature Howard Gober @ 263-4220 ~c:~ard7 ~ber J1?6lc4i Title Phone Wells Engineer Date Prepared bv Sharon AI/$up-Drake 263-4612 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only It i'-Œ7CEïVED ConocoPhillips Alaska SEP 1 2 200tage 1 of 7 Operations Summary Report .Alaska OU & Gas r ." .' I;'~ ,'" ons. COO1ß1/ssion Legal Well Name: 2T-23 Common Well Name: 2T -23 Event Name: WORKOVER/RECOMP Contractor Name: Rig Name: Nabors 3S Date From - To Hours Code Sub Phase Code 7/21/2005 7/31/2005 00:00 - 03:30 3.50 CMPL TN NUND CMPL TN 03:30 - 08:30 5.00 MOVE MOVE DEMOB 08:30 - 13:00 4.50 MOVE MOVE MOVE 13:00 - 16:00 3.00 MOVE RURD RIGUP 16:00 - 18:00 2.00 MOVE RURD RIGUP 18:00 - 00:00 6.00 MOVE RURD RIGUP 8/1/2005 00:00 - 02:00 2.00 MOVE RURD RIGUP 02:00 - 04:00 2.00 MOVE RURD RIGUP 04:00 - 05:30 1.50 MOVE RURD RIGUP 05:30 - 07:00 1.50 MOVE RURD RIGUP 07:00 - 13:00 6.00 MOVE RURD RIGUP 13:00 - 20:00 7.00 MOVE RURD RIGUP 20:00 - 22:00 2.00 MOVE RURD RIGUP 22:00 - 23:30 1.50 WELCTL NUND DECOMP 23:30 - 00:00 0.50 WELCTL SFTY DECOMP 8/2/2005 00:00 - 03:30 3.50 WELCTL KILL DECOMP 03:30 - 04:30 1.00 WELCTL OBSV DECOMP 04:30 - 05:00 0.50 WELCTL COND DECOMP 05:00 - 06:00 1.00 WELCTL OBSV DECOMP 06:00 - 08:00 2.00 WELCTL OBSV DECOMP 08:00 - 18:00 10.00 RIGMNT RGRP DECOMP 18:00 - 00:00 6.00 WELCTL NUND DECOMP 8/3/2005 00:00 - 02:00 2.00 WELCTL NUND DECOMP 02:00 - 06:00 4.00 WELCTL BOPE DECOMP 06:00 - 08:00 2.00 WELLSR PLGM DECOMP 08:00 - 09:00 1.00 FISH PULL DECOMP 09:00 - 12:00 3.00 WELCTL CIRC DECOMP 12:00 - 14:30 2.50 FISH PULL DECOMP 14:30 - 16:30 2.00 FISH PULL DECOMP 16:30 - 00:00 7.50 FISH PULL DECOMP 8/4/2005 00:00 - 07:30 7.50 FISH PULL DECOMP Start: 7/31/2005 Rig Release: 8/19/2005 Rig Number: Spud Date: 3/24/1995 End: Group: Description. of Operations Nu 3 1/2" production tree and test at 1 G-13 rig was released at 03:30-7-31-2005. Prepare rig for move. Move rig from 1 G-2T Begin to spot up rig mats and BOPE stack behind well. Tight quarters around well 2T-22 and 2T-202. Tight quarters around well 2T-22 and 2T-202. Unable to spot and have pipe shed be part of the rig. Call out Valve crew and Drill sites maintenance crew. set BPV on 2T-202 and turn tree. Detach 20' section of flow line and fill cellar with gravel. After several attempts to back rig in, call out valve crew to set BPV in 2T-20 and setVR plugs in Casing valves to allow the most clearence. Still lack aprox 16" for the pipe shed to marry up. Scaffolding crew on location. Valve crew on location. Install BPV. AES crew turned tree valve for more clearance. Disassemble scaffolding, release crews. Lay handy-berm, spot rig over wellhead. Accepted rig at 10:00 on 8-1-2005 to split spotting issues on 2T-23. Raise derrick, spot pits and pipe shed. Raise derrickRig up pump lines to kill well. PT all to 4,000#. John Crisp call from AOGCC to wave BOP Test. Pull BPV 1 miss run Prejob safety meet for well kill. Begin pumping KWF dwn tubing taking returns up IA. Shut down and moitor well. 120 PSI DPP and 70 PSIIA. Raise mud wt in pits to 12.55 for well kill. Attempt to pump 1-1. Mud weight dropping going in. SI pumps and order out 100 BBLS of 12.3 Brine for pits. Monitor tbg & IA. Initial tbg 70 PSI. InitiallA 0 PSI. Tubing pressure dropped to 50 PSI. Bleed tbg pressure to 0 PSI, monitor pressures 30 mins, both tbg and IA pressure at 0 PSI While inspecting derrick, found cracked welds on pipe dividers (fingers) in derrick. Lay down derrick for repairs. Derrick repaired and back in the air. Install BPV, ND tree, & install blanking plug. NU BOP stack. Note: State witness of BOP E test waived by state rep John Crisp. Continue to NU 7-1/16" BOP stack. Begin testing BOPE to 250/3500 psi - tested good. Pull blanking plug and BPV, back out lockdowns, and prep to unland hanger. Pulled completion free 145K up weight to pull free, 75K up weight after completion pulled free. Circulate well with 12.2 ppg brine to raise fluid level inhole and regain consistent fluid wieghts throughout hole and pits. Begin pulling old completion, laying down for visual inspection and NORM testing. Well stable with a constant 12.2 ppg in and out. Rig downtime; air compressor not working properly. Troubleshoot and repair. Compressor seams heat related trip once the reset was found and reset it started working Resume pulling old completion. Continued to pull old 3-1/2" completion. Printed: 9/8/2005 10:02:30 AM Page 2 of7 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2T-23 Common Well Name: 2T-23 Event Name: WORKOVER/RECOMP Contractor Name: Rig Name: Nabors 38 Date I From - To Hours . Code J~dbe Phase I 8/4/2005 07:30 - 11 :00 3.50 FISH RURD DECOMP 11 :00 - 13:00 2.00 FISH TRIP DECOMP 13:00 - FISH TRIP DECOMP 8/5/2005 00:00 - 06:00 6.00 FISH TRIP DECOMP 06:00 - 12:00 6.00 FISH TRIP DECOMP 12:00 - 19:00 7.00 FISH RURD DECOMP 19:00 - 19:30 0.50 FISH WASH DECOMP 19:30 - 20:00 0.50 FISH FISH DECOMP 20:00 - 20:30 0.50 FISH CIRC DECOMP 20:30 - 23:30 3.00 FISH RURD DECOMP 23:30 - 00:00 0.50 FISH TRIP DECOMP 8/6/2005 00:00 - 06:00 6.00 FISH TRIP DECOMP 06:00 - 13:00 7.00 FISH TRIP DECOMP 13:00 - 15:00 2.00 WELLSR TRIP DECOMP 15:00 - 00:00 9.00 WELLSR TRIP DECOMP 8/7/2005 00:00 - 04:00 4.00 WELLSR TRIP DECOMP 04:00 - 06:00 2.00 WELLSR DEQT DECOMP 06:00 - 06:30 0.50 WELLSR DEQT DECOMP 06:30 - 07:30 1.00 WELLSR DEQT DECOMP 07:30 - 09:00 1.50 WELLSR DEQT DECOMP 09:00 - 18:00 9.00 WELLSR DEQT DECOMP Start: 7/31/2005 Rig Release: 8/19/2005 Rig Number: Spud Date: 3/24/1995 End: Group: Description of Operations Old completion out of hole bad corrosion from 11,350' to the cut pipe @ 12,380'. Rigging up to run fishing string to fish tubing stub with K anchor. Start making up BHA to run fishing string in the hole Start running 3.5" 13.5# and 15.5# HT-38 drill pipe for fishing string Shift change running in the hole with fishing string. Pre tower meeting Running in the hole with fishing string Rig up Kelly to circulate down with overshot and rotate K anchor Tag up 13' on kelly, jt# 383 drill pipe in the hole (12,351' at 3S rig floor). Begin circ @ 89 spm, 360 psi. Work down over fish while rotating 28', tag up, see circ pressure increase to 660 psi. Shut down pump. Pick up 175k#, fire jars to set grapple (hanging wgt= 80k). P/U to 95k, hold and begin rotating kelly, 28 turn see drop in torque...appear to have K-anchor unlatched. Run back in hole 28' to ensure fish is on. Appears we have fish. Rev-circulate 1-1/2 X drill pipe volume @ 176 spm, 1200 psi. 12.2 ppg brine in and out. Begin rigging down Kelly, standing it back. Begin pulling fishing string from hole, racking back drill pipe. Pulling fishing string out of hole, racking back pipe. Note: Averaging 15 stands per hour. Pre-tower meeting. Continue to Pulling fishing string out of hole, racking back pipe. Out of the hole with fish (8' tbg stub and K-anchor). Send K-anchor to Baker for rebuild. Rig up and begin running in the hole with test packer to 12390' RKB using 3.5 HT-38 drill pipe. Continue running in the hole with test packer; averaging 15 stands/hr. Hole conditions stable, losing small amount of fluid. Conduct spill drill in cellar. Continue tripping in the hole with test packer. Perform BOP drill (1 min 25 sec to secure well). On bottom; soft tag packer at 26' up on jt 391. Pick up to hanging wgt, then pick up additional 5'. Rotate pipe 3 turns to the left, back out torque at surface. Stroke pipe inlout to work torque to bottom. No change. Repeat 2 more times...have unscrewed somewhere and dropped the pipe 6' to set on production packer. Run pipe back in hole and screw pipe back in using chain tongs. ..break appears shallow. Pick string up; have all our string wgt back. Discuss options. Pull out of hole checking connections as we pull until we found tight connections @ 12,128'. Pull one more stand to 12065' RKB also tight. Run back in the hole re-tork connections. Could not set packer in tension (145K up Wt) doglegs will not let tork transfer to packer. Set packer @ 12388' RKB seal elements (in compression 48K down Wt). Start looking for leak in casing and testing packer. First set at 12388' RKB sealing elements, packer is at 12,398' RKB (no test 8 bbls pumped 1100 psi injecting at 2 bpm bleed back to 600 psi.). Same results testing @ 12,326' , 12,263', 12200', 11948', 11727', 11410', 11347', 11315', 11283', 11251', 11220',11156' and 11093'. Test held @ 10841' 2500 psi, run back in the hole to 10957', test did not hold move to 10907',10875', did not hold. Re-set at 10841'; passed test and confirmed good pipe. Tested bottom packer pumping down the drill pipe Printed: 9/8/2005 10:02: 30 AM Page 3 of 7 ConocoPhillips Alaska Operations Summary Report against CA2 plug with test packer set @ 11948' RKB bottom packer held indicating good packer and casing from that point down. All test where to 2500 psi. Confer with Wells Engineer over plan forward. On standby for direction. Break down Kelly and lay down. Pick up bails. Begin pulling work string out of hole, laying down drill pipe. Continued. Pulling out of hole with workstringltest packer. Averaging 22-26 jts per hour. Shift Change out meeting. Continued pulling out of hole with workstringltest packer. Averaging 22-26 jts per hour. Drill pipe out of hole with test packer. 