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Home My WebLink About187-025Originated: Delivered to:19-May-24 Alaska Oil & Gas Conservation Commiss 19May24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER # FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 1A-03 50-029-206150-00-00 181-088 Kuparuk River WL Plug FINAL FIELD 3-Feb-24 3S-22 50-10320446-00-00 203-011 Kuparuk River WL IBC-CBL FINAL FIELD 5-Feb-24 3M-05 50-103-20875-00-00 223-126 Kuparuk River WL Isealate FINAL FIELD 10-Feb-24 2F-15 50-029-21048-00-00 183-172 Kuparuk River WL Isealate FINAL FIELD 13-Feb-24 MT7-14A 50-103-20856-01-00 223-064 Greater Mooses Tooth WL PPROF FINAL FIELD 20-Feb-24 MT7-03A 50-103-20830-00-10 223-084 Greater Mooses Tooth WL PPROF FINAL FIELD 29-Feb-24 3G-27 50-103-20801-00-00 219-039 Kuparuk River WL TTiX IPROF FINAL FIELD 2-Apr-24 2W-17 50-029-23370-00-00 207-135 Kuparuk River WL PPROF FINAL FIELD 9-Apr-24 1E-23 50-029-20858-00-00 182-184 Kuparuk River WL IPROF FINAL FIELD 10-Apr-24 1E-01 50-029-20464-00-00 180-039 Kuparuk River WL IPROF FINAL FIELD 11-Apr-24 1D-37 50-029-22992-00-00 200-204 Kuparuk River WL PPROF FINAL FIELD 12-Apr-24 3G-09 50-103-20129-00-00 190-067 Kuparuk River WL Punch-Cut FINAL FIELD 13-Apr-24 2P-420 50-103-20391-00-00 201-182 Kuparuk River WL CIBP-Cut FINAL FIELD 15-Apr-24 CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX Sampling FINAL FIELD 18-Apr-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private Eset # T38800 T38801 T38802 T38803 T38816 T38817 T38818 T38819 T38820 T38821 T38822 T38824 T38823 T38825 3M-05 50-103-20875-00-00 223-126 Kuparuk River WL Isealate FINAL FIELD 10-Feb-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.20 12:41:13 -08'00' PTD: 187-025 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: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9110'feet None feet true vertical 6462'feet 8685', 8690', 8801', 8807' feet Effective Depth measured 8635'feet 8504', 8626'feet true vertical 6147' feet 6060', 6142' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 8761' MD 6231' TVD Packers and SSSV (type, measured and true vertical depth) 8504' MD 8626' MD N/A 6060' TVD 6142' 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: 4351' 3419' Burst Collapse Production Liner 2683' 6223' Casing 2334' 6356' 2725' 8948' 4314' 115'Conductor Surface TieBack Patch 16" 9-5/8" 77' measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 187-025 50-029-21706-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025521, ADL0025523 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3M-05 Plugs Junk measured Length 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) ~ Gas-Mcf MD ~ Size 115' ~~~ Well Remains Shut-In ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: BluePack Max RH S#C21P-1214 Packer Packer: NSAK Mono-Pak LTP SSSV: None Jan Byrne jan.byrne@conocophillips.com (907) 265-6471Staff Well Intergrity Specialist 8666-8720', 8728-8731', 8736-8739' 6168-6204', 6209-6211', 6215-6217' 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 9:28 am, Mar 13, 2024 Digitally signed by Jan Byrne DN: OU=Wells, O=ConocoPhillips, CN=Jan Byrne, E= jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2024.03.13 08:59:47-08'00' Foxit PDF Editor Version: 13.0.0 Jan Byrne DSR-3/14/24 RBDMS JSB 031424 DTTMSTART JOBTYP SUMMARYOPS 2/8/2024 REPAIR WELL COMPLETE WEEKLY BOP TEST. MU MOTOR AND 2.79" 5 BLADE JUNK MILL. RIH AND PUMP 90 BBL DOWN IA FOR FREEZE PROTECT. DRIFT CLEAN TO LINER TOP AT 8,626' RKB. MAKE 3 PASSES WASHING TUBING FROM 8,626' TO 4,900'. PUMP GEL PILL AND CHASE RETURNS TO SURFACE. MAINTAIN 1:1 RETURNS THROUGHOUT. LAY IN DIESEL FREEZE PROTECT FROM 2,500' WHILE POOH. 2/9/2024 REPAIR WELL CLEAN DRIFT W/ DUMMY PATCH 2.70" x 27.5', MAX TEMP & PRESSURE @ 4907' RKB 91* / 3437 PSI. READY FOR E-LINE. 2/9/2024 REPAIR WELL PREPARE, RIGUP WELLTEC BRUSH TO CLEAN OVER PATCH DEPTH JOB CONTINUE 2/10/2024 REPAIR WELL PERFORM WELLTEC WISHBONE HONER BRUSH RUN FROM 4900' TO 4925' (THREE PASSES) SET ISEALATE PATCH AT 4907' (TOP OF PATCH AT ~4902', BOTTOM OF PATCH AT ~4912'), CCL TO CENTER OF PATCH = 40', CCL STOP DEPTH = 4867' STANDBY IN HOLE PER ISEALATE FIELD REP FOR PATCH SETTING PROCESS JOB IN PROGRESS 2/11/2024 REPAIR WELL STANDBY FOR PATCH RESIN TO CURE FOR 28 HOURS WELLTEC DEFLATE SETTING TOOL, POOH JOB IN PROGRESS 2/12/2024 REPAIR WELL PATCH SETTING COMPLETED, RIG DOWN, PACK EQUIPMENT AND LEAVE PAD JOB COMPLETE, READY FOR RELAY TO PERFORM CALIPER AND SET RBP, PENDING CALIPER RESULTS (DO NOT APPLY ANY DIFFERENTIAL PRESSURE TO PATCH UNTIL AFTER 2/13/24 AT 0800) 2/12/2024 REPAIR WELL DRIFTED TUBING W/ 2'' x10' DRIFT TO 1.78'' LTP 8626' RKB.....IN PROGRESS 2/13/2024 REPAIR WELL LOGGED TUBING W/ 1.69'' 24 ARM HALLIBURTON CALIPER FROM 8616' RKB TO SURFACE, CONFIRMED GOOD DATA. JOB IN PROGRESS. 2/16/2024 REPAIR WELL SET 2.60" ME RBP MID ELEMENT @ 8610' RKB, OBTAINED PASSING 2500 PSI MIT-T......IN PROGRESS 2/17/2024 REPAIR WELL PULLED 2.60" ME P2P RBP @ 8610' RKB....JOB COMPLETE 2/24/2024 PUMPING TRACKING ONLY METH SPEAR DOWN BACKSIDE. PUMPED 10 BBLS METH DOWN IA 2/25/2024 PUMPING TRACKING ONLY FREEZE PROTECT TUBING AND FLOWLINE, PUMPED 17 BBLS METH DOWN TUBING AND 8 BBLS METH DOWNFLOWLINE 3M-05 Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,635.0 3M-05 5/29/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Isealate Patch 3M-05 2/10/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: IA x OA COMMUNICATION 7/15/2009 hipshkf 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 1615.06 38.0 115.0115.0 62.50H-40 WELDED SURFACE 9 5/8 8.92 37.0 4,351.4 3,419.3 36.00 J-55 BTC 7" Tie-Back Patch 7 6.28 42.2 2,725.0 2,333.8 26.00 L-80 Hyd 563 PRODUCTION ORIGINAL 7 6.28 2,725.0 8,948.2 6,355.9 26.00 J-55 BTC L1-03 Liner 2 3/8 1.99 8,637.3 11,717.0 4.60 L-80 STL L1-01 Liner 2 3/8 1.99 8,738.7 10,987.0 4.60 L-80 STL L1 Liner 2 3/8 1.99 9,306.9 10,975.0 4.60 L-80 STL L1-02 Liner 2 3/8 1.99 9,598.7 11,717.0 4.60 L-80 STL Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.0 Set Depth … 8,760.8 Set Depth … 6,231.1 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L80 Top Connection EUE 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) 33.0 33.0 0.03 Hanger 4.500 FMC 3-1/2"" Tubing Hanger FMC TC-1A 3.910 474.9 474.9 0.29 Nipple - X 3.770 2.813" X-Nipple S#4378911-07 HES X 2.813 2,942.3 2,492.7 43.17 Mandrel – GAS LIFT 5.679 3-1/2" x 1-1/2" MMG SLB MMG 2.926 4,888.2 3,754.9 50.87 Mandrel – GAS LIFT 5.679 3-1/2" x 1-1/2" MMG SLB MMG 2.926 6,190.7 4,598.3 49.20 Mandrel – GAS LIFT 5.679 3-1/2" x 1-1/2" MMG SLB MMG 2.926 7,176.2 5,214.1 51.94 Mandrel – GAS LIFT 5.679 3-1/2" x 1-1/2" MMG SLB MMG 2.926 7,887.1 5,661.0 50.41 Mandrel – GAS LIFT 5.679 3-1/2" x 1-1/2" MMG SLB MMG 2.926 8,437.0 6,016.3 48.98 Mandrel – GAS LIFT 5.679 3-1/2" x 1-1/2" MMG SLB MMG 2.926 8,503.6 6,060.1 48.81 Packer 6.276 3-1/2" x 7" Cut-to-Release. BluePack Max RH S#C21P-1214 SLB Bluepac k max 2.885 8,615.6 6,134.4 48.21 Nipple - X 3.770 2.813" X-Nipple S#4378911-11 HES X 2.813 8,663.0 6,166.0 48.23 Wedge Assembly 5.905 3.5" x 7" Wedge Assembly #2 Northern solutions 2.992 8,677.0 6,175.3 48.24 Nipple - X 4.500 2.813" X-Nipple Northern Solution s X2.813 8,682.8 6,179.2 48.24 Wedge Assembly 5.905 3.5" x 7" Wedge Assembly #1 Northern solutions 2.992 8,696.8 6,188.5 48.25 Nipple - X 4.500 2.813" X-Nipple Northern Solution s X2.813 8,739.0 6,216.6 48.25 Sleeve - Frac 4.490 Ball Seat. 2.755" ID. 2.795" BALL "BUBBLETIGHT" Baker Huges 2.770 8,760.3 6,230.8 48.25 Wireline Guide 4.500 3.5" WLEG Halliburt on 3.012 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) 4,902.0 3,763.6 50.83 SPACER PIPE ISEALATE PATCH OAL 10', THEORETICAL MIN ID 2.68" (CONFIRMED WITH CALIPER LOG) ISEALAT E N/A N/A 2/10/2024 2.680 4,907.0 3,766.7 50.81 LEAK TBG LEAK IDENTIFIED BY EL AT 4907' RKB 10/24/2022 2.992 8,626.4 6,141.6 48.21 PACKER Set NSAK Mono-Pak LTP. Set into liner top @ 8637' RKB. (Drawing of LTP in attachments) A2242 7201 2/17/2022 1.780 8,646.0 6,154.7 48.22 WHIPSTOCK TOWS set at 8646', HS BOT 1/28/2022 0.100 8,666.0 6,168.0 48.23 WHIPSTOCK WS set on X-Lock @ 8677 Northern Solutions 1/23/2022 0.100 8,677.0 6,175.3 48.24 CHOKE 2.813" X-LOCK W/ FLOW THRU SUB (1.75" ID / 18" OAL) 1/23/2022 1.780 8,685.0 6,180.6 48.25 WHIPSTOCK Set on X-Lock TOWS 8685' 1/22/2022 0.000 8,685.0 6,180.6 48.25 FISH 2.80 Diamond Speed Mill sitting on whipstock tray @ 8685' 1/22/2022 1.000 3M-05, 3/12/2024 2:17:26 PM Vertical schematic (actual) L1-02 Liner; 9,598.7-11,717.0 L1-03 Liner; 8,637.3-11,717.0 L1-01 Liner; 8,738.7-10,987.0 L1 Liner; 9,306.9-10,975.0 PRODUCTION ORIGINAL; 2,725.0-8,948.2 FISH; 8,807.0 FISH; 8,801.0 Sleeve - Frac; 8,739.0 IPERF; 8,736.0-8,739.0 IPERF; 8,728.0-8,731.0 IPERF; 8,686.0-8,718.0 IPERF; 8,682.0-8,720.0 CHOKE; 8,697.0 Nipple - X; 8,696.8 WHIPSTOCK; 8,685.0 OBSTRUCTION; 8,690.0 FISH; 8,685.0 CHOKE; 8,677.0 Nipple - X; 8,677.0 RPERF; 8,666.0-8,682.0 IPERF; 8,672.0-8,676.0 WHIPSTOCK; 8,666.0 WHIPSTOCK; 8,646.0 OTHER; 8,637.0 PACKER; 8,626.4 Nipple - X; 8,615.6 Packer; 8,503.6 Mandrel – GAS LIFT; 8,436.9 Mandrel – GAS LIFT; 7,887.1 Mandrel – GAS LIFT; 7,176.2 Mandrel – GAS LIFT; 6,190.7 LEAK; 4,907.0 SPACER PIPE; 4,902.0 Mandrel – GAS LIFT; 4,888.2 SURFACE; 37.0-4,351.4 Mandrel – GAS LIFT; 2,942.3 7" Tie-Back Patch; 42.2-2,725.0 Production String 1 Cement; 34.0 ftKB Nipple - X; 474.9 CONDUCTOR; 38.0-115.0 Hanger; 33.0 KUP PROD KB-Grd (ft) 39.61 RR Date 3/24/1987 Other Elev… Elevation Hi t 3M-05 ... TD Act Btm (ftKB) 9,110.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292170600 Wellbore Status PROD Max Angle & MD Incl (°) 52.78 MD (ftKB) 7,100.00 WELLNAME WELLBORE3M-05 Annotation Last WO: End Date 1/12/2022 H2S (ppm) 240 Date 12/10/2015 Comment SSSV: TRDP Originated: Delivered to:1ͲMarͲ24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & PerforatingAttn.:Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska99501 Anchorage, Alaska 99518 Office: 907Ͳ275Ͳ2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 13KͲ27 50Ͳ029Ͳ22751Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 15ͲJanͲ24 0 1 23MͲ05 50Ͳ029Ͳ21706Ͳ00 n/a Kuparuk River Multi Finger Caliper Field & Processed 13ͲFebͲ24 0 1 33MͲ05 50Ͳ029Ͳ21706Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 16ͲFebͲ24 0 1 43MͲ05 50Ͳ029Ͳ21706Ͳ00 n/a Kuparuk River SBHP Record FieldͲFinal 9ͲFebͲ24 0 1 5 6 7 8 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T38573 T38573 T38573 187-025 T38573 197-046 T38574 T38754 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 14:47:55 -09'00' 187-025 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 3G-10 50-103-20134-00 190084_3G-10_IPROF_08Jan2023 3G-13 50-103-20137-00 190116_3G-13_Puncher_03Oct2022 3G-20 50-103-20141-00 190123_3G-20_IPROF_28Apr2022 3H-35 50-103-20805-00 219064_3H-35_IPROF_03Aug2023 3I-11A 50-029-21932-01 210074_3I-11A_SBHPS-PLUG_25Jul2023 3M-05 50-029-21706-00 187025_3M-05_TBG_09Jan2022 3O-04 50-029-21826-00 188062_3O-04_CBL Post BiSN_24Aug2023 188062_3O-04_LDL_04Jan2022 3O-06 50-029-21824-00 188060_3O-06_CBL Pre-BiSN_24Aug23 3R-18 50-029-22249-00 192017_3R-18_LDL_21Feb2022 192017_3R-18_PressTemp_22Mar2022 3S-03 50-103-20458-00 203091_3S-03_IBC-CBL_04Sep2023 203091_3S-03_MechCut_14Jul2023 9of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38395 T38396 T38397 T38398 T38399 T38400 T38401 T38402 T38403 T38404 2/29/2024 3M-05 50-029-21706-00 187025_3M-05_TBG_09Jan2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:12:37 -09'00' Originated: Delivered to:8-Apr-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1C-15 50-029-22932-00 907743115 Kuparuk River Multi Finger Caliper Field & Processed 16-Mar-22 0 12 1E-31 50-029-22791-00 907676477 Kuparuk River Packer Setting Record Field- Final 14-Feb-22 0 13 1L-29 50-029-22157-00 907706865 Kuparuk River Plug Setting Record Field- Final 25-Feb-22 0 14 1L-29 50-029-22157-00 n/a Kuparuk River Jet Cut Record Field- Final 14-Nov-21 0 15 2W-09 50-029-21235-00 907723402 Kuparuk River Multi Finger Caliper Field & Processed 1-Mar-22 0 16 2W-09 50-029-21235-00 n/a Kuparuk River Multi Finger Caliper Field & Processed 24-Jan-22 0 17 3B-02 50-029-21319-00 907705186 Kuparuk River Injection Profile Field- Final 23-Feb-22 0 18 3M-05 50-029-21706-00 n/a Kuparuk River Multi Finger Caliper Field & Processed 23-Jan-22 0 19 3Q-04 50-029-22219-00 n/a Kuparuk River Plug Setting Record Field- Final 20-Feb-22 0 110PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:187-205T3646183M-0550-029-21706-00Meredith GuhlDigitally signed by Meredith Guhl Date: 2022.04.08 10:37:36 -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: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9110'feet None feet true vertical 6462'feet 8685', 8801', 8807'feet Effective Depth measured 8354'feet 4900', 4914', 8504', 8626' feet true vertical 5962'feet 3762', 3771', 6060', 6142' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 8761' MD 6231' TVD Packers and SSSV (type, measured and true vertical depth) 4900' MD 4914' MD 8504' MD 8626' MD N/A 3762' TVD 3771' TVD 6060' TVD 6142' 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: 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: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: BluePack Max RH Packer Packer: NSAK Mono-Pak LT Packer SSSV: None Jan Byrne jan.byrne@conocophillips.com (907) 659-7224Senior Well Integrity Specialist 8666-8720', 8728-8731', 8736-8739' feet 6168-6204', 6209-6211', 6215-6217' feet 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) 262 Gas-Mcf MD 150 Size 115' 1640 951110 0 1400 159 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 187-025 50-029-21706-00-00 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: ADL0025521, ADL0025523 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3M-05 Plugs Junk measured Length Production Liner 6233' Casing 8948'2725' 4314' 115'Conductor Surface Intermediate 16" 9-5/8" 77' 4351' 3419' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 4:23 pm, Dec 20, 2022 Digitally signed by Jan Byrne DN: CN=Jan Byrne, E=jan.byrne@ conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2022.12.20 14:03:20-09'00' Foxit PDF Editor Version: 12.0.1 Jan Byrne DTTMSTART JOBTYP SUMMARYOPS 10/24/2022 REPAIR WELL RUN 1: PERFORM LEAK DETECTION LOG FROM TOP OF PLUG AT 8615 RKB TO SURFACE, PUMPING AT 0.75 BPM DOWN TBG TAKING RETURNS UP IA (600 PSI TUBING AND 250 PSI IA). IDENTIFY LEAK IN TBG COLLAR AT 4907' RKB. PERFORM UP/DOWN PASS AND STATION SURVEYS OVER LEAK AREA. RUN 2: PERFORM 24-ARM CALIPER LOG FROM 8600' RKB TO SURFACE. JOB COMPLETE, READY FOR PLAN FORWARD. 11/16/2022 REPAIR WELL SET 3 1/2" CATCHER ON 2.813" XX PLUG @ 8615' RKB & PULLED OV @ 6190' RKB. READY FOR CIRC OUT. 11/17/2022 REPAIR WELL CIRC OUT PUMPED 147 BBLS CRW-132 SW FOLLOWED BY 70 BBLS DSL DWN TBG, U-TUBED FOR FREEZE PROTECT PERFORMED CMIT T X IA @ 2500 PSI - PASSED SEE BELOW FOR DETAILS BLED PRESSURE DWN ON TBG & IA 11/19/2022 REPAIR WELL SET DV @ 6192' RKB; PULLED GLV & SET OV @ 4888' RKB; PULLED CATCHER & 2.813" XX PLUG @ 8615' RKB; BRUSH n' FLUSH PATCH INTERVAL FROM 4902'-4916' RKB; DRIFT W/ 2.74" X 15' DMY PATCH DOWN TO 5000' RKB. READY FOR PATCH. 11/20/2022 REPAIR WELL SET QUADCO 3.5" PIIP LOWER PACKER MID-ELEMENT AT 4916.0' RKB, CCL TO ME - 10.2', CCL STOP DEPTH = 4905.8'. JOB COMPLETE, READY FOR SL TO SET UPPER PATCH PACKER ASSEMBLY 11/20/2022 REPAIR WELL RAN 3 1/2" TTS TEST TOOL TO LOWER P2P @ 4916' RKB & CMIT TBG X IA TO 2500 PSI (PASS). IN PROGRESS. 11/21/2022 REPAIR WELL SET UPPER 2.72" P2P (CPP35103), SPACER PIPE, & ANCHOR LATCH (CPAL35192) @ 4899.5' RKB (MID ELEMENT @ 4901.9' RKB); RAN TTS 3 1/2" TTS TEST TOOL TO UPPER P2P & MITT TO 2500 (PASS) CMIT TBG X IA TO 2500 PSI (PASS). JOB COMPLETE. 