3.5" IF pin on bottom of packer shows no marks from dropping pipe on top of bottom packer the previous day. Prep to start running completion; pick up tools and bottom hole assembly. Begin first completion run wI K-anchor and bottom PBR conveying with the 3.5" tubing. Shut down to clean up sma I spill; backup tongs knocked hydraulic hose off of power tongs. Resume running pipe. Having difficulties with tubing collars hanging on lip in BOP stack due to rig being so off-center. Attempt to work though it. Shut down, vac fluids out of stack to examine. Use "come-a longs" to pull stack over to enable pipe to drift past. Resume running pipe. Running in the hole with 3-1/2" tubing, K-anchor and PBR. Continue running in the hole with 3-1/2" tubing, K-anchor and PBR. On jt 397 Up wt 75K Dwn. wt 30 Ran in an tagged 15' in on jt 397 and set 20K down (12390'). Stroked 15' several times at different speeds and had a clean pickup each time. RU head pin established circulation 3.5BPM @ 510 psi, lowered and stacked out 12390' solid again and no press change. Attempted this several times with same outcome. RU tongs torqued pipe to 1400 fUlbs got 2 rounds in 1-1/4 rounds back. Several attempts at this with same outcome. RU to reverse circulate, pumped at 2 BPM @ 220 psi with same results. 2.00 CMPL TN CIRC CMPL TN Hole out of balance, circulate 12.2ppg around. Shut down and monitor well for 10 mins. Consistent 12.2 all the way around, well static. Leave message with state rep regarding possible BOPE test upcoming in A.M. 3.00 CMPL TN PCKR CMPL TN Stand back 4 stand; pull 5th to work off of. Use power tongs (2300# max) to rotate pipe; get 11 turns, back off torque and lose 2-1/2 turns. Work pipe back down to top of packer, stack up to 20k#. Tag up again in same spot. Repeat many times, working torque to bottom. RU headpin and pull suction valve from pump; come online at 2.0 bpm to circulate. Attempt to sting back in several times, varying speeds, rates, wieghts, etc. Clean pickups. No change, still tagging up 15' on jt #397 (12390'). Pull 1 stand. Discuss options with Wells Engineer. 2.00 CMPL TN PCKR CMPL TN Begin mixing metal-to-metal DRA pill; 28 bbls brine w/2 drums EMI 920. Having difficulties getting consistent mix due to viscosity of EM1920. Rig personnel rigging down to cuUstrip drill line while pill is being blended. 0.50 CMPL TN SFTY CMPL TN Continued. Blending DRA pill, have to viscosity to get EMI 920 to mix. Prepping to slip/cut drill line. 2.00 RIGMNT RSRV CMPL TN Conduct pre-job, first time many on crew have done it. Cutting I stripping drill line. Legal Well Name: 2T -23 Common Well Name: 2T-23 Event Name: WORKOVER/RECOMP Contractor Name: Rig Name: Nabors 3S Date From - To Hours .. Code Sub Phase Code 8/7/2005 09:00 - 18:00 9.00 WELLSR DEQT DECOMP 18:00 - 19:45 1.75 WAlTON ORDR DECOMP 19:45 - 23:00 3.25 WELLSR RURD DECOMP 23:00 - 00:00 1.00 WELLSR TRIP DECOMP 8/8/2005 00:00 - 06:00 6.00 WELLSR TRIP DECOMP 06:00 - 15:00 9.00 WELLSR TRIP DECOMP 15:00 - 16:30 1.50 CMPL TN RURD CMPL TN 16:30 - 17:30 1.00 CMPL TN RURD CMPL TN 17:30 - 19:00 1.50 CMPL TN OTHR CMPL TN 19:00 - 22:00 3.00 CMPL TN RUNT CMPL TN 22:00 - 00:00 2.00 CMPL TN RUNT CMPL TN 8/9/2005 00:00 - 02:30 2.50 CMPL TN RUNT CMPL TN 02:30 - 13:00 10.50 CMPL TN RUNT CMPL TN 13:00 - 17:00 4.00 CMPL TN PCKR CMPL TN 17:00 - 19:00 19:00 - 22:00 22:00 - 00:00 8/10/2005 00:00 - 00:30 00:30 - 02:30 Start: 7/31/2005 Rig Release: 8/19/2005 Rig Number: Spud Date: 3/24/1995 End: Group: Description of Operations Printed: 9/8/2005 10:02:30 AM Page 4 of 7 ConocoPhillips Alaska Operations Summary Report Rig back up to rev-circ. Come online reversing 30 bbl DRA sweep @ 3 bpm; spot pill on bottom. Re-attempt getting latched up. Tag up in same spot, 15' of jt 397. Pick up 20'; rotate 11 turns with power tongs, get 1 turn back. Run back in, tag up in same spot. Work pipe up I down rotating. Stack weight, bump obstruction. Clean pickups. Same results as previous attempts. Set back down, stack wgt. 20k and rig up to circulate. On line at 3 bpm, 300 psi. No change in circ pressure. Stop pumping, attempt to work pipe deeper- no change, tagging 12,390'. Discuss options. Well U-tubing again out of balance. Circulate 12.2 ppg brine around to balance. Shut down moitor well, well static. RD circulating line. Pull out and lay down jt 397 & 396. Attempt to set Baker storm packer for weekly BOP test. Could not get packer to latch into setting position. Layed down Baker Storm packer and Baker Rep. broke down and repaired by turning keyway over. The keyway was beveled off or rounded off. Shoulder of keyway should be square to latch up. Pick Baker Storm Packer back up, MU and run in hole, set with no problems at 42'. Lay down settng tool close blind rams and test packer to 1100 psi for 5 min. OK. Weekly test on BOPE. Press test rams to 250/3500, annular to 250/2500 psi. Witness waived by Jeff Jones AOGCC. Test complete- good. Run back in hole with retrieving head, pull storm packer and lay down with pups. Note: Lost rubber O-ring off test plug; able to circulate off and retrieve what appears to be all of o-ring (caught pieces at shacker). Pick up jt#396, 15' & 4' pup. Run in hole and tag up in same spot, 12390'. Perform kick drill. Begin rigging up wireline. Perform spill drill in cellar. Finish rigging up HES slickline to tubing string. Run in hole with slickline 1-7/8" toolstring (13' wgt bar, 13' RS, 2.70 cent, 3' sS, 2.70 LIB. Tag up at end of tubing string 12,391', tap through, make 7' and tag up at top of packer. Attempt to tap through, didn't go (don't want to work too hard and ruin any imprint that may be on LIB). Pull back out of hole, slight bobble pulling back into tubing. Pop off well and inspect LIB; appears to be a small taper on one edge, possible indication of hitting a shoulder/lip-- nothing clear. 3.00 WELLSR SLlN CMPL TN Run back in with same toolstring, swap LIB wI a 2.30 tapered swage. Tagging up in same spot, 12398' rkb, top of packer. Attempt to work throughlopen up restriction, having to jar out of packer to pop free. Work for a while, no change. Pull out of hole for new toolstring Note: caliper toolstring is approx. 5' long below bottom caliper arms so need at least 5-6' of drift into packer to profile area in question. Legal Well Name: 2T -23 Common Well Name: 2T -23 Event Name: WORKOVER/RECOMP Contractor Name: Rig Name: Nabors 3S Date From - To Hours Code Sub Phase Code 8/10/2005 02:30 - 04:00 1.50 CMPL TN CIRC CMPL TN 04:00 - 06:30 2.50 CMPL TN PCKR CMPL TN 06:30 - 10:00 3.50 CMPL TN CIRC CMPL TN 10:00 - 10:30 0.50 CMPL TN PULD CMPL TN 10:30 - 12:00 1.50 WELCTL BOPE CMPL TN 12:00 - 15:00 3.00 WELCTL BOPE CMPL TN 15:00 - 16:00 1.00 WELCTL BOPE CMPL TN 16:00 - 18:00 2.00 WELCTL BOPE CMPL TN 18:00 - 22:00 4.00 WELCTL TRIP CMPL TN 22:00 - 23:00 1.00 WELLSR TRIP CMPL TN 23:00 - 00:00 1.00 WELLSR RURD CMPL TN 8/11/2005 00:00 - 01 :00 1.00 WELLSR RURD CMPL TN 01 :00 - 03:00 2.00 WELLSR SLlN CMPL TN 03:00 - 06:00 06:00 - 07:30 1.50 WELLSR SLlN CMPL TN 07:30 - 12:30 5.00 WELLSR SLlN CMPL TN 12:30 - 14:00 1.50 WELLSR SLlN CMPL TN Start: 7/31/2005 Rig Release: 8/19/2005 Rig Number: Spud Date: 3/24/1995 End: Group: Description of Operations Ran in hole with 2.69" centralizer, 1.5" stem 10' long and 1.750" Sample Bailer. Tagged up at same spot 12,398', loaded bailer, pulled out of hole. Unloaded bailer, 1/2 cup of what looks like pipe dope. Rig up PDS 24 arm extended reach caliper. Run in hole and tagged up at 12,404'. Started logging back up hole t010,900'. Tool closed and pull out of hole. Down loaded data. Rigged down slickline equipment, and prepared rig and tools for pulling out of hole. Printed: 9/8/2005 10:02:30 AM Page 5 of 7 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2T-23 Common Well Name: 2T-23 Event Name: WORKOVER/RECOMP Contractor Name: Rig Name: Nabors 3S Date I From - To Hours Code Sub Phase I Code 8/11/2005 14:00 - 15:00 15:00 - 16:30 8/12/2005 16:30 - 18:00 18:00 - 00:00 00:00 - 01 :00 01 :00 - 03:30 03:30 - 04:30 04:30 - 13:30 13:30 - 15:00 Start: 7/31/2005 Rig Release: 8/19/2005 Rig Number: Spud Date: 3/24/1995 End: Group: Description of Operations 1.00 WELLSR PULD CMPL TN Pull out of hole with completion string laying down first 12 jts. 1.50 WAlTON ORDR CMPL TN Standby waiting on caliper log interpretation and decision on plan forward. 1.50 WELLSR PULD CMPL TN Pull out of hole with completion string standing back in derrick. 6.00 WELLSR PULD CMPL TN Continue to pull completion string out of hole. 1.00 WELLSR SFTY CMPL TN Conduct H2S drill; gather crew together after to review policy I procedures. 2.50 WELLSR PULD CMPL TN Out of hole with completion string. Have sheared seal assembly from PBR; inspection of brass indicates seal assembly sheared out in an upward motion. Seals still in good condition, muleshoe has a "dent" on inside edge, otherwise all is in good shape. Fluid loss during trip 10 bbls. 1.00 WAlTON ORDR CMPL TN Discuss options with team. 9.00 WELLSR TRIP CMPL TN Run back in hole with tubing string / seal assembly. 1.50 WELLSR TRIP CMPL TN Nipple Up head pin in jt 397. Establish circulation, pumping @ 2 BPM w/180 psi, wI seal assy. 6' above PBR lowered until tagged up @ 12,390' with no pressure change. Three attempts with no pressure change.This was done to insure seals are not engaged in SAB-3 packer before making trip to retrieve K-Anchor and PBR. Rig repair time, working on skate. Pull out of hole laying down completion string and seal assembly for preparation of running workstring. Pulling out of hole with tubing I seal assembly, laying down in prep for running workstring. Perform rig evacuation drill. Continue out of hole with tubing. Lay down seal assembly. Fluid loss durng trip 3.2 bbls. Clean rig floor and rig down running tools for completion and rig up tools for running workstring. Remove all tubing from pipe shed and load with 3-1/2" PH-6 workstring and strap. MU up BHA consisting of PBR retrieving tool, Bumper Sub, & Oil Jars. Continue to load pipe shed, and strap pipe. Start in hole with PBR retrieving tool, bumper sub, oil jars,and picking up 3-1/2" PH-6 work string. BOP drill while tripping in hole. Continue picking up workstring, run in hole. 325 jts of PH-6 in the hole, prep to begin running drill pipe. Swap equipment, clean up I wash down rig floor. Conduct pre-job safety meeting. Trip in the hole with drill pipe. Well stable. On bottom 6' above top of PBR (fish). RU head pin to top of jt 395. Established circulation 3 BPM @ 750 PSI. Lowered and tagged PBR 6' in on jt 395' or 12368'. Stacked 17k # wt and no pressure change. PU 6' above string wt. with no indication of latch by K-anchor. Lowered back down to top of PBR. Disconnect hose and RU power tongs. 0.50 WELLSR OTHR CMPL TN Rotate & slack off stacked 8K #. PU released torque, got 1/2 round back. Pulled 20k overpull, hit jars. Slacked off and reloaded jars, picked up and staged up to 145K (55k over) to shear PBR retrieving tool (pinned for 60K over). All indication are K-anchor is latched in. RD power tongs. 4.17 WELLSR CIRC CMPL TN Well out of balance again. Established circulation and pumped bottoms up 12.2 ppg. in and out, 2 bpm. 5.33 WELLSR TRIP CMPL TN Pull out of hole laying down 67 jts of HT38 and standing back 15:00 - 16:15 1.25 WELLSR EQRP CMPL TN 16:15 - 00:00 7.75 WELLSRTRIP CMPL TN 8/13/2005 00:00 - 05:30 5.50 WELLSR TRIP CMPL TN 05:30 - 06:00 0.50 WELLSR SFTY CMPL TN 06:00 - 07:00 1.00 WELLSR TRIP CMPL TN 07:00 - 09:30 2.50 WELLSR TRIP CMPL TN 09:30 - 10:45 1.25 WELLSR TRIP CMPL TN 10:45 - 14:45 4.00 WELLSR TRIP CMPL TN 14:45 - 14:50 0.08 WELLSR SFTY CMPL TN 14:50 - 00:00 9.17 WELLSR TRIP CMPL TN 8/14/2005 00:00 - 01 :30 1.50 WELLSR RURD CMPL TN 01 :30 - 02:00 0.50 WELLSR SFTY CMPL TN 02:00 - 05:45 3.75 WELLSR TRIP CMPL TN 05:45 - 07:45 2.00 WELLSR TRIP CMPL TN 07:45 - 09:00 1.25 WELLSR OTHR CMPL TN 09:00 - 09:30 09:30 - 13:40 13:40 - 19:00 Printed: 9/8/2005 10:02:30 AM Page 6 of7 ConocoPhillipsAlaska Operations Summary Report remainder of PH-6 workstring. Continue out of hole with PH-6, racking back. Going slow, having to use rig tongs to break. Continuing out of hole with PH-6 drill pipe racking back. Hole stable, fill 1: 1 pipe displacement. Add 1/2 drum soap to pits to clean up fluid (suspect EM1920) in fluids. Continue POH. Lay down retrieving tool and clear rig floor Pick up and install wear ring. Make up seal assembly and start running in hole with tubing, ran 66 jts of tubing. picked up FHL Packer & PBR ran below slips. Changed running tools from tubing to accomodate workstring.( Ellevators, tongs, & safety valve). Continue to run in hole with completion on workstring (PH-6). While running in hole at 80 to 90 ft per min. FHL Packer stopped at 3220' RKB with 15K wt. on it. Pulled up to 50K (1 OK below calculated string wt of 60K). Shut down and discussed options. Picked up to 58K and came loose. All indications show that we sheared from the PBR. Lowered back and tagged at same spot. Pull out of hole. At surface; begin making up fishing BHA (same as previous) wI PBR retrieving tool, bumper sub, and oil jars. Begin running back in hole with fishing string. Running in the hole with PBR fishing string. Get pick up wgt 1 jt above fish = 27k. Check torque=750# to turn. Set down on top of PBR at 3228' orig RKB (8' up on jt 102) ; latch up. Pick up and let jars bleed. Rotate pipe and unseat packer. Have picked up wgt...run pipe in hole 5' below tag. Begin pulling out of hole with packer. Well stable. 3.00 WELLSR TRIP CMPL TN On surface with FHL packer, missing two slip segments and covered with black sticky substance believed to be the residue from the EMI-920 friction reducer. 4.00 WELLSR TRIP CMPL TN LD packer and PBR. Search and clean out BOPE looking for missing slip segments. Recovered both segments from pipe ram cavities. Change out tools for pulling 3-1/2" EUE pipe. Notified AOGCC of pulling doors off BOPE and needing to retest plus weekly test. Pull out of hole standing back 66 jt 3-1/2" EUE and seal assy. Inspect seal assy for damage. Everything looks good. Pull wear ring. Test BOPE (weekly) Lou Gramaldi wlAOGCC witnessed test. Install wear ring. Pre job safety meeting. PU seal assy and start running in hole with completion again. Heat 12.2 ppg brine to 100 deg to circulate around staging in as we run packer. Start initial circulation 100 deg 12.2 brine, till good clean returns, circulated brine temp. at 80 deg MU FHLlPBR assembly, work assembly through BOP stack RIH with 3.5" completion (25 stands) Start second circulation 110 deg brine, circulated around to 85 deg. RIH with another 25 stands, with end of tubing at 5280' packer @ 3180'. Circulate 100 deg brine around, 90 deg out. Pumped dry job. Legal Well Name: 2T -23 Common Well Name: 2T -23 Event Name: WORKOVER/RECOMP Contractor Name: Rig Name: Nabors 3S Date From - To Hours Code Sub Phase Code 8/14/2005 13:40 - 19:00 5.33 WELLSR TRIP CMPL TN 19:00 - 00:00 5.00 WELLSR TRIP CMPL TN 8/15/2005 00:00 - 02:00 2.00 WELLSR TRIP CMPL TN 02:00 - 06:00 4.00 WELLSR TRIP CMPL TN 06:00 - 07:00 1.00 WELLSR TRIP CMPL TN 07:00 - 08:00 1.00 WELLSR NUND CMPL TN 08:00 - 12:00 4.00 WELLSR PULD CMPL TN 12:00 - 12:30 0.50 WELLSR PULD CMPL TN 12:30 -13:15 0.75 WELLSR PULD CMPL TN 13:15 -16:15 3.00 WELLSR PULD CMPL TN 16:15 -17:15 1.00 WELLSR PLGM CMPL TN 17:15-21:15 4.00 WELLSR TRIP CMPL TN 21 :15 - 23:15 2.00 WELLSR TRIP CMPL TN 23:15 - 00:00 0.75 WELLSR TRIP CMPL TN 8/16/2005 00:00 - 02:00 2.00 WELLSR TRIP CMPL TN 02:00 - 03:00 1.00 WELLSR TRIP CMPL TN 03:00 - 06:00 06:00 - 10:00 10:00 - 12:00 2.00 WELLSR PULD CMPL TN 12:00 - 17:50 5.83 WELCTL BOPE CMPL TN 17:50 - 19:00 1.17 WELCTL NUND CMPL TN 19:00 - 00:00 5.00 WELLSR TRIP CMPL TN 8/17/2005 00:00 - 01 :30 1.50 WELLSR CIRC CMPL TN 01 :30 - 03:00 1.50 WELLSR PULD CMPL TN 03:00 - 04:30 1.50 WELLSR TRIP CMPL TN 04:30 - 06:00 1.50 WELLSR CIRC CMPL TN 06:00 - 07:45 1.75 WELLSR PULD CMPL TN 07:45 - 10:00 2.25 WELLSR CIRC CMPL TN Start: 7/31/2005 Rig Release: 8/19/2005 Rig Number: Spud Date: 3/24/1995 End: Group: Description of Operations Printed: 9/8/2005 10:02:30 AM '~ ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2T-23 Common Well Name: 2T -23 Event Name: WORKOVER/RECOMP Contractor Name: Rig Name: Nabors 38 Date From - To Hours Code Sub Phase Code 8/17/2005 10:00 - 18:00 8.00 WELLS~ PULD CMPL TN 18:00 - 18:30 0.50 WELLSR PLGM CMPL TN 18:30 - 20:00 1.50 WELLSR INHC CMPL TN 20:00 - 20:45 0.75 WELLSR PLGM CMPLTN 8/18/2005 20:45 - 00:00 3.25 WELLSR TRIP CMPL TN 00:00 - 03:00 3.00 WELLSR TRIP CMPL TN 03:00 - 14:00 11.00 WELLSR TRIP CMPL TN 14:00 - 16:30 2.50 WELLSR TRIP CMPL TN 16:30 - 00:00 7.50 WELLSR TRIP CMPL TN 00:00 - 04:30 4.50 CMPL TN RUNT CMPL TN 04:30 - 06:45 2.25 CMPL TN SOHO CMPL TN 8/19/2005 06:45 - 08:45 2.00 CMPL TN DEQT CMPL TN 08:45 - 18:00 9.25 CMPL TN NUND CMPL TN 18:00 - 22:30 22:30 - 00:00 4.50 MOVE RURD MOVE 1.50 MOVE DMOB MOVE Page 7 of7 Start: 7/31/2005 Rig Release: 8/19/2005 Rig Number: Spud Date: 3/24/1995 End: Group: Description of Operations Continue to run in hole with completion. Did not see anything when we past the location (3220') previous FHL packer set at. Continue running in hole with completion. On bottom. Up wt = 68K Dwn wt. = 38K. RU head pin in jt 329' Established circulation 80 psi @ 1/4 BPM. Lowered seal assy until seals entered PBR, press increased to 150 psi shut down pump. Lowered seal assy and tagged locator @ 12368'. PU and put mark for space out of 2'. PU out of PBR. Spot 60 bbls of .5% by volume of Baker Petrolite CRW132 corrosion inhibitor to fill the IA from the PBR to the FHL packer @ 10,249'. Lowered seal assy back down and tagged, picked up 2' for space out. Staged press up to 750 psi to test seals in K-anchor, & PBR. Raised pressure on tubing up to 1900 psi, packer set at 1480 psi. Held 1900 psi for 10 min. Bled tubing press down to 1100 psi closed pipe rams and press backside to 2500 psi to test packer, held OK. Bled off backside and with 1000 psi on tubing picked up and sheared PBR @ 80K,10k Overpull. Bled press off ND head pin and hose. Prep to POOH laying down workstring. Lay down head pin, weight up brine in pits from, POOH laying down workstring. Continue POOH wI workstring laying down Out of hole and workstring layed down. Inspect seal assembly for rerun. Cleared rig floor of all tools not needed. Changed out tongs, & elevators. Held pre-job safety meeting. Picked up seal assembly, began running second run of completion. Continue running 3.5" completion. New seal rings installed on all connections. Up wt. 52K Down wt. 35K Stabbed the seals into the PBR. Tag top of PBR with locator. PU string weight plus 2'. Spaced out with 2 10' tubing pups. Space out leaves locator 2' above fully located position when tubing hanger is in tubing spool. MU hanger, land tubing hanger. RILDS. Pressure tubing to 2500 psi charted and held for 30 min. Bled tubing down to 1500 psi. Pressured IA to 2500 psi, had a leak on the unibolt connection. Shut down repaired lead repressure to 2500 psi held for 30 min. Bled tubing down to shear the dump kill valve in bottom GLM. Clean pits. Install BPV. NDBOP. NU tree. Pull BPV. Run test plug. Test tree and packoffs to 5000 psi. Pull test plug. Install BPV. Clean around well head and cellar. Released rig @ 1800 hrs 8/19/2005. RDMO, Prep rig and modules for rig move. Rig trucks on location, prep modules for rig move, move rig camp to 1 B-Pad. Printed: 9/8/2005 10:02:30 AM Re: 2T-23 (195-032) Casing Leak and Plan Forward ,¡ ) Subject: Re: 2T -23 (195-032) Casing Leak and Plan Forward From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 08 Aug 2005 16:15:27 -0800 To: "Gober, Howard" <Howard.Gober@conocophillips.com> CC: NSK Problem Well Supv <nI617@conocophillips.com> ) .J Howard, Your plan looks acceptable as we discussed. in your messages. It helps finding the files. Good luck with the work. Tom Maunder, PE AOGCC Just one request, would you please add the PTD number Gober, Howard wrote, On 8/8/2005 4: 11 PM: 'w "N' '\JE'r" I\,IJG {ì. O¡ 2n05 SCA h 'Wi ì-\~ , \.