3M-05 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Tagged Scale/Fill in Tbg above Prod Pkr) 8,354.0 3M-05 8/23/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Upper Section of Patch 3M-05 11/21/2022 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: IA x OA COMMUNICATION 7/15/2009 hipshkf General Notes: Last 3 entries Com Date Last Mod By XX-Plug In X-Nipple at 8,615' 1/11/2022 NSKRWOCM 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 38.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 37.0 4,351.4 3,419.3 36.00 J-55 BTC 7" Tie-Back Patch 7 6.28 42.2 2,725.0 2,333.8 26.00 L-80 Hyd 563 PRODUCTION ORIGINAL 7 6.28 2,725.0 8,948.2 6,355.9 26.00 J-55 BTC L1-03 Liner 2 3/8 1.99 8,637.3 11,717.0 4.60 L-80 STL L1-01 Liner 2 3/8 1.99 8,738.7 10,987.0 4.60 L-80 STL L1 Liner 2 3/8 1.99 9,306.9 10,975.0 4.60 L-80 STL L1-02 Liner 2 3/8 1.99 9,598.7 11,717.0 4.60 L-80 STL Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 33.0 Set Depth 8,760.8 Set Depth 6,231.1 String Ma 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L80 Top Connection EUE 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) 33.0 33.0 0.03 Hanger 4.500 FMC 3-1/2"" Tubing Hanger FMC TC-1A 3.910 474.9 474.9 0.29 Nipple - X 3.770 2.813" X-Nipple S#4378911-07 HES X 2.813 2,942.3 2,492.7 43.17 Mandrel GAS LIFT 5.679 3-1/2" x 1-1/2" MMG S#038AJ07 W/1.5"GLV TRO=1260 PSI SLB MMG 2.926 4,888.2 3,754.9 50.87 Mandrel GAS LIFT 5.679 3-1/2" x 1-1/2" MMG S#022AJ07 W/1.5" GLV TRO=1255 PSI SLB MMG 2.926 6,190.7 4,598.3 49.20 Mandrel GAS LIFT 5.679 3-1/2" x 1-1/2" MMG S#025AJ07 SLB MMG 2.926 7,176.2 5,214.1 51.94 Mandrel GAS LIFT 5.679 3-1/2" x 1-1/2" MMG S#023AJ07 SLB MMG 2.926 7,887.1 5,661.0 50.41 Mandrel GAS LIFT 5.679 3-1/2" x 1-1/2" MMG S#024AJ07 SLB MMG 2.926 8,437.0 6,016.3 48.98 Mandrel GAS LIFT 5.679 3-1/2" x 1-1/2" MMG S#035AJ07 SLB MMG 2.926 8,503.6 6,060.1 48.81 Packer 6.276 3-1/2" x 7" Cut-to-Release. BluePack Max RH S#C21P-1214 SLB Bluepac k max 2.885 8,615.6 6,134.4 48.21 Nipple - X 3.770 2.813" X-Nipple S#4378911-11 HES "X" 2.813 8,663.0 6,166.0 48.23 Wedge Assembly 5.905 3.5" x 7" Wedge Assembly #2 Northern solutions 2.992 8,677.0 6,175.3 48.24 Nipple - X 4.500 2.813" X-Nipple Northern Solution s "X" 2.813 8,682.8 6,179.2 48.24 Wedge Assembly 5.905 3.5" x 7" Wedge Assembly #1 Northern solutions 2.992 8,696.8 6,188.5 48.25 Nipple - X 4.500 2.813" X-Nipple Northern Solution s "X" 2.813 8,739.0 6,216.6 48.25 Sleeve - Frac 4.490 Ball Seat. 2.755" ID. 2.795" BALL "BUBBLETIGHT" Baker Huges 2.770 8,760.3 6,230.8 48.25 Wireline Guide 4.500 3.5" WLEG Halliburt on 3.012 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) 4,900.0 3,762.3 50.83 PACKER - PATCH - UPR 2.725" P2P, SPACER PIPE, & ANCHOR LATCH (14.8' OAL) TTS P2P CPP3 5103 11/21/2022 1.625 4,904.0 3,764.8 50.82 ANCHOR LATCH ON SPACER PIPE SPACER PIPE & ANCHOR LATCH CONNECTED TO UPPER P2P CPAL 35192 11/21/2022 1.600 4,907.0 3,766.7 50.81 LEAK TBG LEAK IDENTIFIED BY EL AT 4907' RKB 10/24/2022 2.992 4,913.6 3,770.9 50.79 PACKER - PATCH - LWR 3-1/2" PIIP LWR PATCH PKR MID-ELEMENT AT 4916' RKB, OAL 4.01' TTS PIIP CPP3 5338 11/20/2022 1.625 8,626.4 6,141.6 48.21 PACKER Set NSAK Mono-Pak LTP. Set into liner top @ 8637' RKB. (Drawing of LTP in attachments) A2242 7201 2/17/2022 1.780 8,646.0 6,154.7 48.22 WHIPSTOCK TOWS set at 8646', HS BOT 1/28/2022 0.100 8,666.0 6,168.0 48.23 WHIPSTOCK WS set on X-Lock @ 8677 Northern Solutions 1/23/2022 0.100 3M-05, 12/19/2022 3:15:15 PM Vertical schematic (actual) L1-02 Liner; 9,598.7-11,717.0 L1-03 Liner; 8,637.3-11,717.0 L1-01 Liner; 8,738.7-10,987.0 L1 Liner; 9,306.9-10,975.0 PRODUCTION ORIGINAL; 2,725.0-8,948.2 FISH; 8,807.0 FISH; 8,801.0 Sleeve - Frac; 8,739.0 IPERF; 8,736.0-8,739.0 IPERF; 8,728.0-8,731.0 IPERF; 8,686.0-8,718.0 IPERF; 8,682.0-8,720.0 CHOKE; 8,697.0 Nipple - X; 8,696.8 WHIPSTOCK; 8,685.0 OBSTRUCTION; 8,690.0 FISH; 8,685.0 CHOKE; 8,677.0 Nipple - X; 8,677.0 IPERF; 8,672.0-8,676.0 RPERF; 8,666.0-8,682.0 WHIPSTOCK; 8,666.0 WHIPSTOCK; 8,646.0 OTHER; 8,637.0 PACKER; 8,626.4 Nipple - X; 8,615.6 Packer; 8,503.6 Mandrel GAS LIFT; 8,436.9 Mandrel GAS LIFT; 7,887.1 Mandrel GAS LIFT; 7,176.2 Mandrel GAS LIFT; 6,190.7 PACKER - PATCH - LWR; 4,913.5 ANCHOR LATCH ON SPACER PIPE; 4,904.0 LEAK; 4,907.0 PACKER - PATCH - UPR; 4,900.0 Mandrel GAS LIFT; 4,888.2 SURFACE; 37.0-4,351.4 Mandrel GAS LIFT; 2,942.3 7" Tie-Back Patch; 42.2-2,725.0 Production String 1 Cement; 34.0 ftKB Nipple - X; 474.9 CONDUCTOR; 38.0-115.0 Hanger; 33.0 KUP PROD KB-Grd (ft) 39.61 RR Date 3/24/1987 Other Elev Elevation Hi t 3M-05 ... TD Act Btm (ftKB) 9,110.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292170600 Wellbore Status PROD Max Angle & MD Incl (°) 52.78 MD (ftKB) 7,100.00 WELLNAME WELLBORE3M-05 Annotation Last WO: End Date 1/12/2022 H2S (ppm) 240 Date 12/10/2015 Comment 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) 8,677.0 6,175.3 48.24 CHOKE 2.813" X-LOCK W/ FLOW THRU SUB (1.75" ID / 18" OAL) 1/23/2022 1.780 8,685.0 6,180.6 48.25 WHIPSTOCK Set on X-Lock TOWS 8685' 1/22/2022 0.000 8,685.0 6,180.6 48.25 FISH 2.80 Dimond Speed Mill sitting on wipstock tray @ 8685' 1/22/2022 1.000 8,690.0 6,184.0 48.25 OBSTRUCTI ON NOTE: TIGHT SPOT BETWEEN LOWER TWO X- NIPPLES WHEN RUNNING LONG ASSEMBLIES (ABLE TO DRIFT 2.80" WITH NO ANOMALIES) 1/14/2022 2.992 8,697.0 6,188.6 48.25 CHOKE 2.813" X-LOCK W/ FLOW THRU SUB (1.75" ID / 18" OAL) 1/14/2022 1.750 8,801.0 6,257.9 48.24 FISH 1 1/2" GLV Empty Pocket; Fell downhole 7/27/1992 7/27/1992 0.000 8,807.0 6,261.9 48.24 FISH 1 1/2" OV Empty Pocket; Fell to Rathole 4/11/1993 4/11/1993 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) 2,942.3 2,492.7 43.17 6 GLV RK 1 1/2 1,260.0 9/23/2022 Camco MMG 0.188 4,888.2 3,754.9 50.87 5 OV RK 1 1/2 0.0 11/18/2022 Camco MMG 0.250 6,190.7 4,598.3 49.20 4 DMY RK 1 1/2 0.0 11/18/2022 Camco MMG 0.000 7,176.2 5,214.1 51.94 3 DMY RK 1 1/2 1/10/2022 Camco MMG 7,887.1 5,661.0 50.41 2 DMY RK 1 1/2 1/10/2022 Camco MMG 8,437.0 6,016.3 48.98 1 DMY RK 1 1/2 1/10/2022 Camco MMG Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 42.2 42.2 0.04 Depth Correction 7.000 7" 26# L-80 Casing Joint HYD 563 6.276 2,710.3 2,323.1 43.10 Cementing Nipple 7.000 7" 26# L-80 Casing Joint HYD 563 6.276 9,306.9 Aluminum Billet 2.630 Liner top billet - Northern Solutions NS Billet 1.920 8,738.7 6,216.4 48.25 Aluminum Billet 2.630 Aluminum Liner Top Billet Baker Billet 1.920 9,692.9 Deployment Sleeve 2.375 Shorty deployment sleeve Baker 1.920 8,710.6 6,197.7 48.25 Swell Packer 2.700 Swell Packer - Reactive Reactive Swell Pkr. 1.686 9,576.6 Deployment Sleeve 2.375 NSAK 350-238 OH Permanent QCLL Northern Solutions 1.920 10,831.5 Deployment Sleeve 2.375 NSAK 350-238 OH Permanent QCLL Northern Solutions 1.920 9,598.7 Aluminum Billet 2.630 Aluminum Liner Top Billet NS Billet 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,666.0 8,682.0 6,168.0 6,178.6 A-2, 3M-05 3/19/1992 6.0 RPERF 2 1/8" Dyna Strip, 0 deg. ph 8,672.0 8,676.0 6,172.0 6,174.6 A-2, 3M-05 7/5/1987 1.0 IPERF 4" Csg Gun, 120 deg. ph 8,682.0 8,720.0 6,178.6 6,203.9 A-2, A-1, 3M-05 3/19/1992 6.0 IPERF 2 1/8" Dyna Strip, 0 deg. ph 8,686.0 8,718.0 6,181.3 6,202.6 A-1, 3M-05 7/5/1987 1.0 IPERF 4" Csg Gun, 120 deg. ph 8,728.0 8,731.0 6,209.3 6,211.3 A-1, 3M-05 7/5/1987 1.0 IPERF 4" Csg Gun, 120 deg. ph 8,736.0 8,739.0 6,214.6 6,216.6 A-1, 3M-05 7/5/1987 1.0 IPERF 4" Csg Gun, 120 deg. ph 3M-05, 12/19/2022 3:15:16 PM Vertical schematic (actual) L1-02 Liner; 9,598.7-11,717.0 L1-03 Liner; 8,637.3-11,717.0 L1-01 Liner; 8,738.7-10,987.0 L1 Liner; 9,306.9-10,975.0 PRODUCTION ORIGINAL; 2,725.0-8,948.2 FISH; 8,807.0 FISH; 8,801.0 Sleeve - Frac; 8,739.0 IPERF; 8,736.0-8,739.0 IPERF; 8,728.0-8,731.0 IPERF; 8,686.0-8,718.0 IPERF; 8,682.0-8,720.0 CHOKE; 8,697.0 Nipple - X; 8,696.8 WHIPSTOCK; 8,685.0 OBSTRUCTION; 8,690.0 FISH; 8,685.0 CHOKE; 8,677.0 Nipple - X; 8,677.0 IPERF; 8,672.0-8,676.0 RPERF; 8,666.0-8,682.0 WHIPSTOCK; 8,666.0 WHIPSTOCK; 8,646.0 OTHER; 8,637.0 PACKER; 8,626.4 Nipple - X; 8,615.6 Packer; 8,503.6 Mandrel GAS LIFT; 8,436.9 Mandrel GAS LIFT; 7,887.1 Mandrel GAS LIFT; 7,176.2 Mandrel GAS LIFT; 6,190.7 PACKER - PATCH - LWR; 4,913.5 ANCHOR LATCH ON SPACER PIPE; 4,904.0 LEAK; 4,907.0 PACKER - PATCH - UPR; 4,900.0 Mandrel GAS LIFT; 4,888.2 SURFACE; 37.0-4,351.4 Mandrel GAS LIFT; 2,942.3 7" Tie-Back Patch; 42.2-2,725.0 Production String 1 Cement; 34.0 ftKB Nipple - X; 474.9 CONDUCTOR; 38.0-115.0 Hanger; 33.0 KUP PROD 3M-05 ... 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&21'8&725 +DQJHU .83352'0 :(//1$0( :(//%25(0 C:\Users\aebell\Desktop\January 2022 Data Drop\CPA Data Drop 01312022\2022-01-26_20195_KRU_3M-05_EVCameraJob_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 20195 KRU 3M-05 50-029-21706-00 EV Camera Job 26-Jan-22 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 FTP ______________________________ ______________________________________ 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 _______________________________________________ Signatururuuruurrururururuururruruurururrurururururuururruuruuruuue 01/31/2022 37' (6HW By Abby Bell at 1:49 pm, Jan 31, 2022 Originated: Delivered to:14-Jan-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 3M-05 50-029-21706-00 905919689 Kuparuk River Jet Cut Record Field- Final 12-Dec-21 0 12 3M-05 50-029-21706-00 905919689 Kuparuk River String Shot Record Field- Final 12-Dec-21 0 13 3O-04 50-029-21826-00 907483748 Kuparuk River Multi Finger Caliper Field & Processed 12-Jan-22 0 145678910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:01/14/2022Wd͗ϭϴϳϬϮϱϬͲ^Ğƚ͗ϯϲϮϰϬBy Abby Bell at 12:45 pm, Jan 14, 2022 Originated: Delivered to:14-Jan-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 3M-05 50-029-21706-00 905919689 Kuparuk River Jet Cut Record Field- Final 12-Dec-21 0 12 3M-05 50-029-21706-00 905919689 Kuparuk River String Shot Record Field- Final 12-Dec-21 0 13 3O-04 50-029-21826-00 907483748 Kuparuk River Multi Finger Caliper Field & Processed 12-Jan-22 0 145678910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:01/14/2022Wd͗ϭϴϳϬϮϱϬͲ^Ğƚ͗ϯϲϮϯϵBy Abby Bell at 12:45 pm, Jan 14, 2022 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. 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The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϴϳϬϮϱϬͲ^Ğƚ͗ϯϲϭϴϱJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct-21 C:\Users\aebell\Desktop\December 2021 Data Drop\CPA Data Drop 12232021\2021-12-22_Run3_15822_KRU_3M-05_CaliperSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 15822 KRU 3M-05 50-029-21706-00 Caliper Survey 22-Dec-21 (run 3) 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 FTP ______________________________ ______________________________________ 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 37' (6HW ______________________________________ Signatttttttttttttttttttttttttttttuuuuruuuuuuuuuuuuuuuuuuuuuuuuuuue 12/23/2021 By Abby Bell at 10:15 am, Dec 23, 2021 ! 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Loepp, Victoria T (OGC) To:Ward, Dusty K Subject:Re: 3M-05 Scope Change Date:Saturday, December 18, 2021 11:15:32 AM Attachments:3M-05 RWO Prop Schematic_Rev1.pdf 3M-05_2021_Sundry_RWO_Summary_Rev1.pdf 9_3M-05 10-403 RWO APPROVED - Copy.pdf Dusty, Approval is granted to proceed with change out of the rams. Please submit a 10-403 Sundry for Change of Approved program by Monday, Dec 20, 2021. Thanx, Victoria Sent from my iPhone On Dec 18, 2021, at 9:27 AM, Ward, Dusty K <Dusty.Ward@conocophillips.com> wrote: Victoria, Hope this finds you well. We tried to slim up our BHA and get past a little tight spot in our 7” casing, but did not succeed with getting a drift for the new packer. This pushes us into doing a Full subsidence. Please find attached update scope that includes Pull and Replace of the 7” Production casing as well (red text is added scope). I also attached a schematic showing the cemented OA we’ll have when we’re done. Please call my cell if you have any questions. I also included original approved sundry for convenience. I’ll try to get a hold of you on the phone here next. Thank you. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 C:\Users\aebell\Desktop\December 2021 Data Drop\CPA Data Drop 12232021\2021-12-15_Run2_20190_3M-05_CaliperSurvey_Transmittal_Replacement.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 20190 KRU 3M-05 50-029-21706-00 Caliper Survey 15-Dec-21 (run 2) DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC ***Replace previous upload**** Attn: Natural Resources Technician ***Updated Data to View files*** 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ 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 37' (6HW __________________________________________ Signaturuuuuuuuuuuuuuuuuuuuuuuuuue 12/23/2021 By Abby Bell at 10:08 am, Dec 23, 2021 C:\Users\aebell\Desktop\December 2021 Data Drop\CPA Data Drop 12162021\2021-12-15_run2_20190_KRU_3M-05_CaliperSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 20190 KRU 3M-05 50-0259-21706-00 Caliper Survey 15-Dec-21 (run 2) 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 FTP ______________________________ ______________________________________ Print Name 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 37' (6HW ___________________________________________________ Signatururuurururururururururururuurrururururururururrrurururururruuee Abby Bell By Abby Bell at 12:27 pm, Dec 16, 2021 C:\Users\aebell\Desktop\December 2021 Data Drop\CPA Data Drop 12152021\2021-12-12_20189_KRU_3M-05_CementBondLog_MultiFingerCaliperLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 20189 KRU 3M-05 50-029-21706-00 Cement Bond Log / Multi-Finger Caliper Log 12-Dec-12 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 FTP ______________________________ ______________________________________ 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 37' (6HW ____________________________________ Signatururururuurururuuururururuururruuuuuuuuururuuruuuuue 12/15/2021 By Abby Bell at 2:46 pm, Dec 15, 2021 C:\Users\aebell\Desktop\December 2021 Data Drop\CPAI Data Drop 12132021\2021-12-12_20189_KRU_3M-05_CaliperSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 20189 KRU 3M-05 50-0259-21706-00 Caliper Survey 12-Dec-21 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 FTP ______________________________ ______________________________________ Print Name 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 37' (6HW ___________________________________ Signatururuurururrururururuuurururuuuruuruuuuuuuuuuuuue Abby Bell By Abby Bell at 9:38 am, Dec 14, 2021 ! 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" <>. &' ( )* !#$8 )+ ,+-. , /0)+ ,+-. , 5%07 1+,& 0)3= )= ,(3= )= (,)= -,)-=/F -F 3%)80F //= (,(= 03(0= & 9&4 6 0---%0/0>0/'0%0/,=> 0/,-%0/,3= 03,= 8,8'7' '%/80F <"C %% < : 9G: @ <#* & !H 437/6'-)%-), D /. # ! # ! !# D & 7%(7, # ,8'7'7 ,. / 2&./3,"4&'3,4&' /& 3 ,.5 * #& 9& 0/('= * #& :& -'3= By Samantha Carlisle at 1:10 pm, Jul 01, 2021 321-325 BOP test to 3000 psig Annular preventer to 2500 psig X X VTL 7/26/21 10-404 DLB 07/01/2021 X DSR-7/1/21 dts 7/26/2021 JLC 7/26/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.26 14:35:42 -08'00' RBDMS HEW 7/28/2021 !! " #$#%&$!'$ &$!'$ &($! !")$# !! *!#+#,) # -,"$.&$!'$ /$" !! "0 /!#1*$"2 "*&&!. " 3/" && .$2*&&! -, && 4!&$!'$3-,"51!5 #!$44& -$# %"2"144")$&#6"')"7"2-" 8 9:/;<+= 86$!" . $&&12" &&2 <+$!$!$24"2-"3#,$!$'63&$'.$!$2,$!56$ )2%" 4"2-# 2#4$!! .83::, !6&&6$!!&-#251#, :/#$$!2"6&&%"$ :/! 2#"$-'&1 #,6&&,$!+><?#5 . 3%1,$)$1@!# !""@ "$1%"#," %"$# 4&$!-#$-#$#A B+ :,6"')".$& !#4&&#,+><?#5 .$24$-'" "2"#4! 