~ Ç.. -- Tom, I wanted to document our conversation this morning. We ran a test packer yesterday on 2T-23 to determine the depth of our casing leak. Here is a summary of the testing: Tested below the test packer to 2500 psi. This confirms that 11948 the permanent packer at 12398' is holding pressure Casing does not pressure test (PT) above the test packer. 11410 No communication with the drill pipe. Casing does not PT above the test packer. IA 11347 communicates with the drill pipe. 10875 Casing does not PT 10841 Casing pressure tests to 2500 psi. The bottom of our casing leak should be between 11347' and 11410'. The top of the casing leak is between 10841' and 10875'. Our plan is to run a seal assembly into the existing packer and then stack a packer above the top leak. We will set the top packer at +/- 10,300' RKB. Corrosion inhibited brine will be circulated into the annulus of the straddle to help mitigate any further corrosion. Please let me know if you have any questions or if you require further information. The approved Sundry asked CPAI to notify the commission upon determination of the depth of our casing leak. This e-mail will serve as the notification. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907 -263-4220 Office 907 -240-5515 Cell Howard. Gober(â2conocophill i ps. com 8/8/2005 4:21 PM @lFlÃ\~rc @ UiÄ1L ~ ) ífì.1 ¡ç: /A\ 11 fÀ\./AI@!V(m \.0 11 d llLS ln1 ~ lfu If!ü ) ALASKA. OIL AM) GAS Ii CONSERVATION COMMISSION FRANK H. MURKOWSK/, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276-7542 Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 ¡q7'-O:7"V SCJ\NNED JUL 2 0 2005 Re: Kuparuk 2T-23 Sundry Number: 305-195 Dear Mr. Gober: 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. Please provide at least twenty-four' (24) hours 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. Daniel T. Seamount, Jr. Commissioner ~ DATED thisa. day of July, 2005 Encl. ) ') ConocriP'hillips Alaska RECEIVED JUL 19 2005 Alalkä CUlt Gal ConQ~ Cømmlssion Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 15, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2T -23. 2T-23 was completed in August of 1995. A tubing leak was diagnosed in 2004. Several unsuccessful attempts were made to regain tubing integrity with patches. While preparing the well for a tubing changeout, it was determined that either the packer is leaking or that there is a casing leak. The purpose of the proposed workover will be to pull the existing tubing string. A test packer will be run to identify the location of any leak. A stack packer will be run above the leak. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 263-4220. Sincerely, ~ Howard B. Gober Wells Engineer CPAI Drilling and Wells ORIGINAL Cf-J-- 7- ZD. 0'5 ;;-, RECEIVED i/).v APPLICATION FOR SUNDRY APPROVAL JUL 19 20051 20 MC 25.280 ' Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 ) ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Type of Request: o o o Suspend 0 o o Stimulate o Alaska Oîl~i6aS CrmJ. ColTl11istion 0 o Time Ex~~'!De Re-enter Suspended Well 0 5. Permit to Drill N~ber: 195-032 V 6. API Number: 50-103-20216-00 V 9. Well Name and Number: 2T -23 Abandon Perforate Alter casing Repair well Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 41', pad 81' Pull Tubing 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory 0 Service 0 8. Property Designation: ADL 25548, ALK 2662 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 12977' 6116' 12606' Casing Length Size 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12414' MD TVD Burst CONDUCTOR SUR. CASING PROD. CASING 121' 121' 4065' 12847' 16" 121' 4187' 12969' 2855' 6112' 9-5/8" 7" Perforation Depth MD (ft): 12506'-12526', 12551'-12569' Packers and SSSV Type: pkr= BAKER SABL-3 PERM. Cameo 'OS' nipple NO-GO 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Perforation Depth TVD (ft): 5843'-5855',5869'-5880' Packers and SSSV MD (ft) pkr= 12398' 510' Tubing Size: 3-1/2" July 25, 2005 Date: 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Contact: Title: Printed Name ..- . ¡~ow",~ober ~1 Commission Use Only Signature Phone: 263-4603 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: \:)0\\\,\ c...o\f'^..~\ S<7\a " 0 ~ ~Q::\\)V\\ 'f'Ö...-\ '\ ô "'- 0 t \ <co. ~ . Subsequent Form Required: \...\ () ., RBDMS BFL JUl 2 1 2005 APPROVED BY COMMISSIONER THE COMMISSION ORIGI~Jj\L Collapse Tubing Grade: L-80 Tubing MD (ft): 12424' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Howard Gober @ 263-4220 Wells Engineer Date -1-lIq 1lY5 Sundry Number: 30£=- /qS- Date ~/5 Submit in Duplicate ) ) Kuparuk 2T-23 General Workover Procedure Pre-rig Work 1. RU Slickline Unit. Pull GL V's and install DV's at 1990', 5235' & 7664'. 2. Set CA-2 plug in nipple at 12414'. Dump bail sluggit on top 3. Combo MIT tubing and IA. Failed. -- 4. Run RST/WFL to determine leak point. Could not get past patch at 11382' RKB. All flow going below this point. 5. Obtain SBHP. 6. Chemical cut tubing above K anchor. 7. Prepare location for Workover Rig. 8. Set BPV. General Workover Procedure 1. MIRU Workover Rig. 2. Kill well. 3. ND Tree, MU blanking plug, NU 7-1/16" 5K BOPE. MASP=2969 psi. 4. Test the BOPE to 250/3500 psi (annular to 250/2500 psi). 5. Pull blanking plug. Pull BPV. 6. Pull tbg to chemical cut 7. PU workstring and RIH to fish K anchor. POOH with K anchor. 8. RIH with test packer. Test casing to 2500 psi. Identify leak point at packer or in casing. POOH. 9. MU K anchor/PBR, packer/PBR, and gas lift mandrels on new 3-1/2" tubing. Set packer. Pressure test IA to 2500 psi. 10. Shear PBR. Space out. Land tubing hanger. RILDS. Set BPV. 11. ND BOPE. NU Tree. Pull BPV. Set test plug. Test tree. Pull test plug. 12. Set BPV. RDMO workover rig. .. ~CJ\~~ Co~~\~~ \0" , . ) ) Post-Ria Work: 1. Pull BPV. 2. RU Slickline. Pull ball & rod, RHC, and SOY. 3. Circulate out brine. Freeze protect with diesel to +/- 2500' TVD. 4. Set DV in bottom mandrel. 5. Bail sluggit off the CA-2 plug. Pull CA-2 plug. Pull nipple reducer. 6. Tag fill. 7. Run gas lift valves. 8. Return to production. . ' ç;,YIT!~1,Çq~ll',!l2U .11II -lJ- .....- I I í i iJ -... '.) ) 2T·23 Ptoposed Workover 2.812° D5 Nipple g",5I81\i' C$Q 3.511 Tbg: 5 KBOOGLMiS & f MMMGlI\~ 2..81211 Caroco W-1 Nipple Oliginal Bak,er SABl-3 Pack-er with KBH-22 anchor OrkjlnaI2.75" Cameo D-Nípple 7" Csg ~~E9~!~·?~º"Çº~P~~~Q!~ ... ~,- 11I~llIIiill";.' ,;;;;'111'11 1IÎi. . ~!I:::r! ~-l" .. ~. ---lit I.....::....:.,,]"'" -- . II ~ : .~ . ¡ , i t ~ -... a... 2..875U D iNipple+l" 500' 3.5"lfbg 6 KBUG GILMS FHL PackarlPBR 2,812" DS Nipple PBR on top of SABL-3 pa~,er aNiKBH-:22 anchor Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job# I ~1- ),,(1 1 F-02 195 ",e'l.'L 2T-23 :;¡- 2W-12 I~'f 22.l( 2Z-19 If8-I'JtJ 1C-111 )e/--/2.. <g' 1C-117 )...ef- 1"2- r 3F-14 /8'5. :2..72 2K-07 2Z-12A l<gr~ 07 ( {'15- /eft 10922513 10952507 10942806 10922502 10922504 10922505 10922499 10922503 10922501 Log Description INJECTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE LEAK DETECTION LOG INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE LEAK DETECTION LOG S'GNd ek.- Þl.~ ::iGANNED API? 1 8 2005 Date 12/14104 12/08/04 12/15/04 12/04/04 12/06/04 12/06/04 12103/04 12/05104 12/04/04 NO. 3292 Company: 12/23/04 I rY--D32- Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk DATE: BL Color 1 1 1 1 1 1 1 1 1 f3~Ç Please sign and return on copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ..~ CD ~ ) ConocóP'hillips Alaska ) P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 E EI OCT 2 7 2004 Alaska Oil & October 25, 2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find two 10-403 Sundry Notice variance request and one 10-404 Sundry Report of Operations for Phillips Alaska, Inc., wells 1D-141, 1D-113 and 2T-23 . The variance requests are for approval to gas lift 1D-141 and 1D-113 with failed ESP pumps. Also attached is a discussion and well schematic for each. The 10-404 reports the completion of a tubing patch in well 2T -23. Please let me know if you have any questions regarding the Sundries. Sincerely, U ::t¿f . / Phillips Problem Well Supervisor Attachments SCANNED NOV 0 3 20D,~ ) /9{ - 051- RECEIVED ALASKA OIL AND ~T:;~g~S~L:~:;;ON COMMISSION OCT 2 7 2004 REPORT OF SUNDRY WELL OPERATION91aska Oil & Gas Cons. Commission Other An~rage Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 195-032 I 6. API Number: 50-103-20216-00 Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl 0 0 0 0 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: Oil 0 GasD WAGD GINJD WINJ D 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: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: RepairWell 0 Pull Tubing D Operat. ShutdownD Plug Perforations 0 Perforate New Pool 0 Perforate D 4. Current Well Status: Development - 0 Stratigraphic 0 1 . Operations Performed: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 122' 8. Property Designation: ADL 25548, ALK 2662 11. Present Well Condition Summary: Total Depth measured 12977' 61161 feet true vertical feet feet Effective Depth measured 12606' true vertical feet Casing Structural CONDUCTOR SUR. CASING PROD. CASING Size MD Length 16" 9-5/8" 121' 4065' 12847' 121' 4187' 12969' 7" Perforation depth: Measured depth: 12506'-12526', 12551'-12569' true vertical depth: 5843'-5855',5869'-5880' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 12424' MD. Packers & SSSV (type & measured depth) pkr= BAKER SABL-3 PERM. pkr= 12398' Cameo 'OS' nipple @ 510' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Oil-Bbl 0 0 Contact MJ Loveland/Brad Gathman Printed Name MJ Loveland ¿ / Title Signature ~~~~one659-7224 Form 10-404 ~ed 04;2004 ABDMS BFL Stimulate 0 Waiver 0 Exploratory 0 Service 0 9. Well Name and Number: 2T -23 10. Field/Pool(s): Kuparul River Field I Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Collapse Burst 121' 2855' 6112' CasinQ Pressure 1275 1275 TubinQ Pressure 1300 1300 WDSPLD Problem Well Supervisors Date ø. S-Oê T6<..l.f Prepared bv Sharon Allsup-Drake 263-4612 '1. ."} ') ". 0 ~ OC1 I;j e f-U Submit Original Only .~~}1~!~H~L,~~~~!cLnPA~~ Frac String 1 D-113 (0-6206, 00:3.500, 10:2.992) Production (0-6851, 00:7.625, Wt:29.70) PUMP (6077-6112, 00:2.313) NIP (6112-6116, 00:3.500) SEAL (6116-6123, 00:5.130) J GEARBOX (6123-6124, 00:5.250) Perl (6282-6312) GRAVEL (6187-6580, 00:4.500) - I I ....-..;... I C í'~ Gas Lift MandrelsNalves i St MD TVD Man Man Mfr Type 1 6015 3351 CAMCO KBMM :~Lt~ri!(~I\.(ö~~1t~qq!~~~"'g~ç~):~'[~al(l;J:iß~ .' Depth TVD Type 6077 3406 PUMP 6112 3437 NIP 6116 3441 SEAL 6123 3447 GEARBOX 6124 3448 MOTOR 6187 3504 GRAVEL API: 500292291700 SSSV Type: NONE ¡ Annular Fluid: 3% KCI I Reference Log: : Last Tag: Last Tag Date: Casing String - ALL Description Conductor Production "Tubing String. ALL ; Size I Top 3.500 0 ¡ Perforations Summary "Interval TVD 6282 - 6312 3590 - 3617 6354 - 6374 3655 - 3673 6407 - 6427 3702 - 3720 6462 - 6482 3752 - 3770 6530 - 6547 3814 - 3829 Size 16.000 7.625 Zone WSD WSB WSA4 WSA3 WSA2 K.1 1 D-113 Well Type: PROD Orig Completion: 9/17/98 Last W/O: 9/28/99 Ref Log Date: TO: 6866 ftKB Max Hole Angle: 66 deg @ 3836 Angle @ TS: deg @ Angle @ TO: 24 deg @ 6866 Rev Reason: Set SOV by ImO Last Update: 4/23/01 Top 0 0 Bottom 121 6851 TVD 121 4106 Wt Grade Thread 62.58 H-40 WELDED 29.70 L-80 BTC Bottom 6206 TVD 3521 Wt I Grade I 9.30 L-80 Thread EUE 8rd Status Ft SPF Date Type Comment 30 4 11/10/98 IPERF 2 1/8" ENERJET, BH; 0 deg phasing 20 4 11/2/98 APERF 2 1/8" ENERJET, BH; 0 deg phasing 20 4 10/27/98 APERF 2 1/8" ENERJET, BH; 0 deg phasing 20 4 10/15/98 APERF 2 1/8" ENERJET, BH; 0 deg phasing 17 4 10/9/98 APERF 2 1/8" ENERJET, BH; 0 deg phasing V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt 4/22/01 2500# SOV 0.0 0.000 0 '.~ . i ," . :~ " "'; " . ... Description CENTRILlFT Retrievable 180ML2000 KUDU pump RESET 3/26/01 Slotted nipple Tandem Seal GSB3 DB IL H6PFS Gear reduction unit 9:1 525 Series Centrilift motor 57 HP 1315/26 KMH w/centralizer ID 0.000 2.992 0.000 0.000 0.000 0.000 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 January 29, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2T-23 (195-032) Dear Commissioner Oechsli Taylor: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforations on the KRU well 2T-23. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad , = STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 122 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 4842' FNL, 4724' FEL, Sec. 1, T11 N, R8E , UM (asp's 498944, 5970416) 2T-23 At top of productive interval 9. Permit number / approval number 195-032 / At effective depth 10. APl number 50-103-20216 At total depth 11. Field / Pool 592' FNL, 3835' FEL, Sec. 35, T12N, R8E, UM (asp's 494549, 5979947) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 12977 feet Plugs (measured) true vertical 6116 feet Effective depth: measured 12629 feet Junk (measured) true vertical 5915' feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 225 sx AS I 121' 121' SUR. CASING 4065' 9-5/8" 800 sx AS III, 730 sx Class G 4187' 2855' PROD. CASING 12847' 7" 267 sx C~ass G 12969' 6112' . , Perforation depth: measured 12506' - 12526', 12551' - 12569' r: true vertical 5843' - 5855', 5869' - 5880' . !.,-"' ir! i~ i'' ' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 12424' MD. Packers & SSSV (type & measured depth) BAKER SABL-3 PERM. @ 12398' MD. CAMCO ' DS' @ 510' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Average Production or I niection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 235 543 383 - 284 Subsequent to operation 367 1094 592 295 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ X Gas _ Suspended __ Service _ _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney 263-4574 / Signed //~-' /~///'~t~,~"~ Title Wells Team Leader Date //~__ ~///~ ~ Michael Moone)/ . Prepared b)/ Sharon AIIsup-Dra~e 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 2T-23 Event History 12/06/01 12/19/01 12/24/01 MILLED TO 12,600.7' WITH A 2.65" UNIVERSAL THREE BLADED MILL. NEVER TAGGED FILL OR SCALE WITH BIT. NO MOTOR WORK. PURGED COIL W / N2 FOR REEL SWAP IN PRUDHOE. LEFT WELL ON PRODUCTION. [FCO] TAGGED FILL @ 12624' RKB (56' BELOW TARGET PERF). DRIFTED TBG W/15' X 2.125" STEM W/ PETROLINE ROLLER ON BTM. [TAG] FREEZE PROTECT FLOWLINE W/20 BBL METHANOL. FIRST GUN MISFIRED. PERFORATE 12551'-69' WITH 2-1/8" 6 SPF, 0 DEG PHASED, POWER JET ENERJET. [PERF] Page I of I 1/21/2002 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2001 - W M ATE .............. IA L U N D ER TH IS M ARK ER P E R Pi l T AO,3CC Ind'¥v'idu,sl ~?~xll G e o 1 o g -i c a 'l l:'i ,-'a'i: e r' "i a I s I i'~ v e n L o r" y DATA I DATA_P L LIS DATE ~'/2J~/?l~/ APe dr"y 1,2// Il /c/ W a s 'L h e w e I 'i c o t" e d ? y e s ~ Analys'is & descr"'¥p'!:-i'on r'ecei'ved? _~ Rece'~ ved? ~- ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 5, 1995 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T-23 (Permit No. 95-32) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 2T- 23. If there are any questions, please call 265-6206. Sincerely, M. Zang~ Supervisor Kuparuk Drill Site Development Ala,ka Oil & ~'''" L/~S COilS. OOlBfflis$iOn MZ/skad ORIGINAL STATE OF ALASKA ALA~,<A OIL AND GAS CONSERVATION COMk,',.'SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL E~ GAS E~ SUSPENDED r--] ABANDONED [] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-32 3 Address 8 APl Number P,O, Box 100360, Anchoracge, AK 99510-0360 50-103-20216 ¢ , .! ~-'i:.~~ .... ..~ 9 Unit or Lease Name 4 Location of well at surface ~ '¢; .: : :.:: .. ~ 432'FSL, 556'F'WL, Sec. 1 T11N, R8E, UM ~ .... ',-~:!!0.:'; ~ fi[ At lop Producing Interval 10 Well Number At Total Depth .' 11 Field and Pool 592' FNL, 1445' F-WL, Sec. 35, T12N, R8E, UM .... KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Kuparuk River Oil Pool RKB 41', Pad 81' ADL 25548 ALK 2662 12 Date SpuddedMarch 24, 1995 13 Date T.D. ReachedApril 4, 1995 14 Date C°mp' ' Susp' °r Aband'28-Sep-95 (peri'd) I15 Water Depth' if OffshOreNA feet MSL 116 NO' Of cOm pletiOnsl 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrosl 12977' MD & 6116' TVD 12879' MD & 6060' TVD YES xL.x__J NO LJI NA feet MD ~ 1380' ss APPROX 22 Type Electric or Other Logs Run GR/CDR ,. 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 Surf. 121' 24" 225 sx AS I 9.625" 40.0# L-80 Surf. 4181' 12.25" 800 sx AS III Lead, 730 sx Class G Tail 7" 26.0# L-80 Surf. 12969' 8.5" 267 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" ~12424' 12398' 12506' - 12526' MD 4 spf 5843' - 5855' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12506' - 12526' 166,000 # proppant (19000# 20/40, 171,340# 12/18 and 9607# 10/14 27 PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) Oct-95} Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO November 28, 199 24.1 TEST PERIOD ¢ 1250 803 193 0 495 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 355 753 24-HOUR RATE I~ t 124 556 192 24.0° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Al~k~ Oil & G~s Con~. Commi~i~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED QN REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 12497' 5838' Bottom Kuparuk C 12504' 5842' Top Kuparuk A 12504' 5842' Bottom Kupark A 12666' 5936" · ' Atssk~ 0it & g~-s Cor~s. Cornrnissior~ Anchorage 31. LIST OF A-Ff-ACHMENTS Daily Drilling History, Directional Survey 32. I hereby certify that thp foregoing is true and correct to the best of my knowlege. Signed ~'< Title DATE · INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date:il/01/95 Page: 1 ARCO Alaska Inc. DAILY DRILLING REPORT WELL:2T-23 RIG:PARKER 245 WI: 55% SECURITY:0 WELLID: AK8149 AFE: AK8149 TYPE:DEV AFE EST:$ 1624M/ 2110M AREA/CNTY:NORTH SLOPE STATE:AK API NUMBER:50-103-20216 FIELD: KUPARUK RIVER SPUD:03/24/95 START COMP: FINAL: 03/25/95 ( 1) TD: 974'(974) SUPV:JT 03/26/95 (2) TD: 4140' (3166) SUPV: JT 03/27/95 (3) TD: 4200' ( 60) SUPV:JT 03/28/95 (4) TD: 5176'(976) SUPV:JT 03/29/95 (5) TD: 6442' (1266) SUPV: RLM 03/30/95 (6) TD: 9063'(2621) SUPV:RLM 03/31/95 ( 7) TD:11592' (2529) SUPV: RLM 04/01/95 ( 8) TD:12329' (737) SUPV:RLM 04/02/95 ( 9) TD:12329' ( 0) SUPV:RLM MW: 9.4 PV/YP: 20/24 APIWL: 8.2 TRIPPING Rig accept 1630 3/24/95. Spud at 2130 hrs 3/24/95. Directional drill 12.25" hole from 121' to 974'. DAILY:S62,549 CUM:$62,549 ETD:SO EFC:$1,686,449 MW: 10.0 DRLG Drilledd f/916 t/4140. DAILY: $99,883 CUM: $162,432 PV/YP: 16/18 ETD:SO APIWL: 8.0 EFC: $1,786,332 MW: 10.0 PV/YP: 19/14 APIWL: 7.4 TESTING BOPE Drilled from 4140' to 4200'. Run 9-5/8" casing to bottom. CIP @ 2300 hrs. Testing BOPE. DAILY:S207,679 CUM:$370,111 ETD:S0 EFC:$1,994,011 MW: 9.5 PV/YP: 10/14 APIWL: 6.8 DRILLING Finish testing BOPE. Drilled froom 4210 to 5176'. DAILY:S88,692 CUM:$458,803 ETD:SO EFC:$2,082,703 MW: 9.7 PV/YP: 17/13 APIWL: 5.8 DRILLING Directional drill 8.5" hole from 5179' to 6442'. DAILY:S101,787 CUM:$560,590 ETD:SO EFC:$2,184,490 MW: 9.4 PV/YP: 14/17 APIWL: 6.2 DRILLING Directional drill 8.5" hole from 6442' to 9063'. DAILY:S81,669 CUM:$642,259 ETD:SO EFC:$2,266,159 MW: 9.6 PV/YP: 16/20 APIWL: 5.4 DRILLING Directional drill 8.5" hole from 9063' to 11592'. DAILY:S84,191 CUM:$726,450 ETD:SO EFC:$2,350,350 MW: 9.6 PV/YP: 16/20 APIWL: 5.4 POOH Directional drill 8.5" hole from 11592' to 12329' -- DAILY:S119,155 CUM:$845,605 ETD:SO EFC:$2,469,505 MW: 10.9 PV/YP: 15/11 APIWL: 8.0 STAGE IN HOLE POOH. Lay down turbine and