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VTL 7/26/21 Pressure test casing and tubing to 3000 psig for 30 min and chart Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 3' of Rathole) 8,742.0 11/14/2019 3M-05 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth & Replaced OV 11/14/2019 3M-05 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 115.0 Set Depth (TVD) (… 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 4,351.4 Set Depth (TVD) (… 3,419.3 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 8,948.2 Set Depth (TVD) (… 6,355.9 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Max … 2 7/8 ID (in) 2.44 Top (ftKB) 33.0 Set Depth (ft… 8,590.6 Set Depth (TVD) (ft… 6,117.8 Wt (lb/ft) 6.50 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 33.0 33.0 0.03 HANGER VETCO GRAY 2 7/8" Tubing Header w/ double pin Pup 2.875 1,796.6 1,661.7 43.00 SAFETY VLV OTIS 'FMX' SSSV 4.76" OD, 2.32" ID 2.320 8,529.2 6,077.0 48.64 PBR CAMCO 2 7/8" OEJ, 4.750" OD Barrel 5.750" OD skirt & btm, 3.250" OD slick stick, 2.312" ID 2.312 8,559.3 6,096.9 48.45 PACKER CAMCO 2 7/8" HRP-1-SP Retr. Pkr 48K pull or Ret release 5.987" OD, 2.347" ID 2.347 8,578.2 6,109.5 48.33 NIPPLE CAMCO 2 7/8" D-Nipple 2.250" ID 2.250 8,589.9 6,117.3 48.26 SOS Baker 2 7/8" Shear out Sub (Sheared). TTL ELMD 8562' SWS 3/23/1987 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 8,801.0 6,257.9 48.24 FISH 1 1/2" GLV Empty Pocket; Fell downhole 7/27/1992 7/27/1992 0.000 8,807.0 6,261.9 48.24 FISH 1 1/2" OV Empty Pocket; Fell to Rathole 4/11/1993 4/11/1993 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,666.0 8,682.0 6,168.0 6,178.6 A-2, 3M-05 3/19/1992 6.0 RPERF 2 1/8" Dyna Strip, 0 deg. ph 8,672.0 8,676.0 6,172.0 6,174.6 A-2, 3M-05 7/5/1987 1.0 IPERF 4" Csg Gun, 120 deg. ph 8,682.0 8,720.0 6,178.6 6,203.9 A-2, A-1, 3M-05 3/19/1992 6.0 IPERF 2 1/8" Dyna Strip, 0 deg. ph 8,686.0 8,718.0 6,181.3 6,202.6 A-1, 3M-05 7/5/1987 1.0 IPERF 4" Csg Gun, 120 deg. ph 8,728.0 8,731.0 6,209.3 6,211.3 A-1, 3M-05 7/5/1987 1.0 IPERF 4" Csg Gun, 120 deg. ph 8,736.0 8,739.0 6,214.6 6,216.6 A-1, 3M-05 7/5/1987 1.0 IPERF 4" Csg Gun, 120 deg. ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,093.3 2,602.5 43.55 MMH FMHO 1 GAS LIFT GLV BK-5 0.125 1,291.0 11/28/2005 2 5,744.1 4,305.5 49.41 MMH FMHO 1 GAS LIFT GLV BK-5 0.188 1,362.0 11/28/2005 3 7,319.8 5,303.4 51.34 MMH FMHO 1 GAS LIFT OV BK-5 0.188 0.0 11/14/2019 4 7,830.8 5,625.2 50.48 MMH FMHO 1 GAS LIFT DMY BTM 0.000 0.0 11/28/2005 5 8,247.6 5,892.5 49.46 MMH FMHO 1 GAS LIFT DMY BK-5 0.000 0.0 11/24/1995 6 8,479.0 6,043.9 48.88 MMH FMHO 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/27/2003 Notes: General & Safety End Date Annotation 7/15/2009 NOTE: IA x OA COMMUNICATION 3M-05, 5/12/2021 2:31:28 PM Vertical schematic (actual) PRODUCTION; 35.0-8,948.2 FISH; 8,807.0 FISH; 8,801.0 IPERF; 8,736.0-8,739.0 IPERF; 8,728.0-8,731.0 IPERF; 8,686.0-8,718.0 IPERF; 8,682.0-8,720.0 IPERF; 8,672.0-8,676.0 RPERF; 8,666.0-8,682.0 SOS; 8,589.9 NIPPLE; 8,578.2 PACKER; 8,559.3 PBR; 8,529.2 GAS LIFT; 8,479.0 GAS LIFT; 8,247.6 GAS LIFT; 7,830.8 GAS LIFT; 7,319.8 GAS LIFT; 5,744.1 SURFACE; 37.0-4,351.4 GAS LIFT; 3,093.3 SAFETY VLV; 1,796.6 CONDUCTOR; 38.0-115.0 HANGER; 33.0 KUP PROD KB-Grd (ft) 39.61 Rig Release Date 3/24/1987 3M-05 ... TD Act Btm (ftKB) 9,110.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292170600 Wellbore Status PROD Max Angle & MD Incl (°) 52.78 MD (ftKB) 7,100.00 WELLNAME WELLBORE3M-05 H2S (ppm) 240 Date 12/10/2015 Comment SSSV: TRDP Annotation Last WO: End Date 7/10/1992 Proposed CTD Sidetrack3M-05Current Setup3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco gas lift mandrels @ TBDBaker Permier packer @ ~6,065' MD 3-1/2" HES landing X-nipple TBD' MD (2.812" min ID)3-1/2" Tandem Wedge Assembly2-7/8" 6.5# TubingA-sand perfs 8,666' - 8,739'16" 62.5# H-40 shoe @ 115' MD9-5/8" 36# J-55 shoe @ 4,351' MD7" 26# J-55 shoe @ 8,948' MD3-1/2" 9.3# Tubing16" 62.5# H-40 shoe @ 115' MD9-5/8" 36# J-55 shoe @ 4,351' MDA-sand perfs 8,666' - 8,739'7" 26# J-55 shoe @ 8,948' MD ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTED©DATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 14 March 2020 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 3M- 05 (PTD #87-25). 3M-05 was originally drilled in 1987 as an A-sand producer. It has a know IA leak on gas and has been waived for production due to passing MIT-OA. This well was selected by the CTD team as donor well for a CTD sidetrack only the well has 2-7/8” tubing. The workover goal is to pull the 2-7/8” tubing & packer in order to upsize the tubing to 3 ½” tubing with a portion of 4 ½” tubing below the packer to allow for CTD to sidetrack the well. This workover is planned to be execute by Doyon 142. If you have any questions or require any further information, please contact me at 265-6927. Sincerely, James C Hayes Senior Wells Engineer CPAI Drilling and Wells By Samantha Carlisle at 7:40 am, Mar 19, 2020 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair W ell Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 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? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8948'2,721 None 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 Commission Representative: GINJ Op Shutdown Abandoned James Hayes Contact Name:James Hayes Senior Workover Engineer Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 5/7/2020 2-7/8" Otis FMX Camco HRP-1-SP Perforation Depth MD (ft): 8948' 8,672' - 8,739' 16" 9-5/8" 80' 7"8913' 4314' MD 115' 3413' 6349' 115' 4351' Size KRU 3M-05 Kuparuk River Field / Kuparuk River Oil Pool L-80 TVD Burst 8951' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25521, ALK 2557 087-025 PO Box 100360, Anchorage AK 99510 50-029-21706 ConocoPhillips Alaska Inc COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): 6,168' - 6,217' James.C.Hayes@cop.com 263-6927, 918-914-9609 N/A6356' 8559' 6070' 1,797' MD / 1,662' TVD 8,559' MD / 6,097' TVD Perforation Depth TVD (ft): Tubing Size: Length m n P s t _ 66 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Mar-18-2020 320-124 187-025 BOP test pressure to 3500 psig Annular Preventer test pressure to 2500 psig X X 10-404 CDW 03/19/2020 -00-00 ADL0025523 DLB 3/19/20 X 00 DSR-3/19/2020 XCTD setup VTL 3/26/20 dts 3/26/2020 3/26/2020 3M-05 Rig Workover CTD Setup (PTD #: 087-025) 1 Current Operations: This well is currently producing and awaiting a RWO. Scope of Work: Pull existing 2-7/8” tubing string & run new 3 ½” tubing string General Well info: Well Type: Producer MPSP: 2,721 psi using 0.1 psi/ft gradient Static BHP: 3,340 psi / 7,279’ 6,194’ TVD (10.8 ppg EMW) Wellhead type/pressure rating: Vecto Gray , 7-1/16” - 5M psi top special connect BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams MIT results: CMIT-TxIA Failed – Waived MIT-OA PASSED – 02/16/2020 IC POT &PPPOT PASSED – 2/15/2020 TBG POT &PPPOT PASSED – 2/15/2020 Production Engineer: Devin Kozak / Ethan Plunkett Workover Engineer: James Hayes Pre-Rig Work 1. Pre-rig cut in tubing at 2. String shot and chem cut first joint above the packer. 3. Grease tree valves and set BPV. Workover Procedure 1. MIRU. Pull BPV. Circulate workover fluid. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 2. Set BPV & blanking plug, ND tree, NU BOPE and pressure test rams to 3,500 psi and annular to 2,500 psi. 3. Pull blanking plug & BPV. Screw in landing joint, BOLDS's, and pull tbg hgr to the rig floor. 4. Lay down tubing for scrap 5. MU fishing assembly RIH & latch onto tubing 6. Jar tubing free from seal assembly 7. Circulate bottoms up and prepare to close annular in the event the packer has released & there could be trapped gas below the packer 8. POOH, lay down fishing BHA & fish 9. Run back in hole with new fishing assembly to packer 10. Latch onto packer & jar packer free 11. Circulate bottoms up and close annular due to possible trapped gas below packer 12. POOH & LD fish and remaining tubing 13. POOH, lay down milling BHA, and PU packer fishing assembly w/ spear 14. RIH, tag packer top, set spear and jar fish free 15. POOH and LD fish 16. Make up clean out/scraper assembly & RIH to 8,500’ 17. Wash down to 8,750’ MD to clean up perfs 18. POOH & LD clean out assembly 19. MU lower completion string on DP 20. RIH to packer set depth 21. Circulate in corrosion inhibited brine 22. RU E-line run in hole, correlate K1 & verify spaceout 23. POOH & RD E-line 24. Move to set depth drop ball & rod and pressure up to set packer 25. Shear out of PBR & POOH LD DP 26. MU upper completion RIH & tag packer top 27. Determine space out, make up tubing pups & land tubing 28. Pressure test packoffs 29. Pressure test tubing and then the IA 3M-05 Rig Workover CTD Setup (PTD #: 087-025) 2 30. Shear out the SOV and freeze protect the well 31. Install the BPV, ND the BOPE, and NU the production tree Post-Rig Work 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline. Pull SOV 4. Install OV 5. Pull ball & rod 6. Pull RHC plug in X-nipple 7. Handoff to operations to put back on production. BOP Configuration The following ram configuration will be utilized for the West Sak wells. Further details regarding the BOPE specifications can be found with the Doyon 142 documentation on file with the State. FIXED/VBR BLIND VBR ANNULAR Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 3' of Rathole) 8,742.0 11/14/2019 3M-05 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth & Replaced OV 11/14/2019 3M-05 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 4,351.4 Set Depth (TVD) … 3,419.3 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 8,948.2 Set Depth (TVD) … 6,355.9 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 33.0 Set Depth (ft… 8,590.6 Set Depth (TVD) (… 6,117.8 Wt (lb/ft) 6.50 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.0 33.0 0.03 HANGER VETCO GRAY 2 7/8" Tubing Header w/ double pin Pup 2.875 1,796.6 1,661.7 43.00 SAFETY VLV OTIS 'FMX' SSSV 4.76" OD, 2.32" ID 2.320 8,529.2 6,077.0 48.64 PBR CAMCO 2 7/8" OEJ, 4.750" OD Barrel 5.750" OD skirt & btm, 3.250" OD slick stick, 2.312" ID 2.312 8,559.3 6,096.9 48.45 PACKER CAMCO 2 7/8" HRP-1-SP Retr. Pkr 48K pull or Ret release 5.987" OD, 2.347" ID 2.347 8,578.2 6,109.5 48.33 NIPPLE CAMCO 2 7/8" D-Nipple 2.250" ID 2.250 8,589.9 6,117.3 48.26 SOS Baker 2 7/8" Shear out Sub (Sheared). TTL ELMD 8562' SWS 3/23/1987 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 8,801.0 6,257.9 48.24 FISH 1 1/2" GLV Empty Pocket; Fell downhole 7/27/1992 7/27/1992 0.000 8,807.0 6,261.9 48.24 FISH 1 1/2" OV Empty Pocket; Fell to Rathole 4/11/1993 4/11/1993 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,666.0 8,682.0 6,168.0 6,178.6 A-2, 3M-05 3/19/1992 6.0 RPERF 2 1/8" Dyna Strip, 0 deg. ph 8,672.0 8,676.0 6,172.0 6,174.6 A-2, 3M-05 7/5/1987 1.0 IPERF 4" Csg Gun, 120 deg. ph 8,682.0 8,720.0 6,178.6 6,203.9 A-2, A-1, 3M-05 3/19/1992 6.0 IPERF 2 1/8" Dyna Strip, 0 deg. ph 8,686.0 8,718.0 6,181.3 6,202.6 A-1, 3M-05 7/5/1987 1.0 IPERF 4" Csg Gun, 120 deg. ph 8,728.0 8,731.0 6,209.3 6,211.3 A-1, 3M-05 7/5/1987 1.0 IPERF 4" Csg Gun, 120 deg. ph 8,736.0 8,739.0 6,214.6 6,216.6 A-1, 3M-05 7/5/1987 1.0 IPERF 4" Csg Gun, 120 deg. ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,093.3 2,602.5 MMH FMHO 1 GAS LIFT GLV BK-5 0.125 1,291.0 11/28/2005 2 5,744.1 4,305.5 MMH FMHO 1 GAS LIFT GLV BK-5 0.188 1,362.0 11/28/2005 3 7,319.8 5,303.4 MMH FMHO 1 GAS LIFT OV BK-5 0.188 0.0 11/14/2019 4 7,830.8 5,625.2 MMH FMHO 1 GAS LIFT DMY BTM 0.000 0.0 11/28/2005 5 8,247.6 5,892.5 MMH FMHO 1 GAS LIFT DMY BK-5 0.000 0.0 11/24/1995 6 8,479.0 6,043.9 MMH FMHO 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/27/2003 Notes: General & Safety End Date Annotation 7/15/2009 NOTE: IA x OA COMMUNICATION 3M-05, 11/15/2019 7:33:12 AM Vertical schematic (actual) PRODUCTION; 35.0-8,948.2 FISH; 8,807.0 FISH; 8,801.0 IPERF; 8,736.0-8,739.0 IPERF; 8,728.0-8,731.0 IPERF; 8,686.0-8,718.0 IPERF; 8,682.0-8,720.0 IPERF; 8,672.0-8,676.0 RPERF; 8,666.0-8,682.0 SOS; 8,589.9 NIPPLE; 8,578.2 PACKER; 8,559.3 PBR; 8,529.2 GAS LIFT; 8,479.0 GAS LIFT; 8,247.6 GAS LIFT; 7,830.8 GAS LIFT; 7,319.8 GAS LIFT; 5,744.1 SURFACE; 37.0-4,351.4 GAS LIFT; 3,093.3 SAFETY VLV; 1,796.6 CONDUCTOR; 38.0-115.0 HANGER; 33.0 KUP PROD KB-Grd (ft) 39.61 Rig Release Date 3/24/1987 3M-05 ... TD Act Btm (ftKB) 9,110.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292170600 Wellbore Status PROD Max Angle & MD Incl (°) 52.78 MD (ftKB) 7,100.00 WELLNAME WELLBORE3M-05 Annotation Last WO: End Date 7/10/1992 H2S (ppm) 240 Date 12/10/2015 Comment SSSV: TRDP Proposed CTD Sidetrack3M-05Current Setup3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco gas lift mandrels @ TBDBaker Permier packer @ ~6,065' MD 3-1/2" HES landing X-nipple TBD' MD (2.812" min ID)3-1/2" Tandem Wedge Assembly2-7/8" 6.5# TubingA-sand perfs 8,666' - 8,739'16" 62.5# H-40 shoe @ 115' MD9-5/8" 36# J-55 shoe @ 4,351' MD7" 26# J-55 shoe @ 8,948' MD3-1/2" 9.3# Tubing16" 62.5# H-40 shoe @ 115' MD9-5/8" 36# J-55 shoe @ 4,351' MDA-sand perfs 8,666' - 8,739'7" 26# J-55 shoe @ 8,948' MD Doyon 142 BOP & Choke Configuration 2-7/8” x 5” VBR BLIND 2-7/8” x 5” VBR ANNULAR 3M-05 Rig Workover CTD Setup (PTD #: 087-025) 1 Current Operations: This well is currently producing and awaiting a RWO. Scope of Work: Pull existing 2-7/8” tubing string & run new 3 ½” tubing string General Well info: Well Type: Producer MPSP: 2,721 psi using 0.1 psi/ft gradient Static BHP: 3,340 psi / 7,279’ TVD (10.8 ppg EMW) Wellhead type/pressure rating: Vecto Gray , 7-1/16” - 5M psi top special connect BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams MIT results: CMIT-TxIA Failed – Waived MIT-OA PASSED – 02/16/2020 IC POT &PPPOT PASSED – 2/15/2020 TBG POT &PPPOT PASSED – 2/15/2020 Production Engineer: Devin Kozak / Ethan Plunkett Workover Engineer: James Hayes Pre-Rig Work 1. Pre-rig cut in tubing at 2. String shot and chem cut first joint above the packer. 3. Grease tree valves and set BPV. Workover Procedure 1. MIRU. Pull BPV. Circulate workover fluid. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 2. Set BPV & blanking plug, ND tree, NU BOPE and pressure test rams to 3,500 psi and annular to 2,500 psi. 3. Pull blanking plug & BPV. Screw in landing joint, BOLDS's, and pull tbg hgr to the rig floor. 