MWD. Make up rotary drilling assembly. RIH. Stage in, circulate. DAILY: $97,819 CUM: $943,424 ETD:SO EFC: $2,567,324 OEC 1 I 1995 Alaska Oil & Gas Cons. Commission A,q, chorage Date:Il/01/95 Page: 2 04/03/95 (10) TD:12511' (182) SUPV:RLM 04/04/95 (11) TD:12932' (421) SUPV:RLM 04/05/95 (12) TD:12977' ( 45) SUPV:JT 04/06/95 (13) TD:12977' ( 0) SUPV:JT 04/07/95 (14) TD:12977' ( 0) SUPV:JT 04/08/95 (15) TD:12879' ( 0) SUPV:JT ARCO Alaska Inc. DAILY DRILLING REPORT MW: 10.9 PV/YP: 21/13 APIWL: 8.0 DRILLING Cut new bit pattern and break in bit. Drilled from 12329' to 12511' · DAILY:S83,228 CUM:$1,026,652 ETD:SO EFC:$2,650,552 MW: 11.1 PV/YP: 20/14 DRILLING Drill 8.5" hole from 12511' to 12932'. DAILY:S91,803 CUM:$1,118,455 ETD:SO APIWL: 4.8 EFC: $2,742,355 MW: 11.3 PV/YP: 28/12 POOH TO RUN CASING Drld f/12930 t/12977. DAILY:S98,521 CUM:$1,216,976 ETD:SO APIWL: 5.0 EFC: $2,840,876 MW: 11.3 PV/YP: 26/13 APIWL: 5.6 POOH TO RUN CASING POOH to run casing. Well was dead. Incorrect fillup volume. RIH. CBU. No gas. POOH. DAILY:S74,475 CUM:$1,291,451 ETD:SO EFC:$2,915,351 MW: 11.3 PV/YP: 22/12 APIWL: 6.2 CEMENTING CASING Finish POH to run casing· RU to run 7" casing to 12977' TD. Circulate, reciprocate and condition mud and cement 7". Displace with diesel and seawater. DAILY:SO CUM:$1,291,451 ETD:SO EFC:$2,915,351 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Completed cement job. CIP @ 0715. ND BOPE. Set pack-off and test. Freeze protect annulus. Release rig 4/7/95 @ 1830. DAILY:SO CUM:$1,291,451 ETD:SO EFC:$2,915,351 ~EC 1 1 1~95 Aleska Oil & G~s Cons. Comrnissm~ Anchora,qe Date: 11/01/95 Page: 3 ARCO Alaska Inc. DAILY DRILLING REPORT REMEDIAL AND COMPLETION OPERATIONS WELL: WELLID: AK8149 AREA/CNTY: FIELD: SPUD: RIG:NORDIC WI: 0% SECURITY:0 AFE: AK8149 TYPE:DEV AFE EST:$ 1624M/ 2110M STATE: API NUNIBER: START COMP: FINAL: 08/25/95 (16) TD:12977' PB:12879' SUPV:DCL RACK AND TALLY TUBING MW: 8.6 SEAWATER Move rig from 2T-22 to 2T-23. Nipple up BOPE. DAILY: $19,776 CUM:$1,311,227 ETD:S0 EFC: $2,935,127 08/26/95 (17) TD:12977' PB:12879' SUPV:DCL RACK AND TALLY TBG MW: 8.6 SEAWATER Pressure test 7" casing. RIH with 3-1/2" completion equipment. DAILY: $31,200 CUM:$1,342,427 ETD:S0 EFC: $2,966,327 08/27/95 (18) TD:12977' PB:12879' SUPV:DCL RIG RELEASED MW: 0.0 Run in hole with 3-1/2" completion equipment. Set packer. Freeze protect. Test tree and packoff. Secure well. Release rig @ 2100 8/26/95. DAILY:S118,495 CUM:$1,460,922 ETD:SO EFC:$3,084,822 9/28/95 Perforated from 12,506'-12,526' with 2-1/8" enerjet BH charges, 4 spf (oriented @ 90° CW and CCW from lowside of hole). Pumped 345 bbls of dsl to get guns downhole. End of WellSummary for Well:AK8149 Oil & G.~s Oons. ' "' "' L,O~TihIISSIO~ Anchorage · 'i / ' i I /· / , ;It · ' z ./' t' ?.u£ .~::S ~ 8i4.9 APl WE~ ND: 50-103-2021600 W~L HEAD LO:..Ailu.~,,,. ~.(N/-o) ,. ,. TiE IN POINT(TIP) : ~.-,.,.-.,,n~ "~' . ...:.-~.,',~ D~.F ,H T::UE ~RT D?TH 121,00 :N.,.I~.TIuN 0,00 A:.:MLOI4 0,00 ~::T~(N/-S) 0,00 DB?ARTI.~ (~./-W) 0,00 -T .... ~,~ :.r, i¥,r- ~., ,-r ........ i2i .v',. ..... O0 --,-~ ~, n , ,:.'.,:., =.':,,', ne; lDO.,,0 ~-'~ ~'" 6'.' 9,'':r' 90, "~" 70?, 0".; ,-.r- ~,~, 'r r',}. ! h'~' :,z, c4: u..-: I bk, LF.', F',:'-~ ft de: dea ft 0,00 (:,CE: 0,00 :.',. 0,:, -0,9'? 0,50 .... 0,75. 4~,00 -I - ..-'. ~l 1,25 2,52 .... ~, ~ ~..~ -' t ~- . l-..'r%,",A,'-,n~l}r?', f'~Tt".r,t A.~M?'.I'~ 0,00 0,rXi 0,51 ;' '"" '"' ~ , v-, 1 ~ ~D,65 2,48 2,57 74,1~ ~ ,-~ ~ -. ~ ~ .- dea,' 0,00 0,57 / i-;~7 893,63 iOO~, 69 I101 ~ t-,~ ,-,~' _ &:,// .-, J.{. ._*-7 iO '-'~'-', -~ -24,63 78,52 341,72 2,52 13S3 =~' !476,2(, 1572,-;.~'"'-' 16,55,5'7 i 0 3,37 i 6,75' 335, ! 9 ?7.4,'., ~0¢,.0 24,91 o~4 245,30 28,~: ~" -47,'~ ,,:,.5 _ . ,0 : ..... 12 33'-?, 14 ?,9/', .... ,:_, _, ,>u,/:.'.;' c-~c.,/'.~, ,',.~/ ,-,dj,/1 338,09 3,32 -76,O3 -93,76 245 , ~.., ,.%5/ , ..;.--' -J' ~ '."£ 91,4 1705,25 '75,2 i~57,13 93,9 1914;,i? 94,0 271,02 .:-.z ,77 '" ~' _ ,, O0/ . o.2,sr: ~';,55 *'~ 31 "'"" TM 349 "~ 4c, J, ~?.39 ¢61,68 42,26 ~$,05 425.26 ~26.65 45,16 * '~ '-= ad 2'.;' ! ,27 337,32 4,0'-}' -i31 '"" .. .... .- ..... 4,07 -153,99 400,69 337,40 4+06 -178,3,5 462,07 337,~? 3,'.7 -205,11 527,03: 337,10 "'~ -5+.{.£ 2413,13 ~06,25 ~,5 2052,2:, 9!,7 2!21," · -.~ ~- v~: ,.., 2177,,:,5 r:,,l 22.-..~3, l: 92,2 2278, _. . J/"/.0- =~",$F_::7~. 48,27 ~-,~ ., ~ ~ ,, ~,~,~ .... =~1,//" ~6,01 611,% 740,48 ~,49 336,28 63I. 10 817.~ ~.21 235,46 896,09 59,62 ~u= ~= ~o, ~, ~ 22.83 -232,79 5'75,07 336.',5'7 3,48 -26!,02 6,.45,33 336,90 3,55 -Z?I,~ 740,69 3:36,82 -323,09 817,95 336,73 3,00 8;o,4,_. .:SE, -3f5,84 '"' ~ ,61 2,63 27&3,91 c.,', .-,~ 63 31.,60,94 3350,18, 93,9 2357,25 93,7 2407,25 283,3 25!4,.i3 i89,2 2.:.-D'7 ~' 975,63 61,19 005,64 ~"= * ;' ~ r,~,-. OO~l'. 7%.-" 7/,/-/~:, :v.~o,81 /'.3,45 ........ - ..... ' 1143,54 ~,Ol ~J,'~= 44 lC:47:64 1405,84 69,65 "~," '":"A '"'~ !5,54,08 71,18 ~6,12 -~8.~0 976,0! 030,52 ~6 -423,70 i~9,17 ~ ,~ -.u?,28 1143,89 3~$,33 -~%,71 t406,20 -A~8,-? ~ 23 ._ /,' 1584,49 oo6, 2;7? ],31 i~) t, 4 · .-, O.{. 353.3,~'3 38!6,48 .000,26 41!2,97 42'~3,87 ,-,~Z,5 2732,5.~ l&~,, 8 2794, !09,7 2830, 1757,52 70,27 ...,_,'~, ,,,.. '~ 1 ~':.'-~. ·*= .-' 20~,83 70.73 3~3,52 !~,".<: S_~ ~00,0'? 70,73 3~,36 200f,.10 2~3,7'{ 70 ,?4 3S5,18 z,/.t,~ 69,95 336,16 2,'_.:.. -710,07 1,'r57,9~ Eq6,18 -8~,03 ..~.,~n~ 16 335,95 -%~3,&6 2200,~ 335,75 -948,84 2303,91 3~,68 -1017,90 2471,54 335,.~ 0,64 0,63 u,08 , ~,58 0,76 190,4 97,0 ....,55_, O£o,' _ 2827,15 72,3~ S~4,40 2575.01 3<:)03,60 71,07 ~%'2,03 70,~ ~7,11 3i~,15 69,82 3~9,~ 2%0,16 -1092.22 2651,17 ~.,q'~ 67 q167,57 2827 ~= ' . -1243,06 3003,78 3~,55 -1778,9'? ' ' ~" ,~/ ~2,70 3183.41 ~5,65 o 0.,4 0,64 0,76 2,24 2.4? ft ft ft ft de9 des ft ~ ~' '~" 3~,2,~ ~'~l,v., 72,34 ~ ~/~ 5~2~ ~ !89,4 ~ ~i, o4~,.~= .~,8.~ 34i,56 3!51 ~:"~ ~ 187,8 ~34'?,~7' .... ~,~r'~,,~= 70,75 ~3..4,1i 34f,2.50 C:-: J ' * -." :-' ..... ' 6542,02 :'"' = 36f2, ~. ,_..:,,, ~, .... 7A 4:-£,2.3','._ . "' - ,.-~. ~ ,~,, a---, ! -..' ~. .... ' !6 ~" 8Y ...... · :,/~Y, :8/,2 -'_'?.67,~ 4772,61 45 70!4,1,.4 285,0 5.-.'M,-'<.q ..... ~,,v="~",4l 729O 101 l, 7755 e. 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"' -o~.o,=~ 6104 ~ ~5,15 -0,/4o¥1 8278,48 335,z8 -3620,17 86~?,37 3.35,20 ~':" .... ~L,2v 0,76 0,74 11208,60 11o:1.11 11482,33 11573,5/-,. "., A.q, A 5235,1.=- n,;,v'n AC' A9+16 .... ~! ~.,. i - - .... W4o,.'/c. ,;,/ ,..,,.~, 48 fi~'5'7.52, 182,5 5'::'K.:',,V~ '" '" '"-' ,.-,'"~, '- ~'"'" ' 9t,2 s':-3'~,';.'~..,~ .. _ y;.--o,88 ~,8,74. ...... oo/.~,61 "~"~ a~' A7,8~ ,..~33.89 '" 91,2 5357.6_~ ~, .~ .. -3765,86 "" '" 335.19 'a~,~..- 9i44,00 -3880,22 ~..o,~J 3~,14 '3917,84} 9313,,~4 ~5,12 -3954,23 9397,58 335,12 1,48 0,30 1,09 1175..4,60 11847,57 I1~?, !3 1~30,12 =' '" . 335,88 MO1.SJ 9'2,1 :-40,.:,5 9481,58 _/,4,95 91,0 ~gO,60 956~,16 62,54 ~4,75 8675.~ 91,6 5524,73 9643,36 5'?,82 336,42 8745.67 91.0 =%57/1,8[ 9721,16 ~,86 ~7,60 8820,3-.I 92,3 56~.,04 9798,53 56.,20 ~7,04 -3989,42 9481,~3 ~5,12 -4023,4~ 9563,21 335,12 -~0~.,63 9643,42 ~5,12 -4087,05 972!,24 335,14 , ', m ~5,16 -41~6,¥i 9798,.z 2,37 2,,57 3,37 2,43 1,87 _~.~ .,.a, ..-'~~..~ a.t.,.~ a.; .~-,l. aJ"t,~ .... '- fi ft ft d~ dea ft ft ft dec ' ,"'-'; c~2,i .;c,.,~,,:,,~" .... " '>~'~'.,..., -,,_.ql 54,57 ,~3/,,~3. ,~ 65F,! . ~1: -%4,f,,c,'! %74,40. 3:35,i.7 i ,86 t_?[:,,, ¢01]':'5, Co~,~T~iS${Orr A!sska 0i} & "'7 -* ,. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9894 Company: 1 1/1 7/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 1Q-26 95360 ARC 5 950922 I I 1 ,, ,, , , , SIGNED: Alaska Oi~ & G~:s Cons. DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9766 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) 9/29/95 Well Job # Log Description Date BL RF Sepia DIR MWD Tape SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ALASKA OIL AND GAS CONSERVATION COMMISSION .TONY KNOWLE$, (~OVEFINOI~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 21,. 1995 . Michael Zanghi Drill Site Develop Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2T-23 ARCO Alaska, Inc. Permit No: 95-32 Sur. Loc. 432'FSL, 556'FWL, Sec. 1, TllN, R8E, UM Btmhole Loc. 670'FNL, 1410'FWL, Sec. 35, T12N, R8E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. y, Chairman~ ~ BY ORDER OF THE ' ISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry r'~ Deepen I-] Service r"'! Development Gas [] Single Zone X MultlpleZone r'~ 2. Name of Operator 5. Datum ElevalJon (DF or KB) 1 0. Reid and Pool ARCO Alaska, Inc. RKB 41' Pad 81' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25548, ALK 2662 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAO 25,025) 432' FSL, 556' FWL, Sec. 1, T11N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8, Well number Number 948' FNL, 1540' FWL, Sec. 35, T12N, RSE, UM 2T-23 #U-63061 0 At total depth 9. Approximate spud date Amount 670' FNL, 1410' FWL, Sec. 35, T12N, RSE, UM 3/21/95 $200,000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2T-2 12949' MD 670'@ TD feet 20.8'@ 640' MD feet 2560 6120' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25,035(e)(2)) Kickoff depth 700' feet Maximum holeangle 70.3° Ma~m~u~ace 1694 p=~ At tot,,' ~p~h ('rVD) 3200 pNg 18. Casing program Settin~l Depth . size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Couplincj Length MD TVD MD TVD (include stage data! 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' :~_2.00 CF 12.25" 9.625" 40.0# L-80 BTC 4079' 41' 41' 4120' 2861' 740 Sx Arcticset III & HF-ERW 730 Sx Class G 8.5" 7" 26.0# L-80 BTCMOC 12908 41' 41' 12949' 6120' 260SxClassG HF-ERW Top 500' above Kuparuk 1 9. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural sCu°r~fadd~:t°r R E C E iV E D Intermediate Production Liner MAR 1 ;5 1995 Perforation depth: measured ~ Oil & Gas Cons. Commission true vertical ..... '~ ~chora, ~' 20. Attachments Filing fee X Property plat I'-I BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X 'Dine vs depth plot r'"J Refraction analysis E] Seabed report r-] 20 AAC 25.o5o requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed o Title Drill Site Develop. Supv. Date '~"'~ Commission Use Only I ISee c°ver letter f°r Permit Number~..._,T-'~--- I 50'/~:~-rAPInumber :~---~---/~ Approval date~.~..~ '"~/~ 2~ other recluirements Conditions of approvaJ Samples required g] Yes "~ No Mud log required [--~ Yes [~ No Hydrogen sulfide measures ri Yes [] No Directional survey required [~ Yes r~ No Required working pressure forBOPE r~ 2M [] 3M [~ 5M r~ 1OM r-! 15M Other: Original Signed By David W. Johnston by order of Form 10-401 Rev. 7-24-89 Submit in triplicate GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 2T-23 , , , 10. 11. 12. 13. 14. 15. 16. 17. 18. Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,120')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (12,949') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (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.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve and NU master valve and cap. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly. Set and pressure test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. DRILLING FLUID PROGRAM Well 2T-23 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.0 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 Derdck 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 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 1,694 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2T-23 is 2T-2. As designed, the minimum distance between the two wells would be 20.8'@ 640' MD. Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The annulus will either be filled with diesel upon completion of fluid pumping. If isolation is reqired per regulations on significant hydrocarbons, the annulus will be sealed with cement from the top of hydrocarbons to the base of the permafrost, with Arctic pack or diesel above to the surface. Risks in the 2T-23 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. The 7" casing will be topset above the Kuparuk and a 5" liner run 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 11.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 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. RECEIVED MAR 1 3 1995 0il & 6as Cons. Commission Anchora ~' Created by : jones For: D PETI~SH Date plotted : 25-Feb-95 Plot Reference is 23 Version #5. iCoordinates are in feet reference slot #23. ITrue Vertical Depths are reference Estimated RKB. --- Baker Hughe= INTEO --- ARCO ALASKA, Inc. Structure : Pad 2T Well : 23 Field : Kuparuk River Unit Location : North Slope, Alaska <-- West ~a,,, : ~,o.oo 5000 4500 4000 3500 3~ 25D0 2000 15001000 500 0 500 I II II II II II II II II I I I I I I 10000 ~7~ ~.~ ~o' ~1 ~ _.ooo SEC. 35. T12N, R8£ I --~ _ ,~le ~rop I T~G~ LO~N: ! ~ - I*~' ~ '~' ~l ~D~12549 DEP-10135 ~ g180 55~ N gS.0g DEG W ~o~aa' (TO ~~) RECEIVED ~ B/ W ~ SNDS ~=2672 ~D=~9 ~P=1752 ~ . , S~F~E L~T~N _ M~MUM ANGLE ~ 70.3 DEG ........ T~G~ T ZO i i ~ i i ~ ~ i ~ i i ~ ~ i i ~ i i i i i i i t i i ~ i ~ i i i ~ i ~ ~ i 1oo 1~ ~ 27~ 3~ 38~ 4~ 4950 55~ ~ 6~ 71~ 77~ 82~o 8~ 95~ 9900 lO4~ 1 ~o Scale 1 : 275.00 Vertical Section on 334.92 azimuth with reference 0.00 N, 0.00 E from slot #23 /X I I z ARCO ALASKA, Inc. Structure : Pad 2T Well: 32/25/29/26/22/31 Field : Kuparuk River Unit Location : North Slope, Alaska ~oo,~,: ,o.oo E a st - - > 2_20 240 260 280 50t3 320 340 560 580 400 420 440 460 480 500 .520 540 560 580 600 620 640 780 · 740 720 640. I I tSO0 1200 1400 _760 _620 - 0 520. 1200 240 260 2~:0 ,DO0 320 .D40 360 Scole 1 : 10.00 400 420 East 460 .o 480 500 520 540 560 580 600 620 64-0 ARC0 ALASKA, Sfrucfure : Pod 2T Well: 32/23/29/26/22/31 Field : Kuporuk River Unif Location : Norfh Slope, Alosko ~o,e ~: ~o.oo East --> ,.320 280 240 200 1 ~0 120 80 40 0 40 BO 120 160 200 240 280 320 360 400 440 480 520 1720. 1600 520, 1320 1280 g c~ lOBO ,. 1960 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 J I I I · 1920. 2600 . 3,300 1880. . 1840. 1800 2,'~0 2300 2?OO 1960 _ _1920 _ _1880 _ _1840 1760 _ _ ! 720 1680 1640 _ _1600 _ _1560 - _1520 _1480 _1440 ~132O ~1280 ~1240 120O 520 280 240 200 160 120 8o 40 o 443 80 120 160 200 240 280 .320 360 400 440 480 520 ~o,~ ~: ~o.oo E a st - - > Casing Design / Cement Calculations 3-Mar-95 Well Number: 2T-23 I Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Kuparuk, TMD: Top of Target, C Sands, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 4,120 ft 2,861 ft 12,949 ft 6,120 ft 2,412 ft 12,549 ft 5,862 ft 3200 psi '3';~bb"i~'~i ................................. Maximum anticipated surface pressure TVD surface shoe = 2,861 ft {(13.5'0.052)-0.11}*TVDshoe =[ 1,694 psiJ Estimated BH pressure at top of target zone Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =1 3,200.0 ppg 5,862 ft 150 psi 11.0 PPgl surface-ie'ad-: ....................................... ' ......................................................................... ;i;~p"w~:S{"~'k;"YM'D'"'-' .......... '"" ......... ' .................. 2;';~';i'2-'~ Design lead bottom 500 ft above the Top of West Sak = 1,912 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 649 cf Excess factor = 120% Cement volume required = 1,427 cf Yield for Permafrost Cmt = 1.94 Cement volume required =[ 740 sxJ Surface tail: TMD shoe (surface TD - 500' above West Sak) * (Annulus area) = 4,120 ft = 692 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4257 cf/If Cmt required in casing = 34 cf Total cmt = 726 cf Excess factor = 15% Cement volume required = 834 cf Yield for Class G cmt = 1.15 Cement volume required =! 730 sxI Casing Design / Cement Calculations 3-Mar-95 Production tail: TMD Top of Target, TM D Want TOC 500' above top of target 5" casing tail top (100' above C sand) 5" Annulus area (9" Hole) 7" Annulus area (9" Hole) (5" Casing Top-TOC)*7" Annulus area + (5" to TD)* 5" Annulus area Length of cmt wanted in csg Internal csg volume Cmt required in casing Total cmt Excess factor Cement volume required Yield for Class G cmt Cement volume required = 12,949 ft = 12,549 ft = 12,049 ft :[ 12,949 ffJ = 0.3054 = O, 1745 = 157 cf = 80 ft = 0.2148 = 17cf = 174cf = 75% = 305 cf = 1.19 :1 260 TENSION - Minimum Desien Factors are: T(ob)=l.5 and T(is)=l.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Length Casing Wt (Ib/ft) Dead Wt in Air Buoyancy = Tension (Pipe Body) Design Factor 916000 lb 4,120 ft 40.00 Ib/ft 164800.0 lb 26938.9 lb 137861.1 lb 6,61 Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 979000 lb 4,120 ft 40.00 Ib/ft 164800.0 lb 26938.9 lb 137861.1 lb 7.1] Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 604000 lb 12,949 ft 26.00 Ib/ft 336674.0 lb 55804.2 lb 280869.8 lb 2.2! Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 667000 lb 12,949 ft 26.00 Ib/ft 336674.0 lb 55804.2 lb 280869.8 lb Casing Design / Cement Calculations BURST- Minimum Desian Factor = 1.1 -- Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =1 Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres (3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE. Minimum Desian Factor = 1,o Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' 'I'VD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000q'VD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =l Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 3-Mar-95 5750 psi 1693.7 psi 3.41 7240 psi 6997 psi 2832 psi 4165 psi 1.71 3090 psi 0.571 Ib/ft 699 psi 4.41 5410 psi 0.571 Ib/ft 3497 psi 1.51 Casing Design / Cement Calculations 3-Mar-95 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb Collapse Burst 4750 psi 6870 psi 3090 psi 5750 psi 2020 psi 3520 psi 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb I 5.000 4.276 18 L-80 5.2746 sq. in. 376000 lb 422000 lb 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb Collapse Burst 5410 psi 7240 psi 10490 psi 10140 psi 4320 psi 4980 psi KUPARUK RIVER UNI, 20" DIVERTER SCHEMATIC 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) RECEIVED MAR 1 3 1995 ~da~sJ~ Pit & Gas Cons. Commission ---, ~mchora, .- 1. 16" CONDUCTOR. 2. SLIP~3N WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOL WITH 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/~ 7 5 4 I 13 5/8" 5000BOP STACK /¥~CUM ULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR 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 AFl'ER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 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. ~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. ~ 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, ENES, AND CHOKES WiTH A 250 PSI LOW AND 3(X)0 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING PosmvE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO]rOM PIPE RAMS. TEST BO]rOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BUND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND MNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRIMJNG PosmoN. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY ~S AND INSIDE BOP TO 30(X) 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. 1. 16" - 2000 PSI STARTING HEAD 2. 11 "- 3(XX) PSI CASING HEAD 3. 11"- 30(X) PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"-5000 PSI PIPE RAMS 5. 13-5/8"-5000 PSI DRLG SPOOLW/ CHOKE AND KILL UNES ~ 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BUND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR WELL PERKrlIT CHECKLIST ADM I N I S T~.T I ON ENGINEERING APPR DATE 1. Permit fee attached ................... 2. Lease number appropriate ................ 3. Unique well name and number ............... 