4. Lay down tubing for scrap 5. MU fishing assembly RIH & latch onto tubing 6. Jar tubing free from seal assembly 7. Circulate bottoms up and prepare to close annular in the event the packer has released & there could be trapped gas below the packer 8. POOH, lay down milling fish 9. Run back in hole with new fishing assembly to packer 10. Latch onto packer & jar packer free 11. Circulate bottoms up and close annular due to possible trapped gas below packer 12. POOH & LD fish and remaining tubing 13. POOH, lay down milling BHA, and PU packer fishing assembly w/ spear 14. RIH, tag packer top, set spear and jar fish free 15. POOH and LD fish 16. MU lower completion string on DP 17. RIH to packer set depth 18. Circulate in corrosion inhibited brine 19. Drop ball & rod and pressure up to set packer 20. Shear out of PBR & POOH LD DP 21. MU upper completion RIH & tag packer top 22. Determine space out, make up tubing pups & land tubing 23. Pressure test packoffs 24. Pressure test tubing and then the IA 25. Shear out the SOV and freeze protect the well 26. Install the BPV, ND the BOPE, and NU the production tree 3M-05 Rig Workover CTD Setup (PTD #: 087-025) 2 Post-Rig Work 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline. Pull SOV 4. Install OV 5. Pull ball & rod 6. Pull RHC plug in X-nipple 7. Handoff to operations to put back on production. BOP Configuration The following ram configuration will be utilized for the West Sak wells. Further details regarding the BOPE specifications can be found with the Doyon 142 documentation on file with the State. FIXED/V BLIND VBR ANNULA Proposed CTD Sidetrack3M-05Current Setup3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco gas lift mandrels @ TBDBaker Permier packer @ ~8,460' MD 3-1/2" HES landing X-nipple TBD' MD (2.812" min ID)4-1/2" Big Tail Pipe configuration9-5/8" 36# J-55 shoe @ 4,351' MD7" 26# J-55 shoe @ 8,948' MD16" 62.5# H-40 shoe @ 115' MDA-sand perfs 8,666' - 8,739'2-7/8" 6.5# TubingA-sand perfs 8,666' - 8,739'16" 62.5# H-40 shoe @ 115' MD9-5/8" 36# J-55 shoe @ 4,351' MD7" 26# J-55 shoe @ 8,948' MD3-1/2" 9.3# Tubing From:Loepp, Victoria T (CED) To:Hayes, James C Subject:RE: [EXTERNAL]RE: 3M-05 10-403 Date:Tuesday, March 24, 2020 2:12:00 PM Perfect From: Hayes, James C <James.C.Hayes@conocophillips.com> Sent: Tuesday, March 24, 2020 2:11 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: 3M-05 10-403 Ok take a look and let me know if you like what you see please? Thanks, James Hayes C: +1 918.914.9609 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, March 24, 2020 1:43 PM To: Hayes, James C <James.C.Hayes@conocophillips.com> Subject: Re: [EXTERNAL]RE: 3M-05 10-403 This works great. You could write it by hand and that would be fine. Yes, include the choke assembly. Thanx, Victoria Sent from my iPhone On Mar 24, 2020, at 1:38 PM, Hayes, James C <James.C.Hayes@conocophillips.com> wrote: Is this too crude of a drawing or would this meet what you would like to see and do you need the choke assembly as well? Thanks, James Hayes C: +1 918.914.9609 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, March 24, 2020 1:22 PM To: Hayes, James C <James.C.Hayes@conocophillips.com> Subject: RE: [EXTERNAL]RE: 3M-05 10-403 Yes, please do update. Point forward, please include on all submissions. Can be on schematic or in listed info. Thanx, Victoria From: Hayes, James C <James.C.Hayes@conocophillips.com> Sent: Tuesday, March 24, 2020 1:20 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: 3M-05 10-403 Sure I was told you guys had that on file otherwise I would have included it. We will be using 2-7/8” x 5” VBR’s in our upper & lower rams. I can update that. Thanks, James Hayes C: +1 918.914.9609 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, March 24, 2020 1:18 PM To: Hayes, James C <James.C.Hayes@conocophillips.com> Subject: [EXTERNAL]RE: 3M-05 10-403 James, I would like to see the size of the BOP rams used as well as the type and configuration. Thanx, Victoria From: Hayes, James C <James.C.Hayes@conocophillips.com> Sent: Tuesday, March 24, 2020 10:25 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: 3M-05 10-403 Victoria, I’m not sure if you have had a chance to look at the 10-403 I submitted for 3M-05 but in the sundry I specified a “Big Tail Pipe” style kick off method for CTD. Unfortunately in order to manufacture this requires us to bring folks up from L-48. We have elected to reduce exposure of COVID-19 and instead run our normal tandem wedge setup which is manufactured locally. This change does tweak my procedure a bit. I have attached an updated procedure & proposed schematic which can be swapped out from the original. In addition I’m sure you have seen our new rig schedule which has us picking up 142 this week to start workovers about a month ahead of schedule. This unfortunately means that this well will hit the schedule here in about 2 weeks. Finally this change will also be carried over to 3G-02 as well so you will see a similar email today for that sundry as well. Thanks, James Hayes COP - Alaska RWO Engineer / CTD Liaison C: +1 918.914.9609 O: +1 907.265.6927 <142 BOP Configuration.pdf> 147025 31469 Well To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 MOLE Transmittal RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Report 2) Signed : l Print Name: RECEIVED READ Cased Hole, Inc. NOV 19 2019 Attn: Diane Williams �+ 4141 BStreet A��`CV Suite 308 Anchorage, AK 99503 Diane.Williams(a)readcasedhole com 05 -Nov -19 3M-05 1 Report / CD 50-029-21706-00 Date : I I l U 2 J READ CASED HOLE, INC, 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL:READ-ANCHORAGE(/DREADCASEDHOLECOM WEBSITE: WWW.READCASEDHOLE.COM SCANNED NOV 2 2 2019 https.'reedcasedhole-mysharepoincwm/personaVdiane Williams readcas�hole com/Documents/DDrive/TempCeliper/3S- 18/CPAI Kup_Caliper_Template)CD__Pe VComc.Mlips_Trammitd= 8 70 2,5 31469 CASED Memory Multi -Finger Caliper HOLE Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3M-05 Log Date: November 5, 2019 Field: Kuparuk Log No.: 1 State: Alaska Run No.: 14410 API No. 50-029-21706-00 Pipe Description: 2.875 inch 6.5 Ib. L-80 ABM EUE Top Log Interval: Surface Pie Use: Tubing Bottom Log Interval: 8.561 Ft. (MDI Inspection Type : Corrosive B Mechanical Damage Inspection COMMENTS: This caliper data is tied into the top of GLM 6 at 8,479 feet per the wellbore schematic. This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage, particularly with respect to buckling due to sub -surface subsidence. The caliper recordings indicate slight cork -screwed tubing from —5,100 feet to 8,561 feet. The caliper recordings indicate the 2.875 inch tubing logged appears to range from good to fair condition, with a maximum recorded wall penetration of 26% in a line of corrosion in joint 146 (4,603 ft). Wall penetrations ranging from 20% to 26% wall thickness are recorded in 6 of the 275 joints logged. Recorded damage appears as a line of pits and line corrosion. No significant areas of cross-sectional wall loss are recorded throughout the tubing logged. The caliper recordings indicate intermittent light to moderate deposits throughout the tubing logged, restricting the I.D. to 2.26 inches in joint 193 (6,087 ft). A graph illustrating minimum recorded diameters on a joint -by -joint basis across the tubing logged is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: -I, �' �--i Percent Wall Penetration Joint Depth Line Corrosion 26 146 4,603 Ft. (MD) Line Corrosion 23 31 1,005 Ft. (MD) Line of Pits 22 99 3,143 Ft. (MD) Line Corrosion 21 80 2,540 Ft. (MD) Line of Pits 20 133 4,218 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 10%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: Description Minimurn Recorded Diameter Joint Depth Deposits 2.26 inches 193 6,087 Ft. (MD) Deposits 2.28 inches 245 7,709 Ft. (MD) Deposits 2.28 inches 242 7,641 Ft. (MD) Deposits 2.29 inches 232 7,315 Ft. (MD) Deposits 2.29 inches 202 6,376 Ft. (MD) C. Goerdt C. Waldrop S. Ferguson Field Engineers) Anilyst(s) witness(os) READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmerica(a)readcasadhol com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 WANNED NOV 2 2 2019 Correlation of Recorded Damage to Borehole Profile E Pipe 1 2.875 in (39.5'- 8,561.2') Well: 3M-05 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country. USA Survey Date: November 4, 2019 GLM GLM GLM 3 GLM 4 GLM 5 GLM 6 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 43 793 1,571 2,381 3,165 0 3,945 c S 4,715 p 5,497 6,284 ME 7,870 269.2 8,529 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 269.2 25 i 50 75 100 $� 125 E c Z c 150 'o 175 200 225 250 i 43 793 1,571 2,381 3,165 0 3,945 c S 4,715 p 5,497 6,284 ME 7,870 269.2 8,529 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 269.2 CASED LP HOLE Well: 3M-05 Field: Kuparuk Company: Conoco Phillips Alaska, Inc. Country: USA v a E 0 Z a 'o 30 40 50 57 67 77 97 106 116 126 136 146 156 166 176 185 195 205 215 225' 234' 244' 253 262 269 Minimum Diameter Profile Survey Date: November 4, 2019 Tool Type: UW MFC 24 No. 10020078 Tool Size: 1.69 inches Tubing I.D.: 2.441 inches Minimum Measured Diameters (in.) 2 2.2 2.4 39 325 949 1,259 1,571 1,819 2,130 2,756 3,068 3,354 3,664 3,977 4,593 4,903 5,215 5,529 5,817 6,126 6,441 6,755 7,069 7,359 7,674 7,965 8,253 8,493 fCASED HOLE Body Region Analysis Well: 3M-05 Survey Date: November 4, 2019 300 �r Field: Kuparuk Tool Type: UW MFC 24 No. 10020078 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches 50 —�— - Country: USA No. of Fingers: 24 _._ Pipe 2.875 in. 6.5 ppf L-80 ABM-EUE Analyst:_ _. Waldrop _ Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 15 - 2.875 in. 6.5 ppf _,L-80 ABM-EUE 2.441 in. 39 ft. 8,561 ft. Penetration (% wall) 300 �r 250 200 150 - 100 50 —�— - 0 -- J 0 to 20 to 40 to over 20% 40% 85% 85% tuber f ioints�nallyzed 269 6 0 0 — F Damage Configuration (body) l 20 15 - 10 - -�- — 5 -- I -- 0 —_- Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole _ Number of joints damagQd total = 30j_ 12 0 18 0 0 Damage Profile (% wall) Penetration body 0 0.1 ce GLM 1 (10:00) 146 GLM 2 (3:00) 195 GLM 3 (2:00) 244 GLM 4 (12:00) GLM 5 (7:00) GLM 6 (9:30) _ Bottom of Survey _= 269.2 - Metal loss body 50 100 =_ I CASED HOLE Joint Tabulation Sheet =MirWell: 3M-05 Survey Date: November 4, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhilips Alaska, Inc. Pipe Description 2.875 in. 6.5 ppf L-80 ABM-EUE Nom. ID Body Wall Top Depth Bottom Depth 2.441 in. 0.217 in. 39 ft 8,561 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min, I.D. (in.) Comments Damage Profile (% wall) 0 50 100 0.1 39 0 0.02 11 2 2.39 Pu 1 43 0.03 00-3 14 3 2.38 2 74 0 0.02 11 3 2.41 3 106 0 0.02 10 3 2.37 Lt. De osits. 4 5 137 169 0.03 0 0.03 0.03 15 12 2 2 2.39 2.37 Shallow Line of Pits. _ Lt Deposits. 6 200 0 0.02 11 2 1 2.39 7 8 231 262 0.03 0.03 0.03 14 14 5__ 2 2.35 2.40 Lt. Deposits 9 293 _0 0 0.03 14 3 2.38 Lt. Deposits. 10 325 0.04 0.03 14 2 2.40 11 357 0 0.03 15 2 2.37 Shallow Pitfin . Lt. Deposits. 12 388 0 0.03 12 3 2.37 Lt. De osits. 13 419 0 0.03 14 2 2.38 Lt. Deposits. 14 451 1 00021 14 2 2.38 15 483 1 0 0.03 15 2 2.34 _ Shallow Line of Pits. Lt. Deposits. 16 1 514 1 0 0.02 10 2 2.38 Lt. Deposits 17 545 1 0 0.02 7 2 2.39 18 19 576 608 0 0 0.02 0.02 10 9 2 3 2.39 2.39 20 639 0 0.03 14 2 2.38 Lt. Deposits, 21 670 0 0.03 14 2 2.40 _ 22 701 0 0.03 12 4 2.39 23 732 0 0.02 10 3 2.38 Lt. Deposits. 24 764 0 0.03 16 8 2.37 Shallow Line of Pits L[ Deposits. 25 793 0 0.03 14 2 2.37 _ Lt. Deposits. 26 825 0.04 0.03 14 2 2.40 27 856 0 0.02 8 2 2.40 28 888 0 0.03 14 2 2.39 29 919 0 0.04 18 6 2.37 Shallow Line Corrosion. Lt. De osits. 30 949 0 0.03 14 3 2.38 Lt. Deposits. 31 32 980 1010 0 0 0.05 0.03 23 14 _ 10 1 2.37 Line Corrosion. Lt. De osi ._ __ 33 1042 0.03 0.03 16 7 _2.39 2.37 _ Shallow Pitting, Lt. De osits. _ 34 1071 0 0.03 12 3 2.40 35 36 1102 1134 0 0 0.03 �- 0.01 14 6 3 2 2.39 2.38 Lt. Deposits. 37 1165 1 0.04 0.03 14 2 2.39 38 1196 0.03 0_03 14 3 2.40 39 40 1228 1259 0 0 0.02 0.03 -7 14 2 31 1 2.38 2.40 Lt. De osits. 41 1290 0 0.02 2 2._3.7 Lt. Deposits. 42 1321 0 0.04._ 16 2 2.39 ShallowPittine 43 1353 0 0.0 2 10 2 2.38 44 1384 0 0.02 9 3 2.39 45 46 1415 1447 0 0.03 0.03 0.03 1 15 -3---2.38 2 1 2.40 Lt. Deposits,_ hallow Pitting. D01478 0 0.03 12 2.38 49T 1508 1539 0 003 0.03_] 12 15 3 2 2.37 2.40 Lt. Deposits._ Shallow Line of Pits_ Penetration Body Metal Loss Body Page 1 CASED HOLE Well: 3M-05 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Pipe Description 2.875 in. 6.5 L80 ABM-EUE joint Tabulation Sheet Survey Date: November 4, 2019 Analyst: Waldrop Nom. ID Body Wall Top Depth Bottom Depth 2.441 in. 0.217 in. 39 ft _ 8,561 ft. F -Joint IN(Ft.) j Depth Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Mia I.D. 1 (inJ Comments Damage Profile (% wall) '0 50 100 50 1571 0.03 F0 003 0.03 0.02 14 12--t 1 8 1 3 4 2 T2.39 238 2.38 .Lt. Deposits. Lt. Deposits. _, 51 1603. 52 1634 0.03 3 1666 1 .03 0.03 14 3 2.40 1 1697 0 0.03 0.03 0.03 1 0.04 13 14 18 3_ 2 2 2.40 2.39 2.40 Shallow Pitting. 55 1729_ 56 1760 56.1 1792 _ 00.01 0 0 01111_ 0.01 6. --:::O:±2.31 1 6 1 1 2.41 2.31 1 2.39 _ Pup___ _ Otis FMX SSSV Pu 56.2 1802 56.3 1809 57 1819 0 0.02 1 11 4 2.38 Lt. De osits. 58 1850_. 0 0.02 L 11 3 2.37 Lt. Deposits. 59 1879 1 0 0.03 1 14 4 2.37 -- Lt. Deposits. 60 1910 1 0 0.03 14 2 2.38 Lt. De osits. _ 61 62 63 _ 1942._ 1973 2004 0 0 0 0.03 13 0.03 14 0.04 1 7 2 2 3 2.40 2.41 2.39 Shallow Pitting. 64f672036 2067 2099 0 _0.04__0.03 0 0.03 0.03 16 14 12 4 2 3 2.38 2.39 2.36 Shallow Line of Pits. Lt. DeLposits. _ Lt. De osits 2130 0 0.04 17 61 237 Shallow Line of Pits. Lt. De osits. 69 70 2161 2193 2224 0 0 _ 0 0.03 0_04 0.02 13 _ 17 11 1 _ 5 3 _2.38_ 2.39 1 2.38 LtDe Shallow Pitting. Lt. Derposits. 71 72 73 2256 2287 2319 0 0 0 0.03 0_03 0.04 13_ 14 _ 16 _ 3 2 4 237 _ 2.36 2.39 Lt. De osits. Lt. Dep sits_ Shallow Line Corrosion. 74 2350 0 0.03 13 4 2.37 Lt. Deposits. 75 76 2381 2413 0 0 0.0.3_ 0.03 _73 14 2 6 2,39 2.37 Lt De -sits. 77 2444 0 0.03 12 3 2.38 Lt. Deposits. 78 1_ 79 2475 2506 2536 0 0 0 0.03 0.04 0.05 14_ 20 21 _ 2 6 8 _ 2.i8 2.38 2.38 Lt. Deraosits. Isolated Pitting Lt. D�osits. Line Corrosion. Lt. Deposits. f83 _ 2567 2598 2630 0 0.03 0.04 0.03 0_03 0.03 14 12 14 3 2 3_2.38 2.36 237 Lt. Deposits_ Lt. Delaosits. 84 2661 0 0.03 14 2 2.36 Lt. Deraosits. 85 2692 0 0.02._7_ 2__2.39 86 2724 0 0.03 12_ _3 _2.37 Lt. Deposits__ 2.38 Lt. De osits. 87 2756 0.03 0.03 13 2 88 89_ 90 2787 2819 2850 0 _ _0._ 0 0.02 _ 0.03. 0.03, _ 9 _ _ 12_ 14 3 _t _3 2 2.39 2 .36 2.38 s. - - Lt. D_epo5its_ Lt. Deposits. 91 2882 0 0.03 .. 14 4 I 2.37 Lt. Deposits. 92_ 2914 0 0.03 14 _ �2.3� LtDeposits. 93 2943 0.04 0.03 _i 14 2 94 2975 1 0.03 1 0.03 1 14 1 2.38 Lt. De osits. 95 3007 1 0 0.02 19 31.2.40 96 1 3037 _I_ 0_ 0_02 7 2 __1 2.39 Penetration Body Metal Loss Body Page 2 CASED HOLE Well: u 3M-05 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Pipe Description 2.875 in. 6.5ppf L_80ABM-EUE Tubing Joint Tabulation Sheet Survey Date: November 4, 2019 Analyst: Waldrop i Nom. IC Body Wall Top Depth Bottom Depth 2.441 in. 0.21 7 in. 39 ft. 8,561 ft. J Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damag e Profi elel (%wall) 0 50 100 97 97.1_ 98 _3068 3098 3105 0 0 0 0.03_ 0 0.03 12 0 13 4 0 4 2.35 2.36 2.36 Lt. Deposits. -,. GLM 1 (Latch ®10a)D Lt. De osits. T -I 99 3136 0 0.05 22 6 2.38 Line of Pits. 100 101 102 3165 3196 _ 3228 0 0 0 0.03 0.02 0.03 13 1 10 14 _ 4 2 2.38__ 2.37 2.36 _ Lt. Deposits. Lt. Deposits. 103 _104 3259_ _ 1 32900 E-0 0.03 0.03 12 14 5 _ 3 1 _2.38 2.37 Lt. Deposits 105 3322 1 0.04 0.03 13 2 2.39 - - 106 3354 0.03 0.03 1 133 2.39 107 3384 0 _ 0.03 14 2 2.35 Lt. Deposits.__ 108 3415 0 0.02 1 10 3 2.37 Lt. Deno -sits, 109 3447 0 0.03 13 2 2.36 _ Lt. Deposits. 110 3476 0.03 0.03 14 _2.37 Lt. Deposits. 111 _ 3507 0 0.03 12 4 2.39 112 3539 0 0.03 14 2 2.37 Lt. De osits. 113 3570 1 0.04 0.02 11 3_ 2.36 Lt. 114_ 115 3601 3633 0.03 0 0.03 0.03 14 14 2 4 2.34 2.37 LL Degosits. Lt. Deposits. 116 3664 0.04 0.03 14 2 2.36 Lt. De osits. 117 3695 i 0 0.03 ._15 4 I, 2.37 Shallow Line of Pits. Lt. Degosits. 118 119 3726 3758 0 0 0.03 0.03 14 13 5 3 _2.36 2.37 Lt. Deposits Lt. Del?osits. 120 3789_ 0 0.04 0.04 0.02 0.03 0.03 10 Ti 12 3 3 2 1 2.37 2.35 2.35 Lt. Deposits. Lt. Dosits. Lt. Deposit . 121 3820 122 3851 123 3883 0 0.03 14 2 2.36 Lt. De osits. 124 3914 0 0.02 9 32.35 Lt. Deposits. 125 3945 0.03 0.03 14 2 2.38 Lt, De osits. 126 3977 0 0.03 14 5 2.36 Lt. De osits. 127 4006 -j_ 0 0.02 _ 10 3 2.36 LtDeposits._ _ 128 4036 0 _ 0.03 16 5 2.37 Shallow Line of Pits. Lt. _Deposits. 129 4068 0.04 0.03 14 2 2.37 Lt. Deposits. 130 131 132 4099 4130 1_ 4163 0 0 0.04 0.02-j-9--2 0.03 1 0.02 14 11 2 3 2.40 2.37 2.38 Lt. De�ogits. _ 133 4194 0 0.04 20 8 2.37 Line of Pits. I L De osits. 134 4222 0 _ 0.02 10 3 22 33_ Lt. Deposits. 135_ 136 4254 4285 0 0 0.03 0.03 _ 13 13 4 2 2.36 2.36 Lt. - Lt. De osits. 137 138 139 4316 4349.. 4378 _ 0 _ 0 0 0.03 0.03 0.03 14 13 14 _3 2 3 2.36 2.34 2.36 Lt. D�osits. _. Lt,_De osits. Lt Q----:- 1 140 4409 0 0.03 12 3 2.37 LL n --- e osits. 141 142 4439 4470 0 0 0.02 0.03 11 13 3 3 2.39 2.34 Lt. De osits. 143 4501 0.05 0.03 14 2 2.34 Lt. Deposits. 