4. Well located in a defined pool ............. 5. Well located proper distance from 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 14. 15. 16 17 18 19 2O 21 22 23. 24. 25. 26. 27. 28. 29. Conductor string provided ............... Surface casing protects all known USDWs ........ CMT vol adequate to circulate on conductor & surf csg. CMT vol adequate to tie-in long string to surf csg . . CMT will cover all known productive horizons ...... Casing designs adequate for C, T, B & permafrost .... Adequate tankage or reserve DJ% ............. If a re-drill, has a 10-403 abndnmn% been approved~~ Adequate wellbore separation proposed .......... If diverter required, is it adequate .......... Drilling fluid program schematic & equip list adequate BOPEs adequate ..................... ~ BOPE press rating adequate; test to ~ psig.(~ N Choke manifold complies w/API RP-53 (May 84) ....... ~ ~F~ Work will occur without operation shutdown ....... ~ N /~ ~ ~ Is presence of E2S gas probable ............ ~ N ~~,(~[~ ~ ~ ~ ~"~ ' GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 5~ 31. Da%a presented on potential overpressure zones ..... Y J 32. Seismic analysis of shallow oas zones .......... X N 33. Seabed condition survey (if off-shore) ........ /Y N 34. [exploratory only] ~ Contact name/phone for weekly orogress reports . . . / . Y N GEOLO).~Y: ENGINEERING: COMMISSION : Comments/Instructions: c) '-~C~RMS~.cheklist rev 03~94 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. c!ds" t C(r -~3;L- Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe 1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. August 10, 2005 7517 1 3.5" 9.3 lb. L-80 EUE 8RD Tubing Well: Field: State: API No.: Top Log IntvI1.: Bot. Log IntvI1.: 2T -23 Kuparuk Alaska 50-1 03-20216-(}t u 0 12,350 Ft. (MD) 12,400 Ft. (MD) Inspection Type: Polished Bore Receptacle Deployment Inspection COMMENTS: This log is tied into the end of the top of the packer @ 12,398' (Driller's Depth). This log was run to assess the successful deployment of the polished bore receptacle into the packer. A 3-D log plot of the caliper recordings across the polished bore receptacle, seal anchor and packer is included in this report. The caliper recordings indicate no intervals of 7" casing in the interval logged. No significant wall penetrations, areas of cross-sectional wall loss or 1.0. restrictions are recorded. " ..' ...... . ,~~.-. ,"~ q·:..i.. '2 q n't: .,....., r,.~,)/I'\~\:,,_I~ I"~ C t) (, d ~..L.-,.I ~)\"d~~t.\> IJ'...~~' ,J L ~ ,. I Field Engineer: L. Mills-Dawson Analyst: M. Lawrence Witness: T. Senden ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 56.5-9085 Fax: (281) 565·-1369 E-mail: PDS@rnernorylog.com Prudhoe Bay Field Office Phone: (907) 659~2J07 Fax: (907) 659-2314 Comm,:.nto; ;: ?500 MIN In (111000 in.) 450 ?!\OO MAX In (111000 in.) 450" 75 ?500 Nnmin"ltn. 4500 Q Description: Last Full Joint of Tubing I Pup Joint 'I I 'I Polished ,I Bore Receptacle , I I II l~ Pup Joint Anchor II Seal Packer I PDS MultißJlger Caliper 3D Log Plo¡ Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Well: 2T-23 Date: August 10, 2005 Detail of Caliper Recordings Across Polished Bore Receptacle and Packer 12355 ~ -- --- --..\ --. ----- ---- --- ---------.-.l.---- -------------.-------- - -- ---_._---~-------- --- ---- --- --- -- --- ~, , . -..---- -- ---.- ',~--' --.------ ------- ----- ---- -------- --- --- --. -- -~.)-,--- ---- ---- -- -- ---- ..._- -- -- --.---_. -- ..- -- --.- ..---- -... ..,.--. -_.- -~ "" -'--- .-- ..-- -._..~ ---- -~'- .-- -....- 12360 I ----- -- -' -; f ----- -".- -,.-- --- -- -_.~ -.-.- -- ~'--"---"~- ~._- ----.-- ____.____ ....__ ___ .jl..1__ I - ..- .--. ----..--,-- -. .--- ,.-- ~~ -----~-------------- ~ 12365 ~( ----iL-------------- - ---- -- -.-..-- -, -- (' ,( -----..- -- -~~----- --------- 12370 ===-}~==___---==== ~ -- -.-.. ---- -..-., ~.- -"- ...- -.---.,,- -'-'''-.-.- --- -.---- -- ---.. --_.---- ~; 12375 ' ----"'" -- '-..-- -- .-. -~-_._- .-., -- ,_..- ----.---- -,.._- -."-'--'-- -..- -- ,.-.. --~._.- -.-... --- ._~._~- ___h. ~.......---- -- -- --- .-- -.---'-'- -.-- ---_.._~~ - ,-- -. ,-.---- 12380 I --- - - ~ r---- -- -- ---- " ~._------------- ... ----~--------------- - -... .-- --- _.".~ '.--.- ._- ...- .--~ ~-, .....~- -- .~._.. ...--.. ~--. .__..~ -".- -- ~- .-.-. 12385 , -- _._.~- ~ ~----~- -~..","--"'- ---_._~ ~_.._--- ~ -r;' -..... .-.~- .--- ,._-~- .- ,,-,~ .-- -- '.--- -.- 12390 ~ _ ~1 ~u_ ._____ .___._______ ...~ ~~ 12395 \ / ------šf--------- ,&'1 ...--- -,--- ,,( ~. 4 . , (.~ - ------- ------ --- 12400 \ 1 ~ ALASKA COMPUTING CENTER SCHLUMBERGER COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 2T-23 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-103-20216-0~ REFERENCE NO : 95162 LIS Tape Veri..~ication Listing Schlumberger Alaska Computing Center 3-0CT-~995 ~6:02 **** REEL HEADER SERVICE NAME : EDIT DATE : 93/10/ 3 ORIGIN : FLIC REEL NAME : 93162 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC., KUPARUK 2T-23, API #30-103-20216-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 95/le/ 3 ORIGIN : FLIC TAPE NAME : 93162 ~ CONTINUATION # : ~ .... ' PREVIOUS TAPE : COMMENT : ARCO ALASKA, INC., KUPARUK 2T-23, API #30-~03-20216-00 TAPE HEADER KUPARUK RIVER MWD/MAD LOGS WELL NAME: 2T-23 API NUMBER: 30103202~600 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 27-SEP-95 JOB DATA BIT RUN 1 BlT RUN 2 BIT RUN 3 JOB NUMBER: 95162 95162 LOGGING ENGINEER: KADRMAS KADRMAS OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: liN RANGE: 8E FNL: ESL: 432 FEL: FWL: 556 ELEVATION(FT FROM MSL 0) KEllY BUSHING: 122.00 DERRICK FLOOR: 122.00 GROUND LEVEL: 80.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS BlT SIZE (IN) SIZE (IN) DEPTH (FT) 93162 KADRMAS 1ST STRING $.500 9.625 4151.0 2ND STRING PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-0CT-1995 16:02 3RD STRING PRODUCTION STRING REMARKS: Well drilled 2T-MAR through 06-APR-95 with CDR only. Data was collected in three bit runs. There was continuous MWD data to TD, with a short section of MAD data. $ $ *,,~ FILE HEADER -**= FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 0~C01 DATE : 95/10/ 3 MAX REC SIZE : ~024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: EDITED MERGED MWD Clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 4iSi.e 12951.~ $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH. BASELINE DEPTH MWD $ MERGED DATA SOURCE LDWG TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE MWD 1 4iSl.e 5438.0 MWD 2 5438.~ i2329.0 MWD 3 12329.~ 12977.0 $ REMARKS: There were no depth corrections made at the request of ARCO. This file also contains the Very Enhanced QRO resisitivit¥ with 2' average that was processed at GeoQuest. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-0CT-~995 16:~2 PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB *~ TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 5 66 6 73 7 65 8 68 ~.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 SET TYPE - CHAN ~* NAME SERV UNIT SERVICE API API APl API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 619188 00 ~00 00 0 1 1 1 4 68 0000000~00 RA MWD OHMM 619188 00 00~ 00 0 1 I 1 4 68 0000000000 RP MWD OHMM 619188 00 00~ 0~ 0 I 1 I 4 68 0~00~00000 VRA MWD OHMM 619188 00 ~0~ ~0 0 1 I 1 4 68 0~00000~00 VRP MWD OHMM 619188 ~0 ~00 ~0 0 1 1 1 4 68 0000000000 DER MWD OHMM 619188 00 ~0~ ~0 ~ I I 1 4 68 ~0000~000 ROP MWD FPHR 619188 00 00~ ~0 0 1 I 1 4 68 0~00000000 GR MWD GAPI 619188 00 00~ ~0 ~ 1 1 1 4 68 00~0000000 FET MWD HR 619188 00 0~ 00 ~ 1 1 1 4 68 0~00000000 DATA DEPT. 12976.0~0 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 22.496 GR.MWD FET.MWD -999.250 DEPT. 4124.5~0 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD -999.250 GR.MWD FET.MWD -999.250 -999.250 -999.250 -999.250 45.598 LIS Tape Veri~;catien Listing Schlumberger Alaska Computing Center 3-0CT-1995 16:02 PAGE: END OF DATA **** FILE TRAILER **=* FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/10/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : *~** FILE HEADER FILE NAME : EDIT .~02 SERVICE : FLIC VERSION : 001C01 DATE : 95/10/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MAD $ MERGED DATA SOURCE LDWG TOOL CODE 12212.0 12329.0 MAD RUN NO. MAD Pass NO. MERGE TOP MERGE BASE $ REMARKS: This file contains the MAD data obtained on bit run #3. No depth corrections were made at the request of ARCO. $ LIS FORMAT DATA LIS Tape Verificatien Listing Schlumberger Alaska Computing Center 3-0CT-1995 16:02 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 S 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN ** PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 619188 00 000 00 0 2 1 1 4 RA MAD OHMM 619188 ~ 000 00 0 2 1 1 4 RP MAD OHMM 619188 00 000 00 0 2 1 I 4 DER MAD OHMM 619188 0~ 0~0 0~ 0 2 1 1 4 ROP MAD FPHR 619188 0~ 000 00 0 2 1 1 4 GR MAD GAPI 619188 00 000 00 0 2 1 1 4 FET MAD HR 619188 00 0~0 00 0 2 1 1 4 ** DATA ** DEPT. 12329.000 RA.MAD 2.209 RP.MAD ROP.MAD 59.340 GR.MAD 93.657 FET.MAD DEPT. 12179.500 RA.MAD -999.250 RP.MAD ROP.MAD -999.250 GR.MAD 122.719 FET.MAD 2.36~ DER.MAD 2.431 -999.250 DER.MAD -999.250 2.298 -999.250 END OF DATA LIS Tape Veri,ficatipn Listing Schlumberger Alaska Computing Center 3-0¢T-1995 16:02 PAGE: ***, FILE TRAILER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001601 DATE : 95/10/ MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER SERVICE NAME : EDIT DATE : 95/1¢/ 3 ORIGIN : FLIC TAPE NAME : 95162 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, INC., KUPARUK 2T-23, AP1 **** REEL TRAILER SERVICE NAME : EDIT DATE : 9511¢/ 3 ORIGIN : FLIC REEL NAME .: 95162 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC., KUPARUK 2T-23, API