144 145 4531 _ 4562 0.04 0 0.03 0.03_ 12 14_ 3 _2.37 42.36 Lt. Deposits._____. Lt_De osits. Penetration Body Metal Loss Body Page 3 _ CASED HALE Joint Tabulation Sheet Well: 3M-05 Survey Date: November 4, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc- Pipe ncPipe Description Nom. ID Body Wall Top Depth Bottom Depth 2.875 in. 6.5 ppf L-80 ABM-EUE Tubing _ 2.441 in. 0.217 in. 39 ft 8,561 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss 4% Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 146 4593 0,04 0.06 26 7 _2_36 Line Corrosion. Lt. Dem_ 147 148 _ 4623__x_.0 4653 1 0.03 0.02_ 0.03 11 4 2.37 Lt. Deposits 1 14 2 1 2.38 Lt. Deposits. _ 149 4685 1 0 0.02 10 3 2.37 Lt. Deposits. 150 4715 0.04 0.03 _ 14 1 2.36 Lt. DJ77>eposits. 151 152 4746 4778 0.03 0.04 0.03 0.04 _ 72 4 2.35 Lt. Deposits. 19 2 2.35 Shallow Pitting. Lt. De osits. 153 154 4809 _ 4841 0.04 0 _ 0.03 0.03 14 12 2 4 2.36 2_38 Lt. Deoosits _ _ Lt Deposits 155 4872 0 0.02 10 2 2.37 Lt. Deposits. 156 4903 0 0.03 12 2 2.36 It De osits. 1 157 158 4934 4965 0 0 0.03 0.03 14 14 1 4 2.3.5 2.34 Lt. Deposits _ Lt. Deposits, 159 4996 0.03 0.03 13 1 2.35 Lt. Deposits. 160 50270 _0.04 17 2 1 2.36 Shallow Pit�._t.tDeosits. 761_ X62 5059_ 5090 0.04 0 0.03 0.03 12_ 13 2_ 2 2.36 2.35 Lt. Deeposits. Lt. De osits. 163 764 5123 5154 0.03 1_0.04 0.03_ 0.03 13 7S 1 1 2.32 2.36_. Lt Deposits..... Lt. Deposits 165 5185 0 0.03 13 3 2.34 Lt. De osits. 166 5215 0 0.03 14 2 2.35 Lt. De osits. 767 168 169 5248 5279 5311 0.04 1 0_ 0.04 0.03 1 0.03 0.03 14 14 14 2 3 2 2.36 2.36_ 2.37 _Lt. Deposits. Lt. Deposits. _ Lt. De osits. _ 170 171 5342 _ 5374 0 0.04 0.03-_ 0.03 13 12 3 2 2.34 2.35 Lt Deposits._ LtDeposits. 172 5405 0 0.03 14 3 2.36 Lt. De osits. 173 5436 0 0.03 14 6 2.35 Lt. Deposits, 174 5467 0_ 0.02 _ 11 3 2.34 _ Lt Deposits. 175 5497 0 0.02 9 1 1 2.34 Lt. Deposits. 176 5529 0 0,03 13 3 1 2.34 Lt. De osits. 777 178 5559 5591 _ 0 _ 0 0.02 0.03 __ 11 12 2 3 2.35 _2.37 Lt. Dep_osits.__ _ Lt�aosits. 779 5622 0.04 0.03 13 2 2.36 Lt. De osits. _ 180 181 182 5654 5684 5716 0 _.... 0.04 0 0.02 0.03 0.03 11 14 163 3 2 2.34 2.34 2.31 Lt. De osits. _ _Lt Deposits,__ Shallow Line of Pits. Lt. De osits. 182.1 5748 0 0 0 0 2.31 GLM 2 Latch C 3:00 183 784 185 5754 5785 5817 0.04_. 0_ 0.04 0.03 0.03 0.03 14 13 13 3 4 3 2.37 2_37 _ 2.36 Lt Deposits. Lt. Deposits Lt. Deposits. 186 5848 0.04 0.03 14 3 2.37 Lt. Deoosits 187 _ 788 5880 5910 1 0 _ 0 0.03 0.03 12 14 2 4 2.35 _ 2.39 Lt Deposits. 189 5938 0 0.03 12 4 2.36 Lt. De osits. 190 191 5971 6007 1 0.04 0 0.03 0.03 14 12 3 3 2.37 2.38 Lt. Deposits. _. -. _ Lt. -Deposits 192 6032 0 0.03 12 2 2.35 Lt. Deposits. 193 6064 0 0.03 13 2.26 Deosits. 194 6095 0. 0.03_ 14 3 2.31 Lt. Deposits - Penetration Body Metal Loss Body Page 4 =_ CASED HOLE Well: 3M-05 Field: Kuparuk Conoc Company: ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: November 4, 2019 Analyst: Waldrop - -- -- Pipe Description 2.875 in. 6.5 ppf L-80 ABM-EUE Tubing Nom. ID Body Wall Top Depth 2.441 in. 0.217 in. 39 ft Bottom Depth 8,561 ft._ Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. Metal % Loss % Min. I.D. (in.) Comments damage Profile (% wall) 0 50 100 _ 195 _ 6126 0.04 0.03 x_14 1 ,.2_31 Lt. _Dettosits 196 6158 0 0.0314 2 2.32 Lt. De�osits.-_ -, - - -- 197 6189 0 0.03 12 2 2.36 LL Deposits. - -- 198 6221 0 0.02 11 2 2.33 Lt. Deposits. 199 6251 0_03 0.03 12 2 2.34 Lt. Densits 200 201 _6284 6315 1.004 0.04 0.03 0.03 14 15 3 4 2.33 2.31 _ Lt. DeQosits. _ Shallow Line of Pits. Lt. Deposits.. 202 203 204 6346 6378 6410 0 1 0 0 0.03 0.03 0.02 14 12 9 3 2 2 2Z 2 32_ 2.35 De osits._______ . Lt. Deposits _ Lt. Deposits. 205 6441 0 0.03 14 3 233 Lt. De osits. 206 6472 _0_ 0.03 1_2 2 2.30 Lt. De_posits._ 207 6504 0 0.02 10 2-2.3 Lt. Deposits. 208 6536 0 0.03 14 2 2.33 Lt. De osits. 209 _ 210 - 6567 6599 _ _ 0 0 _ 0.03 .0.02 __ 14 9 2 1 2.35 2.32 _ Lt. Deposits. Lt. De osits.-_ 211 6629 0 0.03 12 3 2.32 Lt. De osits. 2 _22 6661 _ 0 0.03 16 2 1.2.33 Shallow Pittin . Lt. De osits.__ 213 6691 0 0.03 12 2 2.32 Lt. Deposits 214 6723 0 0.03 12 2 2.33 ______ Lt. De osits. 215 6755 0 0.03 12 3 2.33 Lt. De osits. 216 217 6787 6817 1 0 0 0.03 0.03 13 13 6 2.37 Lt. De osits. 218 6850 0 0.03 13 2 2.36 Lt. De osits. _219 6880 __0 0_03 13 3 2 35 Lt. osits. 220 6911 1 0 0.03. 12 2 2.34 Lt. De osits. 221 6944 0 0.03 14 i 2.35 Lt. De osits. 222 6975 0 0.03 13 4 2.33 Lt. De 'SITS. 223 7007 - 0 0.03 13 2_ 2.34 Lt. DeDosits. 224 703- 7 0 0.03 13 2 2.33 Lt. Deposits. 225 7069 0 0.03 12 2 2.32 Lt. Deposits. 226 227 228 7099 7133 7164 0 0 0 0.03 0_03 _ 0.03 14 12 1 _3 3 3 2.33 2.31 2.32 epo Lt. Dsits. Lt. Deposits. Lt. Deposits. _229 7195 0 0.03 13 1 _, 2.35 Lt Dep_osits._- 230 7227 0 0.03_ 12 2 _2.35 Lt, Deposits. 231 7259 0 0.03 14 3 2.32 It Deposits. 232 7290 0 0.03 14 2 2.29 De osits. 232.1 _7420 0 0 0 0 1 2.32 CLM 3 Latch C 2:00)_ 233 234 7328 7359 0 _ 0 0.03 0.03 12 14 1 2 2.33 2.33 Lt. Deaosits.__ Lt. Deposits. �2357391 236 237 t0 7423 _10 7453 _ 0 0.03 _0.02 0.03 15 11 13 3 2 i 2.34 2.33 2.31 Shallow Pit ng. Lt. De_posits.-_____, _Lt_Deiposits. Lt. Deposits. 238 7484 0.03 0.03 14 4 2.35Lt. De 'sits. 239 240 75 1 6 7548 _ 0 0 0.02 0.02 11 _ 11 1 2 2.31 2.33 _Lt. )osits. Lt. De 'sits. 241 7580 0 0.03 12 2 2.31 Lt. De osits. F242 _ 243 7611 7642 0 0 0.02 0.w-113 11 2 1 2 , 2.28 2.33 Deus. Lt. Deposits. 'Penetration Body Metal Loss Body Page 5 CASED HOLE Joint Tabulation Sheet Well: 3M-05 Survey Date: November 4, 2019 Field: Kuparuk Analyst: Waldrop CompanyConocoPhillips Alaska, Inc. Pipe Description - Nom. ID Body Wall Top Depth Bottom Depth 2.875 in. 6.5 ppf L-80 ABM-EUE Tubing 2.441 in. 0.217 in. 39 ft_ 8,561 ft. Joint No. Jt. DepthT (Ft.) Pen. I Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. _ (in.) Comments Damage Profile (% wall) 0 50 100 244 7674 0 0 0 0,02 0.03 0.02 10 13 11 2 2 2 2.32_Lt. 2.28 2.34 De)osits_ _ Des__ _ Lt. Deposits. 245 7705 _ 246 7737 247 7767 0.03 0.03 1 14 4 2.34 Lt. Deposits. 248 7800 0 0.02 9 2 2.34 It. Deno sits, 248.1 7833 0 0 0_ 0.02 0 11 0 1 2.35 2.34 GLM 4Latch0 12M0 Lt. Deposits. 249 7838 250 7870 _ 0_ 0.03 14 4 2.32 Lt._Penosits_ 251 7900 0 0.03 13 2 2.34 Lt. Deposits, 252 7932 0 0.02 11 2 2.31 Lt. Deposits 253 7965 1 0 0.03 12 2 2.33 Lt. Deposits. 254 7995 0 0 _ 0.02 0.02 _ 8_1 10 2 2.32 2.34 Lt. Deposits.__-_ _ Lt. De .sits. 255 8027 256 8059 0 0. j 2.34 Lt. Deposits. 257 8090100 0.03 1 12 i_! 2.35 Lt. Deposits. 258 8f22 I 0 0.02 11 2 2.35 Lt.Dee .sits. 259 8154 0 0.02 11 1 2.35 Lt. De .sits. 260 261 8185 8217 0 0.02 10 2 2.35 Lt. De .sits. 0 261.1 8248 0 0 0 0 2.34 GLM 5 Latch 7:00 262 8253 0 0.03 12 2 2.33 Lt. Deposits. 263 8286 _ 0 0.0.2 _9 1 2.34_ _ Lt. De osits. __ 265 831 6_._ 8349 0 0 0.03 0.02 12 10 3 1 2_35 2.32 Lt. Deposits. Lt. De osi s. 266 8380 0 0.02 9 _1 _ 2_33_. Lt. Deposits. _ 267_ 8411 0.04 0.04 18 5 2.36 _ Shallow Line of Pits. Lt Deposits. 268 8440 0 0.03 14 2 235 Lt. De osits. 268.1 8474 0.03 0.02 8 0 2.36 Pop Lt. De osits. 268.2 268.3 8479 8487 0 0 0 0.02 0 11 0 0 2.34 2.36 GLM6(Latch Q 9-301 Pu Lt. De .sits. 269 8493 0.04 0.03 14 4 2.35 Lt. De 269_.1 8523 269.2 8529 0 0 0.02 _ 0 _ 7 0 0 0 2.37 2.27 _osits. _ Pu Lt. Deposits. Camco PBR Penetration Body Metal Loss Body Page 6 Cross-sectional Illustration Survey Date: _P& CASED i Tool Size: HOLE Well: 3M-05 Field: Kuparuk Company: Conoco Phillips Alaska, Inc. Country: USA Tubing: _ 2.875 in. 6.5 ppf L-80 ABM-EUE Cross-sectional Illustration Survey Date: November 4, 2019 Tool Type: UW MFC 24 No. 10020078 Tool Size: 1.69 inches. No, of Fingers: 24 Cross Section for Joint 146 at depth 4,603.100 ft. Tool speed = 54 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 95% Tool deviation = 53° Finger = 24 Penetration = Line Corrosion ___ CASED HOLE Cross-sectional Illustration Well: 3M-05 Survey Date: November 4, 2019 Field: Kuparuk Tool Type: UW MFC 24 No. 10020078 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 _ Tubing: _ 2.875 in. 6.5 ppf L-80 ABM-EUE Analyst Waldrop Cross Section for Joint 31 at depth 1,005.413 ft. Tool speed = 54 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 93% Tool deviation = 19° Finger = 16 Penetration = 0.050 in. Line Corrosion 0.05 in. = 23% Wall Penetration HIGH SIDE = UP ICASED HOLE Well: 3M-05 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing: 2.875 in. 6.5 onf L-80 Af Cross-sectional Illustration Survey Date: November 4, 2019 Tool Type: UW MFC 24 No. 10020078 Tool Size: 1.69 inches No. of Fingers: 24 Analyst: — Wald- - - -- – - -__ --J Cross Section for Joint 193 at depth 6,086.843 ft. Tool speed = 54 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 99% Tool deviation = 5W Minimum I.D. = 2.256 in. Deposits Minimum I.D. = 2.26 in. HIGH SIDE = UP =_ CASED HOLE Well: 3M-05 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing: 2.875 in. 6.5 ppf L-80 ABM-EUE Cross-sectional Illustration Survey Date: November 4, 2019 Tool Type: UW MFC 24 No. 10020078 Tool Size: 1.69 inches No. of Fingers: 24 Analyst:.. __ Waldrop ---- Cross Section for Joint 245 at depth 7,708.973 ft. Tool speed = 54 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area= 100% Tool deviation = 52° Minimum I.D. = 2.280 in. Deposits Minimum I.D. = 2.28 in. HIGH SIDE = UP KLaP PROD WELLNAME 3M-05 WELLBORE 3M-05 ConocoPhillips Alaska, Inc. Web 14utes Max Angle 1K TD Field Name Wellbore APINWI KUPARUKRIVERUNIT 500292170600 Wellbore StaPus PROD nd (`) 2.78 ea0 (ttK8) N 7,100.00 net arm lftKBj 9,110.0 Comment SSSV: TRDP 240 -Fm-2T-(Wm) Date 12110/2016 Annotation Last WO: End Data K"rd (ft) Rig Release Date 7/10/1992 39.61 3/24/1987 3MD5, 8/13120197:06:37 AM Last Tag Vedlrel u:M1ematic(actua0 Annotation I Depth(II End Date wellbore Lary and By ...__................ ......_...........-..-_._..._... __...__......._------._...._.__ HANGER. 330 GONIRICTOP; 3a.0.115A SAFETY VLV', 1:965 GAB LIFT; 3,003.3 SURFACE; 37.0-4,351.4-, GAS UFT; 5,744., GAB LIFT. 7,919.8 GAS LIFT; 7,830.a GAS aFP, 8,24c6 GAS UFT; 8,479p PBfl; 8,5392 pnckER; e,559s NIPPLE; e,67e2 803:8,549.9 RPERF; 8,659,04ea2.0 IPERF: 8,672 0-8,674. D IPERF. a,BB2.0.9,]20.0 IPERF; A686.0-8.718.0 Last Tag: 8,743.0 8/1N2019 3M -OS jhansen8 Last Rev Reason Annotation End Date W¢Ilppro Wet III By Rev Reason: T3q, SBHP 3I1J2019 13M-05 jhansen8 Casing. Strings: ... ,;. ..„.. Casing Deacdpfion CONDUCTOR 16 be (in) ID (in) 16.06 Top IRKS) 38.0 Set Depth IRKS) I Set 115.0 1115.0 Depth OVDI... IMLen (I... 162.50 Grade H -4D Top Thread WELDED Casing Descrlption SURFACE OD (in) 9518 M On) 8.92 Tep (RKB) 37.0 Set Depth (RKB) ISO 4,351.4 13,419.3 Depth (ND)... WHLen (1... 36.00 Gmtle J-55 Top Thread BTC Casing Deacdpdon PRODUCTION OV en) 7 ID1ia) 6.28 Top ((tile) 35.0 Set Depth (RKB) 150 8,948.2 16,355.9 DepW (TVD)... I WtlLen (I... 26.00 Grade I b55 Top Thread BTC L Tubing Stn"h 5 Tubing Description TUBING String Ma._ ID 27/8 (ini 24d Tap (RKB) 330 Set Depth is . 8,5906 Set Depth (ND) (-T 6,1178 Wt (01n1 680 Grade L-80 Top Connection ABM-EUE Completion Details _ Top (RKB) Top(TVD) Top Incl [RKB) (°) Rem Dos Nominal Co. ID (in) 33.0 330 D.03 HANGER VETCO GRAY 27/8"Tubing Header w/double pin Pup 2.875 1,79 .6 1,fi61.7 4300 SAFETY VLV OTIS'FM%' SSSV 4.76" OD, 2.32" ID 2320 8,529.2 6,077.0 48.64 PER CAMCO 2 Otic 4.750" OD Barrel 5.750" OD skirt & b1m, 2.312 slick 3.250" OD slick stick, 2.312" ID 8,5593 6,096.9 48.45 PACKER CAMCO 2 7/8" HRP -I -SP Rett. Pkr 48K pull or Ret release 5.987" 2.347 OD, 2.347" ID 8,578.2 6,109.5 48.33 NIPPLE OAMGD 2716"D -Nipple 2,260" ID 2.250 8,589.9 6.117.3 48.26 SOS Raker27/8"Shear out Sub(Sheared). TTL ELMD 8562'SWS 2.441 3!23!1187 Other In Hole.(Wlreline retrievable plugs, valves, pumps, fish, etc.) Top(TVD) Top Incl Top (RKB) (RKB) (°) Dee Com Run Date ID (In) e,e0t0 6,257.9 48.24 FISH 1 1/2"GLV Empty PxkeC Fell doymh0le 712711992 7/27/1992 0.000 8.807.0 6.261.9 4824 FISH 1 12" OV Empry Pocket; Fell w Relhole 4/11+1993 4+11/1993 1 0.000 Perforations: & $lots ..... - _.. Shot Dens Top rND) Bim 1ND) (sM1otsaa Top (RKB) Stm(RKB) (ftKe) (RKB) Linked Zona Data 1 Typo Co. 8,666.0 8,682.0 6,168.0 6,178.5 A-2, W-05 3119/1992 5.0 RPERF 2 116" Dyne Strip, 0 deg. ph 8,572A 8,676.0 6,172.0 6,174.6 7-2,3M-05 7/511987 1.0 IPERF 4" Csg Gun, 120 deg. ph 8,682.0 8,720.0 6,178.6 6203.9 A-2, A- , 3M-05 3119!1992 6.0 IPERF 2118" Dyna Strip, 0 deg, ph 8,686.0 8,718.0 6,181.3 8,202.6 A-1, 3M-05 71511987 1.0 (PERF 4" Csg Gun, 120 deg. ph 8,728.0 8,731.0 6,209.3 6,211.3 A -1,3M-06 7/5/1987 1.0 IPERF 4" Csg Gun, 120 deg. ph 8,736.0 8,739.0 6,214.6 6,216.8 A-1, 3M-05 7/5/1987 1 1.0 1 PERF 4" Csg Gun, 120 deg, ph Mandrel Inserts at ail on N Top (RKBI Top (TVD) IRKS) I Make Model 00 (Inl SON Valve Type Latch Port Type I Size (In) TRO Run (psi) Run Data Co. 1 3,093.3 2,602.5 MMH FMHO 1 GAS LIFT GLV BKS 0.125 1,291.0 11/28/2005 2 5,744.1 4,305.5 MMH FMHO 1 GAS LIFT GLV BK -5 0.188 1,362.0 11/28/2005 3 7,319.8 5,303.4 RIM FMHO d GAS LIFT OV RK -5 0.188 0.0 112812005 4 7,830.8 5,625.2 MMH FMHO 1 GAS LIFT DMY BTM 0.000 0.0 11/28/2005 5 8,247.6 5,892.5 MMH FMHO 1 GAS LIFT DMV SK -5 0.000 0.0 11/24/1995 6 9,479.0 6,043.9 MMH FMHO 11/2 GAS LIFT IOMY RK 0,000 0.0 8/27/2003 Notes; General & Safety _. End Date Annotation 7/15/2039 NOTE: IAx OACOMMUNICATION ConocoPhllips P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 IREC€IVED APR 0 ~`~ 201Q ~~stca ail & Gas Ccx~s. Gemm Anehvr~ct~ March 31, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~ ~ ~- gas 3 ~ i a ~.. ~,~'.~> Dear Mr. Dan Seaniount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL)7. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 2 and 21, 2010. The corrosion inhibitor/sealant was pumped March 27, 28 and 29, 2010. The attached spreadsheet presents the well name, t`op of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, MJ Loveland 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 3/31/10 3e ~R ~r ~r. ~N zi z_i znn zn ~ so ~en~e Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-02 5002921431.0000 1852050 Surface Na 26" n/a 4.25 3/29/2010 3A-04 50029214330000 1852070 SF n/a 26" n/a 4.25 3/29/2010 3A-07 50029214440000 1852230 SF Na 25" n/a 4.25 3/29/2010 3A-16 50029214920000 1852840 SF n/a 23" n/a 3.4 3/29/2010 3B-10 50029213660000 1851140 6'6" Na 6'6" n/a 25.5 3/28/2010 3C-11 50029213570000 1851020 SF n/a 25" n/a 4.25 3/27/2010 3G-08 50103201280000 1900650 SF 0.65 27" 3/2/10 5.52 3/28/2010 3G-09 50103201290000 1900670 SF 0.60 22" 3/2/10 4.67 3/28/2010 3G-22 50103201470000 1901420 SF n/a 22" n/a 4.25 3/28/2010 3H-01 50103200840000 1871100 SF Na 21" n/a 4.25 3/28/2010 3H-03 50103200850000 1871110 17" 0.40 8" 3/21/10 1.7 3/28/2010 3H-146 50103200920200 2050210 SF n/a 23" n/a 3.4 3/29/2010 31-02 50029215150000 1853080 SF n/a 22" Na 2.97 3/29/2010 31-10 50029219340000 1890370 39' 3.50 24" 3/21/10 3.4 3/29/2010 3J-04 50029214000000 1851650 SF n/a 23" n/a 3.4 3/28/2010 3J-14 50029214960000 1852880 SF n/a 25" n/a 4.67 3/28/2010 3J-15 50029214970000 1852890 SF Na 22" Na 3.4 3/28/2010 3M-05 50029217060000 1870250 SF Na 21" n/a 3.4 3!2912010 3M-07 50029217080000 1870270 SF n/a 22" n/a 4.25 3/29!2010 30-09 50029218250000 1880610 SF Na 23" n/a 4.25 3/27/2010 30-16A 50029217960100 1880430 SF n/a 22" Na 3.52 3/27/2010 3R-10A 50029222530100 1920310 SF n/a 21" n/a 4.25 3/27/2010 3R-11 D 50029222480000 1920160 SF n/a 17" Na 3.25 3/27/2010 3R-15 50029222580000 1920340 SF Na 24" n/a 3.82 3/27/2010 3R-19 50029222690000 1920460 1" n/a 21" n/a 5.1 3/27/2010 3R-25 50029226220000 1951810 SF n/a 21" n/a 5.52 3/27/2010 MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK Plugging 5. Type of Well: Development X Exploratory _ Stratigraphic _ 99510 Service -- Location of well at surface 0 F~ t Gi['"\!A 204' FNL, 1703' FEL, Sec 25, T13N, R8E, UM · i~ At top of productive interval 1817' FNL, 1379' FEL, Sec 30, T13N, R9E, UM At effective depth 1826' FNL, 1220' FEL, Sec 30, T13N, R9E, UM At total depth 1835' FNL, 1033' FEL, Sec 30, T13N, R9E, UM Present well condition summary Total Depth: measured true vertical 9110 6462 feet feet 12. Perforate Other 6. Datum elevation (DF or KB) RKB 64 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-05 9. Permit number/approval number 87-25 10. APl number 50-029-21706 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 8 8 5 9 true vertical 6295 feet feet Junk (measured) 2 1.5" GLV's @ 8859' Casing Length Structural Conductor 8 0' Surface 4 3 1 4' Intermediate Production 8 9 1 3' Liner Perforation depth: measured 8672'-8676', true vertical 6171'-6173', Size 16" 9.625" 7" Cemented Measured depth True vertical depth 198SXCSII 115' 115' 1200 Sx CS III & 4351' 341 8' 325 Sx Class G w/100 Sx CS II Top Job 400 Sx Class G & 8948' 6355' 175 Sx CS I 8686'-8718', 8728'-8731' 6180'-6201', 6208'-6210' Tubing (size, grade, and measured depth) 2 7/8", 6.5#, L-80 @ 8591' Packers and SSSV (type and measured depth) PKR: Camco HRP-I-SP @ 8559'; SSSV: Otis FMX @ 1797' 8736'-8738', 8666'-8720' 6213'-6214', 6167'-6202' RECEIVED 13. Stimulation or cement squeeze summary ~y 0 7 1995 Stimulate "A" Sand interval on 11/27/95. Intervals treated (measured)-.,,~,a~&~ ,C0a,$. IC0m~ 8672'-8676' 8686'-8718' 8728'-8731' 8736'-8738' 8666' 8/~,'~'-''----- Treatment description including volumes used and final pressure Pumped 164 Mlbs of 12/18 & 20/40 ceramic proppant into formation, fp was 7200 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1029 605 10 1124 180 Subsequent to operation 1 6 9 5 1059 17 656 199 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Wells Superintendant Date SUBMIT'IN D~JPLICATE ARCO Alaska, Inc. I~dPARUK RIVER UNIT --~, WELL SERVICE REPORT ~' K1(3M-05(W4-6)) WELL JOB SCOPE JOB NUMBER 3M-05 FRAC, FRAC SUPPORT 1 120951342.1 DATE DAILY WORK UNIT NUMBER 1 1/27/95 "A" SAND FRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 2 (~) Yes ~'~ No (~) Yes (~ No DS-YOAKUM CHANEY ESTIMATE 998501 23ODS36ML $140,727 $148,553 ,. Initial Tbcl Press Final Tbcl Press Initial Inner Ann Final Inner Ann I Initial Out~'/An~ '[ Final Ou.t, ef'~ 900 PSI 500 PS! 1876 PSI 1500 PSII 50 PSII ~//400 PSI DAILY SUMMARY I "A" SAN~ ~.AC COM,LEYE. SCREENED OUT TOP TO BTM. 164000 LBS OF PROPPANT BEHIND PIPE WITH 8.1# @ PERFS. LEFT 1 13200 LBS OF SAND IN THE TBG. TOTAL SLURRY VOLUME PUMPED WAS 1717 BBLS. MAX PSI WAS 7200 PSI. TIME LOG ENTRY o 06:30 MIRU DOWELL EQUIP, HOT OIL UNIT, AND VAC TRKS. HELD SFETY MTG( 14 ON LOCATION ). HOU TIED IN TO 7' HARD LINE AND P'I'D TO 4000 PSI. SET TREESAVER AND PT'D HI-PRESS LINES TO 8800 PSI. 08:30 09:20 PUMP CONDITION 40# DELAY-XL GW AND STRAIGHT WATER @ 20 BPM, VOLUME PUMPED 300 BBLS, PROPPANT USED 2114 LBS OF 20/40, MAX PSI 7350 PSI, ENDING PSI 5450 PSI, ISIP 2151 PSI. S/D FOR CLOSURE. 10:10 PUMP DATAFRAC 40~ DELAY-XL GW AND STRAIGHT WATER @ 20 BPM, VOLUME PUMPED 202 BBLS, MAX PSI 5500 PSI, ENDING PSI 5280 PSI. ISIP 2170 PSI. S/D FOR CLOSURE. 11:40 PUMP FRAC 40# DELAY-XL GW @ 20BPM, VOLUME PUMPED 1215 BBLS, MAX PSI AND ENDING PSI 7200 PSI. SCREENED OUT TOP TO BTM. PROPPANT USED 177020 LBS(167720 LBS OF 12/18 PROPPANT AND 9300 LBS OF 20/40 PROPPANT). ABLE TO GET 164(X)0 LBS OF PROPPANT BEHIND PIPE WITH 8.1# @ PERFS. LEFT 13200 LBS OF SAND IN THE TBG. TOTAL SLURRY VOLUME PUMPED WAS 1717 BBLS. 13:00 STARTED TO CLEAR LINES AND RD EQUIP. DEPRESSURED 7" TO 1500 PSI AND RD HOU. REMOVED TREESAVER(LOST RUBBER PART OF CUPS IN WELL), RU HOU TO FLOWLINE AND FREEZE PROTECTED WITH DIESEL. 15:00 RD COMPLETED. SECURED WELL AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE APC-LABOR APC-PUMPING APC-TRUCKING DIESEL DOWELL-STIMULATION HALLIBURTON LI'I-I'LE RED HOT OIL TOTAL FIELD ESTIMATE DAILY COSTI ACCUM TOTAL I REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown Stimulate X Pull tubing Alter casing Repair well 2. Name of Operator 5. Type ~f Well: Development X ARCO Alaska. Irl~, Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Ser~ce _ 4. Location of well at surface 1204' FNL, 1703' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 1817' FNL, 3901' FWL, Sec. 30, T13N, At effective depth 1826' FNL, 4060' FWL, Sec. 30, T13N, At total depth 1835' FNL, 4247' FWL' Sec. 30, T13N~ Present well condition summary Total Depth: 12. Plugging Perforate _ Other I 6. Datum elevation (DF or KB) I 64' RKB 7. or Property name Unit feet R9E, UM R9E, UM R9E~ UM measured 91 1 0' feet true vertical 6462' feet Plugs (measured) Kuparuk River Unit 8. Well number 3M-05 9. Permit number/approval number 67-25 10. APl number S0-029-21706 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8859' feet true vertical 6295' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 4314' 9 5/8" 8913' 7" measured 8672-'8676', 8682'-8720' true vertical 6171'-6173°, 6177'-62020 Cemented Measured depth 198 SX CS II 115' 1200 Sx CS III & 4351' 325 Sx Class G, 100 sx CS II TOP JOB 400 Sx Class G 8 9 4 8' 175 sx CS I 8686'~8718', 8728'-8731', 8736'-8738', 6180'-6201', 6208'-6210', 6213'-6214', True vertical depth 115' 3418' 6355' 8666'-8682', 6167'-6177', Tubing (size, grade, and measured depth) 2 7/8" 6.5#, L-80, 8591' Packers and SSSV (type and measured depth) SSSV: Otis FMX SSSV, 1797'~ Packer: Camco HRP-1-SP~ 8559' 13. Stimulation or cement squeeze summary A-Sand Water Gel Fracture Treatment Intervals treated (measured) 6940', 6942', 6944', 6948', 6954'-6992' Treatment description including volumes used and final pressure Pumped 34MIbs in perfs-16/20 Carbolite followed by 12/18 Carbolite (see Well Service Report) 14. Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Alaska 0il & 6as Cons. Anchorage Prior to well operation 650 450 -0- 1200 60 Subsequent to operation 9 0 0 3 5 0 3 8 1 2 0 0 15. Attachments ! 16. Status of well classification as: Copies of Logs and Surveys run m I Water Injector __ Daily Report of Well Operations X Oil ~X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the' best of my I~nowledge. Service 60 Form 10-404 Rev 09/12/90 Ti~e Kuparuk Petroleum Engineer Date ~__~4/~ ?-- SUBMIT IN DUPLICATE ~rt~.,u ~lasKa, inc. - ~ Subsidiary of Atlantic Richfield Corn: ~' *WELL 1 PBDT CONTRACTOR REMARKS FIELD- DISTRICT- STATE KP,,U OPERATION AT REPORT TIME WELL SERVICE REPOF IDAYS / DATE 4 000 es, 3 z 75 :~4oo sc.E.~.~j o~- RECFiVt D S E P 2 B I~,92 Alaska Oil & Gas Cons. Ancnorag~ I-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W..ther ] T. mP.R.port 'F I Chill F'ct ivl'lbllltyOr"F mil. [ Wind Vel. Signed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Pull tubing x Alter casing Stimulate Repair well Plugging __ Perforate _ Other Pull 2-7/8" J-55/Re-run .L.:80 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well' Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1204' FNL, 1703' FEL, SEC 25, T13N, R8E, UM At top of productive interval 1817' FNL, 3901' FWL, SEC 30 , T13N, R9E, UM At effective depth 1826' FNL, 4060' FWL, SEC 30, T13N, R9E, UM At total depth 1835' FNL, 4247' FWL, SEC 30, T13N, R9E, UM 6. Datum elevation (DF or KB) RKB 64', PAD 27' 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-05 9. Permit numbedapproval number 87-~5 lConserv Order 10. APl number 50-029-21706 11. Field/Pool Kuparuk River Oil Pool #261 12. Present well condition summa~ Total Depth: measured -true vertical ,, 91 1 0' feet Plugs (measured) 6462' feet Effective depth: measured 8859' feet Junk (measured) true vertical 6295' feet 13. 14. Casing Structural Conductor Surface Intermediate Production Length Size Cemented Measured depth 80' 16" 198 SXCSII 115' 4314' 9-5/8" 8913' 7" True vertical depth 115' Liner Perforation depth: measured 1200 SX CS III 4351' 3418' & 325 SX CLASS G, 100 SX CS II TOP JOB 400 SX CLASS G 8 9 4 8' 6 3 5 5' &175 SX CS I 8672'-8676', 8686'-8718', 8728'-8731', 8736'-8738' MD @ 1 SPF, 8666'-8682', 8682'-8720' @ 6 SPF MD true vertical 6171'-6173', 6180'-6201', 6208'-6210', 6213'-6214' TVD Tubing (size, grade, and measured depth) 2-7/8"6.5# L-80 @ 8591' Packers and SSSV (type and measured depth) CAMCO HRP-I-SP RETR PKR @ 8559'~ OTIS FMX SSSV @ 1797' MD Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 6167'-6177", 6177'-6202' TVD JUL 2 9 1992 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation 15. Attachments ~16. Status of well classification as: Copies of Logs and Surveys run -- I Water Injector __ Daily Report of Well Operations ~ Oil ..X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Tubing Pressure Service Title Area Drilling Engineer sDUaBt;.7 N~D~~p L~i C~AT E ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 3M-5 NORTH SLOPE BOROUGH KUPARUK RIVER KUPARUK RIVER 50-029-21706 87-25 ACCEPT: 07/01/92 01:07 SPUD: RELEASE: 07/10/92 08:07 OPERATION: DRLG RIG: NONE WO/C RIG: NORDIC 1 07/01/92 ( 1) TD: 0 PB: 8859 07/02/92 (2) TD: 0 PB: 8859 07/03/92 (3) TD: 0 PB: 8859 07/04/92 (4) TD: 0 PB: 8859 PREP TO DISPLACE TO SEAWATER MW: 0.0 Diesel ACCEPT RIG @ 0100, 7/1/92 UNLOAD SEAWATER INTO PITS. HOOK UP HARD LINE TO FLOWLINE AND TANKS. PRIME PUMP AND LINES. TEST TO 3000 PSI. PULL BVP. RU TO KILL WELL. CIRC SEAWATER DOWN HARD LINE TO OUTSIDE TANK TO CHECK FOR LEAKS. TIGHTENED LAEKS. CIRC. 11.0 PPB BRINE MW:ll.0 NaCl/Br SITP=SICP= 1000 PSI. BLEED 10 BBL DIESEL OFF ANNULUS. P (TUB)=150 PSI P (CAS)=0 PSI. CIRC. 55 BBL SEAWETER THRU OPEN GLM @ 7623'.CIRC. AND MONITOR PRESSURE. SITP=SICP=750 PSI. KILL WELL. CIRC. 53.5 BBL 11.0 PPB BRINE. CONTINUE CIRC 10.4 PPG BRINE UNTIL 10.9 PPB RETURNS. WELL DEAD. FREEZE PROTECT. SET BPV. TEST BOPE ANNULAR AND EQUIP TO 3000. TEST WITNESSED BY AOGCC INSPECTOR HAROLD HAWKINS. PULL VECO GRAY HANGER, PULLED FREE @ 68K ~, PU WEIGHT 48K#. CIRCULATE 11.0 PPB BRINE. 11 BBL HOLE FILL. PREP POH W/ IMPRESSION BLOCK MW:ll.0 NaCl/Br CIRC BRINE ONCE AROUND. POH AND LD 270 JTS 2-7/8 TBG. LIH PIN END OF JT #260, 4' PUP, OEJ, PACKER, AND TAILPIPE. RECOVERED 29 SS BANDS. NORM TEST EQUIP, OK. CLEAR PIPE SHED & RD FOSTER TONGS. CALL FISHERMAN AND TOOLS. RU TO RUN DP. STRAP AND TALLY DP AND DC. STRAP AND CALIPER FTA#1 : 5.75 LIB, CIRC SUB, BUMPER SUB, AND JARS. CHANGE AND TEST 3.5 RAMS. SET WEAR BUSHING. MU FTA#I. RIH ON 4.75 DC 3.5 DP TO 8433. CIRC BU. RD CIRC LINES. RIH AND TAG FISH AT 8502. SET 26K TO GET IMPRESSION. LR 2-3 BBL/HR. PREP POH W/ FTA#3 MW:ll.0 NaCl/Br SERVICE RIG. POH W/ FTA #1. EXAMINE LIB. LOAD TRISTATE FISHING TOOLS. MU FTA #2. RIH-TAG FISH AT 8502 AND WORK DOWN 3'. MU, TEST, AND SERVICE KELLY. WASHOVER FISH F/ 8502-8525. CIRC BU. BLOW DOWN AND STAND BACK KELLY. POH W/ FTA #2. BREAKOUT AND LD SHOE. MU FTA #3. RIH AND WORK OVER FISH F/8502-8509. LD 1 JT DP. CIRC BU. WELL : 3M-5 OPERATION: RIG : NORDIC 1 PAGE: 2 07/05/92 (5) TD: 0 PB: 8859 07/06/92 (6) TD: 0 PB: 8859 07/07/92 ( 7) TD: 0 PB: 8859 07/08/92 ( 8) TD: 0 PB: 8859 07/09/92 ( 9) TD: 0 PB: 8859 RIH W/ JUNK MILL MW:ll.0 NaCl/Br SERVICE RIG. POH W/ FTA #3. SAC 50' DL. GRAPPLE BROKE AND LIH. ORDER OUT TOOLS FROM TRISTATE. MU FTA #4. RIH. WORK OVER FISH F/8502-8508. MU KELLY. CIRC AND WORK OVER FISH TO 8512. CIRC BU. BLOW DOWN AND STAND BACK KELLY. POH W/ FTA #4. GRAPPLE BROKE AND LIH. LD FTA #4. MU BITSUB AND 2 BOOR BASKETS. CALL OUT MILL, POLYMER, AND TOOLS FROM TRISTATE. MU FTA#5. RIH. DEFOAM/DEGAS SURF PIT MW:ll.0 NaCl/Br SERVICE RIG. RIH W/ FTA#5. MU AND SERV KELLY. TAG FISH AT 8502. BREAK CIRC AND LOAD DP W/ VISC BRINE. MILL FISH F/ 8502-8507. CIRC BU. BLOW DOWN AND STAND BACK KELLY. PULLING WET-MIX AND PUMP DRY JOB. POH W/ FTA#5. CLEAN OUT JUNK BASKET. LD MILL. MU FTA#6. RIH, PU KELLY. WASH OVER OEJ BARREL F/ 8507-8523. NO FLOW. PACKER IS FALLEN. CIRC BU. 10 BBL GAIN. SHUT-IN AND SHUT DOWN TO DEGAS/DEFOAM SURFACE VOLUME. POH W/ FTA #7 MW:ll.0 NaCl/Br DEFOAM AND DEGAS SURFACE VOLUME. BREAK CIRC. LOAD DP W/ 11.0 PPG BRINE. SHUT-IN AND MONITOR WELL. CIRC UNTIL 11.0 PPG RETURNS. SHUT DOWN AND MONITOR WELL. CIRC AROUND. WELL DEAD. RIH W/ KELLY AND TAG FISH AT 8538. BLOW DOWN AND STAND BACK KELLY. POH. PULLING WET, PUMP DRY JOB. POH W/ FTA #6. BREAK DOWN TOOLS. MU FTA#7. SAC 50' DL. RIH. BREAK CIRC. TAG AND LATCH OEJ BARREL AT 8538. CIRC BU. POH W/ FTA #7 AND FISH. CLEAN OUT FRAC SAND MW:ll.0 NaCl/Br SERVICE RIG. POH W FTA #7 AND FISH. LD TOOLS. MU FTA #8. RIH AND TAG FISH AT 8511. WORK FISH TO FREE PACKER. CIRC BU. PULL 1 STAND AND PUMP DRY JOB. POH W/ FTA #8 AND FISH. RECOVERED SLICK STICK, PACKER, AND ALL 2-7/8 TAILPIPE. LD FISH AND TOOLS. MU 6.125 BIT AND BHA#1. RIH. SAC 50' DL. MU AND SERVICE KELLY. CLEAN OUT FRAC SAND AND FILL F/ 8530-8803. POH MW:ll.0 NaCl/Br SERVICE RIG. WASH OUT FRAC SAND F/ 8803-8846. CIRC BU. PUMP SLUG. H2S ALARM SOUNDED. SECURE WELL AND VERIFY FALSE ALARM. POH. CLEAN OUT JUNK BSKT. RIH W/ BHA #2. WORK SCRAPER F/ 8500-8825. CIRC BU TWICE. PU TO 8640. CIRC BU, HOLE CLEANED UP. PUMP SLUG. POH AND LDDP. ~WELL : 3M-5 OPERATION: RIG : NORDIC 1 PAGE: 3 07/10/92 (10) TD: 0 PB: 8859 RILDS ON TBG HANGER MW:ll.0 NaCl/Br SERVICE RIG, POH-LDDC & BHA #2, CLEAR RIG FLOOR, UNLOAD DP & DC, PULL WEAR BUSHING, LOAD & RACK PIPE, DRIFT & INSTALL SEAL RINGS, MU 2-7/8" TAILPIPE ON OEJ/HRP-1-SP PACKER ASSY & LEAVE STANDING, CHANGE RAMS TO 2-7/8" & TEST TO 3000PSI, RUN 2-7/8" SINGLE COMPLETION ASSY, MU VETCO-GRAY 2-7/8" TBG HGR, TST CL TO 5000PSI WHEN MADE UP TO SSSV & HGR, LND HGR, RILDS, DROPPED BALL 17 JTS BEFORE HGR MU, RAN 31SS BANDS, 50K UP, 26K DWN, PRESSURE TBG TO SET PKR, BALL NO ON SEAT-CIRC TBG VOL, BALL NOT SEATED, SURGE PUMP & SEAT BALL. PRESS TBG TO 2500 PSI & SET PKR (SAW SHEARS @ 1800 & 2000 PSI), HELD 2500PSI FOR 5 MIN THEN TBG BLED DOWN TO 1800 OVER NEXT 5 MIN, BLED TBG & REV 5 BBLS TO FLUSH OUT CV IN GLM #1, PRESSURE TBG & SURGE TBF & ANN TO CLOSE CV & SEAT BALL-OK, PRES TBG TO 2500PIS & HELD 5 MIN-OK, PRESS TBG TO 3000PSI FOR 10 MIN-OK, HELD TBG @ 3000PSI & PRES ANN TO 1000PSI, HELD BOTH FOR 10 MIN-OK, BLED OFF ANN, HELD TBG @ 1375PSI, BOLDS, PU & SHEAR OEJ @ 78K (28K OVERPULL), BLED OFF TBG, RELAND HGR, RILDS 07/11/92 (11) TD: 0 PB: 8859 RIG RELEASED MW:ll.0 Diesel TEST ANN AND TBG. SET BPV. ND BOPE. NU FMC TREE. TEST PACKOFF TO 5000 PSI. CLEAN ONE PIT AND PUT IN 40 BBL WATER. REVERSE CIRC 40 BBL WATER UNTIL CLEAN DIESEL RETURNED. BREAK OUT AND BLOW DOWN CIRC LINES. LOAD BRINE ON TRUCKS. FLUSH CIRC SYSTEM. CLEAN AND RINSE PITS. MOVE RIG. SIGNATURE: DATE: A,.n.~shoraga TO: THRU: FROM: ' 'MEMORANuUM State of Alaska ? ~ ALASKA OIL AND GAS CONSERVATION COMMISSION %~,~ ~ ~,,~-~-~.. DATE: July 7 1992 Commi ~ s lone t----c~' : FILE NO: hh7 7 - 2. doc Blair Wondzell P.I. Supervisor TELEPHONE NO: SUBJECT: BOP Test-Nordic #1 AAI KRU 3M-5 Permit No. 87-25 Kuparuk Rv Field arold R Hawkins Petr Inspector T__~daY~. July .2~ 1992 I witnessed the BOP test on AAI KRU 3M-5 on Nordic Rig #1. There were two failures~ !~._r~Dmmavy~ the BOP test on AAI KRU 3H-5 on Nordic Rig #1 was satisfactorily performed. The failures were repaired and tested okay. Attachment 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 OPERATION: Drlg~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report Wkvr / Rep TEST: Initial Weekl y~ Other Drl9 contrctr Location (general) Housekeeping (general Rsrve pit MUD SYST~S: Visual Trip tank Pi t gauge F1 o~ monitor Gas detectors Well sign Audio BOPE STACK: Annular preventer Test Pressure permit # ~-~ Location: Sec~'J ACCUMU~TOR SYSTEM: Full charge pressure j /YJ psig Pump incr clos press 200 psig .... min ~ sec Full charge press attained /~1 ~ min ~ sec Controls: Master ~ Remote ~ / I KELLY AND FLOOR SAFETY VALVES: Pi pe rams :' -' HCR valve Upper Kelly Lower Kelly Bal 1 type ! nside BOP Choke manifold Number valves /X Number flanges ~ Test pressure Test pressure Test pressure Test pressure Test pressure Kill line valves ,~0~0 Adjustable chokes Check valve ~- 3 ~ 0 Hydraulically operated choke TEST RESULTS: Failures ~ Test time .~:)~ 'Y hrs Repair or replacement of failed equipment to be made within ---'- days. Notify the Inspector, and follow with written/FAXed [276-7542] verification to Commission office. Distribution: orig - AOGCC c - Operator c - Supervisor STATE W l TNES/S/REOUi RED? yes 'V no 24-HR NOT1 CE GI'VEN? yes ,,V/' Waived by: C.004 (rev 03/92) ... -' . STATE OF ALASKA ~- ,N~/f//~ ALASK~ OIL AND GAS CONSERVATION t.,,,,)M MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inco 87-25 3. Address 8. APl Number Po 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21706 4. Location of well at surface 9. Unit or Lease Name 1204' FNL, 1703' FEL, 5ec.25, T13N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1817' FNL, 3901' FWL, Sec.30, T13N, R9E, UM 3M-5 At Total Depth 11. Field and Pool 1835' FNL, 4247' FWL, Sec.30, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 64'I ADL 25521 ALK 2557 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 03/17/87 03/22/87 10/17/87*I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set ] 21.Thickness of Permafrost 9110'MD, 6462'TVD 8859'MD, 6295'TVD YES [~ NO [] 1793' feet MD 1600' (approx) 22. Type Electric or Other Logs Run DIL/SP/GR/SFL, FDC/CNL, Cal, CBT, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 198 sx CS II 9-5/8" 36.0# J-55 Surf 4351' 12-1/4" 1200 sx CS Ill & 325 s; Class G Performed top job w/10( sx CS II 7" 26.0# J-55 Surf 8948' 8-1/2" 400 sx Class G & 175 s~ CS I 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) Perforated w/1 spf, 120° phasing 2-7/8" 8571' 8540' 8672 '-8676'MD 6171 '-6173'TVD 8686'-8718'MD 6180'-6201 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8728 ' -8731 'MD 6208 ' -6210 'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8736'-8738'MD 6213'-6214'TVD See attached Adden~um~ dated 10/21/87~ for fracture dat~. 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD e I Flow Tubing Casing Pressure CALCULATED oIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE e 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None *Note: Drilled RR 3/24/87. Perforated well & ran tubing 7/6/87. Fracturedi~[~$~/~7~.O~e WC3/9~ :UAN I Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8645' 6153' N/A Base Kuparuk C 8664' 6165' Top Kuparuk A 8664' 6165' Base Kuparuk A 8770' 6236' 31. LIST OF ATTACHMENTS Addendum (dated 10/21/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge t~~~~_~ Title Associate Engineer Date ~'~7 . Signed 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 ADDENDUM WELL: 4~30~87 10/17/87 3M-5 RU Schl, make GR/JB rn to 8801WLM. Rn CBT f/8795' - 6200'. Rn GCT gyro f/8771' - surf. Frac Kuparuk A-1 and A-2 zone perfs 8672'-8676', 8686'-8718', 8728'-8731', 8736'-~ 8738' in ten stages per revised procedure dated 10/7/87 as follows: Stage 1: 100 bbls gelled diesel @ 20 BPM, 5950-5000 psi Stage 2: 500 bbls gelled diesel @ 20 BPM, 5050-4390 psi Stage 3: 20 bbls gelled diesel 2 ppg 12/20 sand @ 20 BPM, 4390 psi Stage 4: 40 bbls gelled diesel 4 ppg 12/20 sand @ 20 BPM, 4790-4900 psi Stage 5: 40 bbls gelled diesel 6 ppg 12/20 sand @ 20 BPM, 4880-5040 psi Stage 6: 40 bbls gelled diesel 7 ppg 12/20 sand @ 20 BPM, 5200-5330 psi Stage 7: 30 bbls gelled diesel 8 ppg 12/20 sand @ 20 BPM, 5360-5500 psi Stage 8: 20 bbls gelled diesel 9 ppg 12/20 sand @ 20 BPM, 5440-5480 psi Stage 9: 26 bbls gelled diesel 10 ppg 12/20 sand @ 20 BPM, 5590-6550 psi Stage 10:54 bbls gelled diesel flush @ 6600-7300 psi Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 815 bbls 43,600# 0 5410 psi Drilling Supervisor D~ate $ UB-$ URFA CE DIRECTIONAL F~ UIDANCE SURVEY ~ONTINUOUS [-~ OOL RECEIVED JUL 2 8 ~ [1tl & Gas Cons. Commission Anchorage Company ARCO ALASKA, INC. Well Name 3M-5(1204' FNL, 1703' Field/Location KUPARUK~ NORTH 5LOPE, FEL~SEC AI_ASKA 25~T13N~R8E.UM) Job Reference No. 72304 SARBER Date 28-APR-87 Computed By: KRUWELL ~ SCHEUMB~RG~R ~ GC? DZR£CTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA~ iNC. KUPARUK NO~TH SbOPE,ALASKA SURVEY DATE: 28-APR-87 £NGINEERI G. BARBER METHODS OF COMPUTATION TOOb LOCAI'IONI TANGENTZAL- Averaged devlat&on end az&muth INTERPObATIONI LZNEAR V~TZCAb $~CTIONI HORIZ, DIST,,PROJECTED ONTO A ?ARGET AZIMUTH DE BOU~H ~4 DEG 3e MIN EABT ARCO AI.,A~KA~ ]:NC', 31q-5 KUPARUK NORTH $~OPE,AL, ASKA CONPUTATZON DATEI 17-RA¥-97 RECEIVED PAGE DATE Or SURVIC¥1 28-APR,,87 K£LI.,Y BUSHZNG ELEVATIONI 64.00 CAI., TRUE SUB-$£~A~.uaOij,.A~lldk~lliSsio[: VgRT! DOGk, EG RECTANGUI.,AR COORDINATE8 HORI~,~ PlIEA,6URED VERTZCAb VERT:[C.~ .1,.¥~T~ AZJ. IqUTH SE(~],I~N ~¥ NORTH/SOUTH EAST/IdE&T D l'.. 0 O0 100 O0 200 O0 3O0 O0 40O O0 500 O0 599 99 699 88 799 10 896 79 "64,00 0 0 N 0 0 E 0,00 36.00 0 4 N 51 33 ' '0.{6 ,~,.oo ~ ~ . ,9 ~o . .o' 34 .60 3 ,00 0 15 N '1 14 E -0.74 436.00 0 ti N 6 21 W -0.7? 535,99 0 N 23 30 E -0.88 ~.88 4 N 70 16 E 2.64 ~.7.~0 9 ~t N 77 45 g 14.11 832. 9 14 N 93 58 £ 34.62 0 O0 O0 0 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 #UTH #IN O0 N ,00 0.00 O0 0 .~, o.o~ ~~ ~:,, ?o t~ ~' : 9? . , 1373,84 1379,61 84 tl~.O0 2606 82 2542."2 43 78 ~ ~½~ ~ {.34 '26.06 ~ E ~ 45 , 449, 4.44 139.78 .00 2677 70 2613.70 46 ~ i 79 ~ 5 4 0.67 152,82 ~ 1443.01 · 80 1516.54 - 3300.00 2744 19 2680.19 48 .' 1524.22 3400.00 28~0 lO 2746.10 48 ~ ~ 80 1~ 15~9 I~ 0,15 165.55 1590.66 1599.25 84 ' 83 . 1664 71 1674,24 3500.00 2876 07 48 80 ~ 1674 09 0.74 178.34 ~ ~ ~ 53 ~,oo.oO~oo.oo ="" ~' ~½~.O**oo,.~ o , ~ I 'ii · ,45 49 749 52 0.14 191.43 8?39 24 1749.75 ' 8 1901, , 217,88 8859 46 83 25 901, 0,68 ~ 1979.09 ~o?o ~ ~o ~ ~ ?~ ~? . ' 3900.00 3134.31 3070.3151 ?9 4~ £ 1979. 0,9~ 23~,51 19s5 50 47 , , 1021 47 13 ½oo oo ,~ ~ ,o i I o oo oo ~'~ ~ "'~ ~ ~ '~ [ ~:?o 88 187,62 . , 239,03 40, O0 O0 i350 70 1286 70 ]2 86 96. e 89 · 57 1600 O0 1512 86 1448.86 38 59 84 . ~ 357 17 89 . ,~o.½~ ?.~, . ,2, ,o27 {800O0 1663 99 1599.99 43 ~ , , 86 ~oo oo ~ ~o ,~,.~o ~ ~, _ _ 556.35 557 57 699 48 22 85 698 18 9~ 76 6~9 E 1946 05 1864.05 43 S 84 31 768 14 26 55 768 g 769 35 87 81 i 66 2500 O0 2167 68 2103.68 42 50 [ 971 68 ~ 973 1038 1040 2~oo oo 224~ ?o 2~??.~o ~2 s~o ~8 ~o39 50 2?00 O0 2314 99 2250,99 43 , 1172 1175 2600 O0 2397 95 2323 95 42 51 79 1175 48 . 2900 O0 2461 23 2397.23 434 $ 79 ~ 1243 23 54 16 $ 1239 391243 35 $ 85 COMPUTATION ARCO ALA$KA~ INC. KUPARUK NORTH ~LOPE~ALASKA DATE Of 5URVEYt 28-APReB7 KELLY BUSHING E~EVATIONI 64.00 ENGINEERI G. SARBER INTERPOLATED VALUES FOg gV£N 100 FEET OF MEASUHED DEPTH TRUE ~UB-$£A COUR$£ EASUR£D VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG NIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE $ ECTXON S~VER~T¥ NORTH/SOUTH EAST/WEST D10~. AZ~#UTH FEET DEG/IO0 F~ET FEET ,ooo o, 8~ 2133.28 04? 253 2118.83 2134 O0 3323.80 3259e80 5057 8248 ~ 55 4300003386.473322.4751 Ii $~$ 823~gE 2210.80 0382635. ! 2195.79~ E 22tl 82 2288.67 038 27350 ~2273.08 ~228947 44004500 O000 351[.123448'95 3447.123384"95 5151 S 82815~ E 2366.692444.93 O0530 294283 9397 242e.01235°'45 [ 236724458654 82 3~b $ 2601~08 2680 2660,13 82 4eO0 O0 369~.45 3634~45 51 19 2679.02 E 14 4900 O0 3~61,30 3697~30 SO $ 8229 ~ , 337 2737.24 275792 & 82 2756,75 5i00 O0 3888.42 3824.42 50 J 82 44 ~ 29Ji,05 O, 9 356 2890e~6 ~ 2912 5200 O0 3952.52 3,88.52 50 8245 2987.77 0,09 '66 t76 29'6.51 98 5300 O0 4016.83 3952,83 49 i44 [£ 3064.30 0,,28 65 5500540000004081.43 4146.04 4082.044017.4349 49 ~8282 ~! ~ 3140.60 3216.89 0,32 0,37 385 395 ~393.9431'8'20 ~ 3218 ~2 5700.00 4275'89 4211.89 49 ~ 3368.95 72 3344.94 3370 89 3446 40 3444,89 0,30 422 ~420,36 seoo.oo 4~40.~t 4~6.~ 4~ a~ ~ 5900,00 4406,]2 4342,32 48 $ 16 84 04 7 3520.51 0,12 431 3495.47 $ 9 E 3595,93 0.39 440 5 3570.$9 ~ 3597 49 3672 83 3671.17 Oe57 449 ~645,11 75 0.36 6400 O0 4730.62. 4666°62 5053 8336 ~38 ~ 3900.87 0.380'28 484 47666073873.35 E 390250 i 8 6600 O0 4857,15 4793,15 5042 83 39 ~ $ 4055.74 0,22 493 23 4027.29 g 4057 4X34 30 83 4104.12 69 4133.03 Oe60 50 88 6800 O0 4993.05 4919.05 51 46 $ 83 22£ 4211.09 0.6) 510 82 41el.68E 4212 77 8~ 23 E 428~.90 0.23 519 93 42sg.ge E 4291 60 6900 O0 5044.58 4980.58 52 14 83 E 7000 O0 5105.82 5041.82 52 22 $ 83 25E 4366.94 0 ]} 529 O0 4338 51~ 4370 ?ioo oo 5~66.~4 5~02.64 52 46 s E ~,.30 2 5~ o? 83 26 0 6 4417 37 ~ 4450 83 7200 O0 52~.4~ 5~6~.44 5~ 41 ~ 8458~ 4527.683 38 546 44~6 Jo 4529 83 62 7~00 oo 5289o98 5225.98 5~ 21 o .5 5o ~ 4605,69 0 4? 7400005352,3588.35~ 5115 S 85 56 E13 £ 46838449160400 558 0946520775 ~ 468543 ]~ O0 5477.98 54 3.98 5055 S 86 8 E 4839.41 043 56880 480732 4840 , . , 49t8 7800 O0 5604 7 5540.27 50 ]0 $ 86 21 E 4994.44 06 578 97 4'62 07 4995 79 ARCO A~ASKAA. 1NC, 3N-5 KUPARUK NORTH ~OPE~A~ASKA CONPUTATION DAT[t ~?-~A¥-~7 INTERPOI.,ATED VAbUE$ FOR EVEN I00 r£gT OF HEASUREO DEPTH TRUE SUB-,gA COURSE VgR,,CAb DOGbEG. REC,ANGObAR COOeD Z N ATE, HOR,,., D[,AR,URE 8000.00 5711,85 5667.85 50 14 8200 0 5860.40 5796 40 8300:~0 5925.38 56~I ii 49 6 8400 0 5990.82 59 8 49 3 8500 O0 6056.42 5992 48 49 8600 O0 6122.69 6058 48 it 8700 O0 ~.35 ~115.35 48 8800 O0 .03 t 2.03 48 4 8900 O0 6322.63 6258e63 48 ~4 $ 86 43 E 5t48.37 0 $ 87 4 E 47 1? o $ 2 E 2:94 0 S 86 56 E 5603,16 0 $ 86 59 E 56??,66 0 S 87 0 £ 5752,10 0 $ 87 0 E 5826,64 0 O0 O0 · 39 O0 94 , 6455 48 , 87 , 9110.00 6462. 6398.48 48 4 $ 87 0 E 5983. 6 0.00 1.32 ARCO AEASKA~ INC, KUPARUK NORTH SLOPEAAEASKA COMPUTATION DATEI 17oMA¥-87 PAGE, 4 KELLY .USHING ELEVATXON, 64.00FT ENGZNE£RI G,. BARBER INTERPOLATED VALUES FOR £VEN 1000 fEET OF NEASURED DEPTH TRUE SUB-SEA COUR6£ 4EASURED V£RTZCAb VERTZCAh DEVIATZON AZIHUTH DEPTH DEPTH DEPTH DEG NZN DEG MZN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 O0 O0 992 O0 1806 O0 2534 O0 3197 O0 3824 O0 4471 O0 5105 O0 5731 O0 6389 -64 O0 0 0 35 928 3519 16 O?12 ?4 07 45 69 3760.69 50 48 95 4407,95 82 5041,82 52 22 85 5~;:85 50 14 23 6 23 48 14 VERTICAL DOGLEG RECTANGULAR COOROINATE$ SECTION SEVERITY NORTH/8OUTH EAST/WEST FEET DEG/IO0 FEET FEET N 0 0 E N 89 55 E 87 3 E 627,32 i 81 54 g .96 39 $ 82 38 E 2834,04 S 83 9 E 3595,93 $ 83 25 E 4368,94 $ 86 43 E 5148,37 S 87 0 E 5901,1'7 HORZ:~": DEPARTURE ! To UTH MIN O. O0 0 4 45 0 3~ 9110.00 6462.48 6398,48 48 14 8 87 0 E 5983,16 0,00 63~,32 $ 5950022 E 5983062 8 83 56 E CDHPUTA?ZON DA~I PAGE 5 ARCO AbASKAw XNC, KUPARUK NORTH ~bOPEwAbASKA DA SURV 280APRoiI? KE:bL, Y BUSHII~ OF ~YNI ICbEVATX , 64.00 ENGIN~ERI Go~SARBER {NT£RPOLATED VAbOg~ FOR BVgN 100 Fg£T OF SUBmSgA D~PTN TRUE ~UB-$gA COUR&E VERTICAb DOGbEG R£CTANGUbAR IEASURED VERTICAL VBRTXCAb DEVXATXON AZXMUTH SECTXON SEVERXT¥ NORTH/8OUTH DEPTH DEPTH DEPTH DEG. #ZN DEG NiH FE£T DEG/IO0 FEET 0,00 0 O0 0 0 N 0 0 E 0,00 0 O0 0 O0 64,00 6400 '6~§§4 ~552~: -0,14 064 006~ OiiE ,~,.oo ,~,oo ,oooo ,,~, .o.,,-o.~? OO,o , o!~", ~': .i ~ ,o :~ ,,~,. ~ :!! {il ~,ooo ~ oo ~oo oo ~,.oo ~, oo ~oo oo ~[I~ ,o ~ ~ .o..?'°'?~ o ~.o~~.oo~oo oo ~ ~ o.~8 ?~,.,~ ?~,.oo ?oo oo ~ ,~ ~ ?~ }~ ~ ~.?, ~.~ 866,22 864,00 800 O0 13 N 1~?~07 ,,,,.0, ,,0,.oo ,,oooo 1! ,,,.,, 1537,83 1464.00 1400.00 ~84 50 E 317.43 3..24 6 398.32 ~oo.ox ,~.oo x6oo.oo ~ ,, ~ I:~I I ,,? 4,?,9, 486,76 584.73 0,67 2082,22 1864o00 1800.00 44 86 b~6,93 685,63 1.12 21 2359,752064,002000,0042 ~ 878.01 1.36 40.48 78 2~.o~ ~,.oo ~,oo.oo,~ ~ ~ ~ ~ ~.o, o.~, 2630,33 2264,00 2200,00 42 80 32 0 88 33 1058 1060 52 1X53.28 01 ~i 48 1150 1153 55 1339 46 2767.28 2364.u0 2300,00 43 79 44 2903,80 2464.00 2400.00 435 $ 1 3041,13 2564,00 2500,00 43 18 $ 78 31 ~1339.44 0 19 I 01 1546 1538 3330.18 2764.00 2700,00 48 5i 80 1~ ~1546.88 O0 81~5 156 137 67 ~,.~= =~.oo =~oo.oo ~ ,~ ~ ~o ~ ~o.=~ 175 97 { 1651, 1660 4t 2 8 O0 ~.~? ~ ~xo~ oo~oo.oo ~x ~ 6 8o ~ =ox~.~ 4105 273264 O03200.0050 83 2137,36 ,,24 ~,~,~, oo ~ . 2637 23 . 40 ~ 2881 64 * , , 2882 89 ARCO AbASKA, INC, ]#-5 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DA~EI 17-NA¥-87 PAGE DATE OF SURVEY1 28eAPR-87 KELLY BUSHING EbEVATXONI 64,00 ENGINE&RI Ge. SARBKR INTERPOLATED VALUES FOR EVEN 100 FEET Or SUB-SEA DEPTH TRUE SUB-SEA ~OURSE IEASURED VERTICAL VERTICAL DEVIAT ON AZIMUTH DEPTH DEPTH DEPTH DEG. 5217 88 3964 O0 3900 O0 50 1 99 4064 O0 4000 O0 49 44 .73 4164 6 OD ,. 71 4264 O0 _ 56~I 5835 5987 6139 6294 6452 6610 41 4364 90 4464 63 4564 33 4664 86 4764 81 4864 O0 O0 49 O0 4300 O0 49 O0 4400,00 48 O0 4500,00 48 32 O0 4600.00 50 54 O0 4700,00 50 46 O0 4800,00 50 41 S 83 0 £ 3238,00 £ t471.73 S 8 0 £ 3586,80 $ 8 E 3700,88 8 8 £ 3818.86 $ 83 36 E 3941,85 S83 38 £ 4064.10 6769 25 6931 095 258 7736 7893 8050 8205 4964,00 4900 75 5064,00 5000 47 ,00 5 60 5364,00 5300 83 5464,00 5400 38 5564,00 5500 72 5664 O0 o 5864 O0 5800 10 O0 52 46 O0 51 14 oo O0 50 O0 50 ~t O0 50 4 O0 50 8 O0 49 36 DEG MIN 368 37 S 98 ,0 E 3002, 8 a 82 57 E 0 412 04 $ 3331 14 E 3356~53 426 10 a 3447 01 E 3473~21 K !! 439 66 $ 3561 33 E 3588'36 ~ I1 i~ 453 36 s 3674 63 E 3703,48 ~ I : 480 61 $ 3914 09 Z 3943,40 E 466 85 $ 3791 85 E 3820,48 96 u 74 522 02 s 4204 03 E 43!6,7! · 550 11 S 4541 79 E 4574.8~ S 8 30 559 12 S 466b 54 E 4699.92 S 8 1 21 0 48 567 63 $ 4790 15 E 4823 67 8 83 14 ~ 0 '3 575 80 $ 49'2 91E 4946 54 S 81 18 583 41, 50~4 15 E 5067 ,4 ! ii 11 6192 0 23 590 35 S 51~4 33 ~ 5188 O, 7i o 20 5g6 70 $ 527~ 04 r 5306 70 57 E 4698 S 85 $ 86 6 E 4822 S 86 15 E 4945 S 86 34 E 5066 $ 86 47 E 5186 $ 87 4 E 5305 8359.05 5964.00 5900,00 49 5 8511,49 6064,00 6000,00 48 45 8661.95 ~t~,00 6~00,00 48 13 8811o96 .00 6 00,00 48 14 8962,~2 6364,00 6300.00 48 14 91i0,00 6462,48 6398,48 48 14 S 87 16 E 5422,04 $ 87 9 E 5536,97 $ 86 56 E 5649,30 $ 87 0 £ 576~ 02 S 87 0 E 587:94 $ 87 0 E 598~,16 O019 .0 602,35 389 35' 542!,91 607 95 I ~504' [ 553 .74 , ,27 ~ , 598 631 22 ARCO AbASKA~ INC. 3N-5 KUPARUK NORTH SLOPE~AbASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD COMPUTATION DATEt 17-MA¥-87 DArE Or SURV~¥~ 28-AP~-87 ENGZNgERI Ge: 8A~BER %N~ERPObATED VAbUE$ FOR CHOSEN HORXZON$ NEA&UR£D DEPTH BEbON KB 86445.~~ 6152.70 6088.70101 866 . 6165.36 61_0!,36 6165.36 6 .36 8664. 8770.(~0 6236.05 6172.15 8859. 0 6295.32 6 31. 2 91i0,00 6462,48 6 98. 8 61!.18 5603.9 ~ · 5618,0 6i .94 5618,0i i 61 .09 i 5696.9 6 1 55 · . 5950,2 COHPUTAT]ON DATEI 17-MA¥-87 ARCO Ab&$KAm ZNC, 3M"5 KUPARUK NORTH SbOPEwAbASKA DATE OF' ,SURVEYI 28'APR"8? ' KE[,,I,,Y BUSHING EI,,ICVAT];ONi ~4,00 FT' ENGT. NEERI G,, 8ARBE:R MARKER MEASURED DEPTH BEbOW KB SURYACE bOCATZON A OR~GXN~ 1204 rNbw 1703 FEb:. &EC.'~5. TI~N~RBEf UN 'rvo COOROZ.A S TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD Ib45.00 664000 8664,00 8770000 8859,00 9110,00 6t52,70 6088:~ 6165,36 6~01 6236,05 6172 6462,48 , 56~800 ~ 09 5696,0 ' 5763,~ FZNAb Wgbb bOCATXON A~ TRUE SUB-SEA MEASURED VERTXCAb VERTICAL DEPTH DEPTH DEPTH HORZZONTA~ DEPARTURE DZSTANCE A~XMUTH FEE~ DEG MZN 9110000 6462,48 6398.48 5983,62 S 83 .56 E SCHLUMBERGER O I RE C T I ONAL SURV E Y COMPANY ARCO ALASKA INC. WELL 3M-S F I ELD KUPARUK COUNTRY USA RUN 1 DATE EOOOED 28 - APR - 87 REFERENCE 72S04 WELL' 3M-5 HORIZONTAL PROJECTION '(1204' FNL, 1703' FEL, SEC 25, T13N, R8E, UM) 4000 3OOO 2OOO 1000 -2OOO -3000 ~OUTH -4000 - 1000 WE(~T REF '72304 $CAt_E = !/!000 IN/FT ! ) , : ~ = ~ . : ! : = = *T T ....... '~-*T**T* ~ i i ~ ! ~ ! ' ? ~ I i ' ! i i ' ' ' ; ' ' ' ' ! ! ~ , ! ! ! 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["~": ........ 7T"7'i ...... t"l'"TT":"t'"t'"~'"FT"7'J · ..i...;..~...~...~-..;...i .... ~ ....... L.: ;...!..:..i ......... i...L..L;..-L.~..;...;..-.i.; .... :-..: -?i'"' ........... .......... ............... ....... ....... ....... ? ...~..+...;..., ...... ,._~...~...~ ............. ;..;.....;...~ ...... ; ..... ,....~ ....... ; ...... ,...;...;...; ................ , ....... , ........ ,..~,..., ...... ;...,._; ...... ~ ..... ~ ............. ,...~..., ..... ~ ........ ,_.?_; .................. ~_~ ..... ; ............. ~ ...... ,. ,...,...;._, ....... ~._ 0 1000 2000 3000 4000 ~5000 6000 7000 EIq~T WELL' 3M-5 (-1204' FNL, 1703' FEL, SEC 25, T13N, R8E, UM) VERTICAL PROJECTION - ! 000 0 0 ! 000 ~000 ~000 ~000 BO00 GO00 7OOO 9!~. PROJECT[ON ON VERTICAL PLANE 9S. - 27S. SCALEO IN VERTICAL OEPTHS HORIZ SCALE = l/ ]000 IN/FT ARCO Alaska, ~ Posl Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: August 26, 1987 Transmittal g 6041 RETURN TO: ARCO .Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 · Transmitted herewith are the following items. Please acknowledge receipt and. return one signed copy of this transmittal. 2U-13 Static Well Pressure Survey 'C' Sand 8-27-87 3M-8 Kuparuk Well Pressure Report 'A' Sand 7-10-87 ~3M-7 Kuparuk Well Pressure Report 8-13-87 ~3M-6 Kuparuk Well Pressure Report 'A' Sand 8-12-87 ~3M-5 Kuparuk Well Pressure Report 'A' Sand 8-12-87 "r"-3M-4 Kuparuk Well Pressure Report 8-11-87 100554H Receipt Acknowledged: DISTRIBUTION: BPAE Chevron Mobil SAPC Unocal State of Alaska ~ D & M' ARCO Alaska, Inc. Is a Subsidiary o! AllantlcRIchlleldCompany -¢-- STATE OF ALASKA AL. ¢,~ OIL AND GAS CONSERVATION CC .,. .SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Alter Casing [] Other Stimulate [] Plugging © Perforate [~ Pull tubing COMPLETE 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1204' FNL, 1703' FEL, Sec.25, T13N, R8E, UM At top of productive interval 1817' FNL, 3901' FWL, Sec.30, T13N, R9E, UM At effective depth 1826' FNL, 4060' FWL, Sec.30, T13N, R9E, UM At total depth 1835' FNL~ 4247' FWL~ Sec.30~ T13N~ R9E~ UM 11. Present well condition summary Total depth: measured 9110'MD true vertical 6462 'TVD Effective depth: measured 8859'MD true vertical 6295 'TVD 5. Datum elevation (DF or KB) RKB 64 ' Feet 6. Unit or P~roperty name Kuparuk t{iver Unit 7. Well number 3M-5 8. Approval number 7-251 9. APl number 50-- 029-21706 10. Pool Kuparuk River 0il Pool feet Plugs (measured) None feet Casing Length Size Conductor 80' 16" Surface 4314' 9-5/8" Producti on 8913, ' 7" feet Junk (measured) None feet Measured depth True Vertical depth 115'MD 115'TVD 4351 'MD 3418 'TVD 8948'MD 6355'TVD Perforation depth: measured Cemented 198 sx CS II 1200 sx CS III & 325 sx Class G Top job w/lO0 sx CS II 400 sx Class G & 175 sx CS I true vertical 8672'-8676'MD, 8686'-8718'MD, 8728'-8731'MD, 8736'-8738'MD 6171'-6173'TVD, 6180'-6201'TVD, 6208'-6210'TVD, 6213 ' -6214 'TVD Tubing (size, grade and measured depth) 2-7/8", J-55 tubing w/tail @ 8571' Packers and SSSV (type and measured depth) HRP-1-SP pkr ~ 8540' .& TRDP-1A-SSA SSSV ~ 1793' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) 13. Treatment description including volumes used and final pressure N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Well History w/Addendum, dated 5/16/87) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ¢-" Signed (¢¢0 ~ ~[~)~¢~., Title Associ ate Engi neet Date '7L24 "~7 Form 10-404 Rev. 12-1-85(¢~' (Dani) $W02/51 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish ~State Alaska North Slope Borough I Alaska Field Lease or Unit Kuparuk River ADL 25521 Auth. or W.O. no. Title AFE AK2050 Completion JWell no. 3M-5 Nordic 1 Operator ARCO Alaska, Inc. API 50-029-21706 A.R.Co. W.I. 56.24% Spudded or W.O. begun Date Complete 7/5/87 Date and depth Complete record for each day reported as of 8:00 a.m. 7/05/87 thru 7/06/87 7/07/87 · Old TD Released rig 1800 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing I otal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well I our I Prior status if a W.O. I 0615 hrs. 7" @ 8948' 8859' PBTD, Pmp'g dn ball w/5' tail 10.0 ppg NaC1 Accept rig @ 0615 hrs, 7/5/87. ND tree, NU & tst BOPE. RU Gearhart, perf 1SPF, 120° phasing f/8672'-8676', 8686'-8718', 8728'-8731' & 8736'-8738'. Make JB/GR rns, RD WL. RU & rn 260 its, 2-7/8", 6.5# J-55 EUE 8RD AB-Mod tbg &lnd. Att to press up tbg w/o success. Rev circ, wrk string, C-in leaking. POH, chg C-line. RIH after dropging #2 ball, rev circ; no press. Drop #3 ball w/tail, pmp dn. 7" @ 8948' 8859' PBTD, RR Diesel Att to pmp dn balls w/o success. RU WL, make blank box rn & push balls to SOS sub. Set pkr, RD SL. Tst tbg/ann to 2500 psi. Tst SSSV to 1000 psi. Shear out balls w/3500 psi. Set BPV. ND BOPE. NU & tst tree to 5000 psi. Displ well to diesel. RR @ 1800 hfs, 7/06/87. SSSV @ 1793', HRP-1-SP Pkr @ 8540' , TT @ 8571' RECEIVED JUL 2 8 ~aska 0tl & 6as Cons. Commission INew TD t PB Depth Anchora~ie 8859 ' P"BTD IDate IKind of rig 7/06/87 Rotary I! Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Potential test data ~V'~ll no. Date Reservoir Producing Interval Oil or gas Test time ;Production Oil on test Gas per day P~'mp size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Si g n at u~,e~z--'//~ /i Date ._./ ITM .... . Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ADDENDUM WELL: 4/30/87 3M-5 RU Schl, make GR/JB rn to 8801WLM. Rn CBT f/8795' - 6200'. Rn GCT gyro f/8771' - surf. RECEIVED J u L 2 8 1~87 Oil & Gas Cons. Commission Anchorage Dril~ ARCO Alaska, Inc. Pos! Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3M Pad (Wells 1-22) Dear Mr. Chatterton. Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/pk GRU1/31 Enclosure 0il & Gas Cons. AncJ~orarj~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Z4 19 VICINITY MA_P_ $C&LE I", 2MILES NOTES: I. ALL COORDINATES ARE A.$.P., ZONE 4. 2.ed. DISTANCES SaO~ nE TRUE. ALL WELLS LOCATED IN SEC. 25, $.~L~VATIONS AnE B.P.M.S.L. TISN, R8E, UMIAT MERIDIAN. 4.REF. FIELOB~K L~7-3, Pg~ 7-1~ LIT-I,RT; LeT-3,PSI-53; 5.0.G.ELEVATIONS ~OM F.R. BELL B ~CIATE$. ~U~NTS ~R LHD · A~IATES. ...... ASPs 'X' LATITUDE L~GITUDE Dist. EN.L. OiII. EE.L. 6,225.l( 5~,"6.45 .T 20.00 :~ 127" 17'2 2'.2: 26.6: 6,248-;:; ~6,t45.98 7'20.2~ [ 1~50', 1722 ~S-S, 26.9, 6,271 .~' 506,155.57 7'20.45 ~6 12~7' 1713 2S.4 ~6.8 s,~4.;, ~os,~s.o~ 7' ao.s;~ ~s'. ~zo4', nos' ~s.4', 6,317.4~ 5~,174.63 T'20.913 i6 IlII 1694 I~.~ 6,016,S40.41 5~,184.1~ T'~l .1~ ~6'5~.~16 1158: 1684 Z~.Z~ ,016,S~6.9; 506,Z03.14 7:~1.59E ~6:57. T~6 II IZ' 1665 ES.O', Z6.4' ~,016,456. I~ 506,~2.0~ 7 ,E~.ZT? ~6, 56.9'~ I~', 16~6 ~ 1.7 ,016,479.~: 506,Z41.5~ :7 ~2.5~ )6 ~.6Z1 1019 16~6 Z 1.5' 6,016,525.51 506,~60.~ :1 22.959 '°56'56D~1 973 1607 ~l.t 0~6,54e.6z ~,270.~0 .7',~s,t~ ~6',5~.7~, ~5~', ~598' ~ t' ~6.4~ ~0.9 E6.4, 016,5~1.4~ 5~,~.T9.TT :7 2~.410 i655.5DI t~T, 1586~ ' ~ 016,5t 4.7] 5~,289.40 7'29.699 i6'55.21T 904, 1578', t 0.9', 016,617~9 506,~99.05 '25.868 i6'54.95~ 8BI 1569 20.9 ~6.5 ,016,~1.02 5~08.76 T~ZT'24.094 4~56'54.64T 858' 1559' 20.8' E6.6~ 5~k, ~;7.9Z 7~'Z7~. ~; /~'~'~4.~77" ~5' !~' Zo.~' 25.9' I NE~Y CER11FY T~TI AM PROPERLY ~GISIER~ AND LICENSED TO ~AC- s~[ or [~ ~.~ ~ f. lS , tt PLAT REPRESENTS A ~ATION ~ .e ~ -'*%.~ I --. · M~ S~ERVISI~, AND THAT ALL o,~s~o,s ~,~ o~, ~ms ~.-L~::;"/~''~"' ~ I e,~'.%. 4538-S ..~ ~ ~.~.~~ ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: May 12, 1987 Transmittal # 5976 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2Z-7 3K-gA 3K-8 3K-17 iA-10 3Q-16 lA-2 3Q-15 3M-6 3M-2 3M-5 3M-7 3M-4 3M-3 3M-1 2Z-5 2Z-5 CET Log 4-20-87 8275-8597 CBL 11-14-86 5408-7460 CET 11-15-86 7148-8376 CET 11-15-86 7940-9400 CET' 11-21-86 8650-8936 CBL 12-20-86 5349-7173 CET 12-21-86 7095-7781 CBL 12-20-86 5453-7360 CBL 4-30-87 5300-7312 CBL 4-28-87 6500-8295 ' CBL 4-28-87 6200-8795 CBL 4-30-87 6300-8359 CBL 4-28-87 7950-9845 CBL 4-28-87 5800-7933 CBL 4-28-87 4900-7187 Squeeze & Plug/Retainer Record 4-30-87 8090-8144 CET 4-30-87 7000-8324 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC .. ~~~-, A~S~ '~ (+Sepia)~?{ BPAE Chevron Union Vault (fi~) ARCO Alaska, Inc. ts a Subsidiary o/AllanlicRichlleldCompany Date: ARCO Alaska, Inc. Post Office B,. i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 28, 1987 Transmittal #: 5958 RETURN TO: - ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. and return one signed copy of this transmittal. Please acknowledge receipt 3M-4 3M-5 OH LIS Tape + Listing 3-15-87 ~72228 OH LIS Tape + Listing 3-23'87 #72232 Receipt Acknowledged: DISTRIBUTION: D. Wetherell ~,State ARCO Alaska, inc. is a Subsidiary of AtlanticRich/ieldCompany ARCO Alaska, Inc. Post Office .~ ~ ~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: April 28, 1987 Transmittal #: 5956 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted"herewith are the following items. Please acknowledge receipt and return one' signed copy of this transmittal. Open Hole Final Logs: 3M-5 5" FDC Porosity 3-23-87 6750-8959 2" FDC Porosity 3-23-87 6750-8959 2" FDC Raw Data 3-23-87 6750-8959 5" FDC Raw Data 3-23-87 6750-8959 2" DIL 3-23-87 2700-8986 5" DIL 3-23-87 2700-8986 Cyberlook 3-23-87 8270-8959 3M-4 Cyberlook 3-15-87 2" FDC Porosity 3-15-87 9250-9815 5" FDC Porosity 3-15-87 9250-9815 2" FDC Raw Data 3-15-87 9250-9815 5" FDC Raw Data 3-15-87 9250-9815 2" DIL 3-15-87 4668-9841 5" DIL 3-15-87 4668-9841 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Vault (film) Rathmell D & M L. Johnston (vendor pkg) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALAS,.., OIL AND GAS CONSERVATION COMN..,~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown I~ Re-enter suspended well ~ Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate rq Pull tubing ,~ Amend order [] Perforate [~ Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P. 0. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 1204' FNL, 1703' FEL, Sec.25, T13N, R8E, At top of productive interval 1739' FNL, 1270' FEL, Sec.30, At effective depth 1768, FNL, 4072, FWL, Sec.30, At total depth 1774' FNL, 4260' FWL, Sec.30, 11. Present well condition summary Total depth: UM measured true vertical T13N, R9E, UM (approx.) T13N, R9E, UM (approx.) T13N, R9E~ UM (approx.) 91 t 0 ' MD feet Plugs (measured) 6456 ' TVD feet 5. Datum elevation (DF or KB) RKB 63 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3M -5 8. Permit number 87-25 9. APl number 50_029-21 706 10. Pool Kuparuk River 0il Poo] None feet Effective depth: measured 8859 ' MD true vertical 6290'TVD Casing Length Size Conductor 80 ' 1 6" Surface 431 4 ' 9-5/8" Producti on 8913 ' 7" feet Junk (measured) None feet Cemented Measured depth ~ue Verticaldepth 198 sx CS II 115'HD 115'TVD 1200 sx CS III & 4351'MD 3413'TVD 325 sx Class G Top job w/lO0 sx CS II 400 sx Class G 8948'MD 6349'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Well History, Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation August, 1987 14. If proposal was verbally approved Name of aPprover Date approved Approved by ~,~f |.~,{~[ Form 10-403 Rev 12-1-85 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ 0,./)~/~(..~~ ,/": Title Associate Engineer Signed ~ ~ ~./,LU~ ) " ' Commission Use Only ( DAN I ) SA2/~O I Conditions of approval Notify commission so representative may witness Approval No. ~ Plug integrity ~ BOP Test ~ Location clearanceI Commissionor Date 4-/~ -c'~ 7 by order of ! the commission Date Submit in triplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. Alaska ICounty, parish or borough North Slope Borough State Alaska District Field Lease or Unit Kuparuk River ADL 25521 Auth. or W.O. no. T tie AFE AK2050 Drill Doyon #9 API 50-029-21706 no. 3M-5 Operator ARCO W.,. 56.24% Prior status if a W.O. ARCO Alaska, Inc. Spudded or W.O. begun IDate Hour Spudded I 3/17/87 Date and depth as of 8:00 a.m. 3/18/87 3/19/87 3/20/87 3/21/87 thru 3/23/87 Complete record for each day reported 2300 hrs. 16" @ 115' ~960', (845'), DD Wt. 9.3, PV 19, YP 27, PH 9.0, WL 11.8, Sol 7 Accept rig @ 1930 hfs, 3/17/87. NU diverter. Spud well @ 2300 hrs, 3/17/87. Drl to 960'. 554', 0.4°, N 6E, 554.00 TVD, .02 VS, 1.92N, .20E 739', 7.1°, N78E, 738.49 TVD, 6.83 VS, 10.26N, 7.82E 16" @ 115' 3047', (2087'), Navi-Drlg Wt. 9.0, PV 12, YP 16, PH 9.0, WL 9.2~ Sol 5 Drl, Navi-Drl & surv to 3047'. 920', 15.6°, N86E, 916 TVD, 42 VS, 14.90N, 43.09E 1326', 30.3°, S88E, 1287 TVD, 202 VS, 13.36N, 204.02E 1767', 41.9°, S86E, 1640 TVD, 465 VS, 5.93S, 466.51E 2133', 44.8°, S85E, 1906 TVD, 716 VS, 23.89S, 717.08E 2925', 43.3°, S79E, 2483 TVD, 1258 VS, lO0.15S, 1254.06E 9-5/8" @ 4351' 4375', (1328'), Prep to cmt Wt. 9.3, PV 17, YP 17, PH 9.0, WL 9.0, Sol 7 Navi-Drl & surv to 4375', short trip, C&C, POH. RU & rn 109 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 4351', FC @ 4267'. Prep to cmt. 3303', 49.5°, S80E, 2744 TVD, 1530 VS, 150S, 1523E 4213', 51.1°, S83E, 3327 TVD, 2227 VS, 262S, 2212E 9-5/8" @ 4351' 9110', (4735'), RU loggers Wt. 9.9, PV 10, YP 5, PH 8.5, WL 4.6, Sol 11 Cmt 9-5/8" w/1200 sx CS III & 325 sx C1 "G" w/2% CaCi~ & 2 GHS D-6L. Displ w/wtr, bump plug. ND diverters. Pmp 106 sx CS II top job. NU & tst BOPE. RIH, tag FC @ 4267', tst csg to 2000 psi. Dil to 4385', displ to new mud. Conduct formation tst to 12.5 ppg EMW. Drl & surv to 9110', short trip, C&C, POH f/logs. 4623', 51.5°, S82.3E, 3583 TVD, 2546 VS, S302, E2529 5092', 50.4°, S82.DE, 3878 TVD, 2910 VS, S349, E2890 5565', 49.6°, S83.4E, 4183 TVD, 3273 VS, S393, E3250 6504', 50.8°, S84.7E, 4792 TVD, 3987 VS, S468, E3961 7429', 51.3°, S87.1E, 5365 TVD, 4713 VS, S529, E4684 8381', 49.2°, S89.0E, 5973 TVD, 5444 VS, S553, E5416 8757', 48.0°, S87.6E, 6222 TVD, 5726 VS, S561, E5698 9110', 48.7°, S88.2E, 6456 TVD, 5990 VS, S570, E5963(Projected) The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, Date Title Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. IAccounting State cost center code District lCounty or Parish Alaska Field ~Lease or Unit Kuparuk River [ ADL 25521 Auth, or W.O. no. ITitle AFE AK2050 I Drill North Slope Borough Alaska IWell no. 3M-5 Doyon 9 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth Complete as of 8:00 a.m. 3/24/87 3/25/87 API 50-029-21706 A.R.Co. W.I. '~otal number of wells (active or inactive) on this Icost center prior to plugging and I 56 · 24~0 ]abandonment of this well Date IHour I Prior status if a W.O. 3/17/87 ~ 2300 hrs. record for each day reported t 9-5/8" @ 435~' 9110', (0'), Rn 7" csg Wt. 10.0, PV 12, YP 6, PH 8.5, WL 4.4, Sol I1 RU Schl, rn DIL/GR/SP/SFL f/8996'-4350', FDC/CNL f/8996'-8270', CAL f/8996'-4350'. RIH, make wiper trip, POH, LD DP. RU & rn 7", 26#, J-55 BTC csg. 7" @ 8948' 9110', (0'), RR 10.0 NaC1/NaBr Fin rn'g 206 ]ts + mkr it, 7", 26#, J-55 BTC csg w/FS @ 8948', FC @ 8859'. Cmt w/100 sx C1 "G" w/2% A-2, 1% R-7 & 2 GHS FP-6L & 300 sx Cl "G" w/l% FL-19, .5% CD-31, .3% A-2 & 1GHS FP-6L. Displ w/10.0 ppg NaC1/NaBr brine. Tst csg to 3500 psi, ND BOPE, NU tbg head & lower master vlv, tst packoff. RR @ 1530 hfs, 3/24/87. Old TD New TD Released rig 1530 hrs. Date I PB Depth 3/24/87 Rotary Oil Single Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Flowing Kuparuk Sands Producing method Official reservoir name(s) Potential test data IKind of rig Well no. Date Reservoir Producing Interval Oil Or gas Test time Production Oil on test Gas per day ...... , Pump s'ize, SPM X length Choke size T'iP. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Alaska, Inc. Post Office Box 100360 A~chorage, Alaska 99510-0360 Telephone 907 276 1215 March 27, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3M Pad (Wells 1-18) Dear Mr. Chatterton' Enclosed is an as-built location'plat for the subject wells. If you have any questions, pleaSe call me at 263-4944. Sincerely, Cl. Gruber Associate Engineer JG/db GRU1/31 Enclosure RECEIVED t~ .. MAR I ] J,8 ! 0il & Gas Cons~ G0mmlsslon ~',1~(;O Alaska, Inc. is a Subsidiary of AtlanlicFlichfieldComp3ny " ' __ OLII(TOK liT. 19 .... ~. ~ mUPSON I ~'<' ~b' ~ LAGOON '- ~ VICINITY MAP SCALE I"-- 2MILES NOTES: I.ALL COORDINATES ARE A.S.P., ZONE 4. Z.ALL DISTANCES SHOWN ARE TRUE. ALL WELLS LOCATED IN SEC.:;)5, 3.ELEVATIONS ARE B.RM.S.L. 4.REF. FIELD BOOK L87-$, Pgs. 7.1~ L87-1, R72 L87-3,P51- 532 5.0.G. ELEVATIONS FROM F.R. BELL & ASSOCIATES. 6.HORIZONTAL POSITIONS BA~ED ON 3M CONTROL MONUMENTS PER LND & ASSOCIATES. Y ' ASPs 16,1[02.17 6,016,225. I0 6,016,248.21 66016,271 . 24 '016,294.2.8 6 016,317.42 6 016,340.48 6.016,363.49 6.016,386.92 66016,456.13 016,479 016,525.51 016,548.62 016,571.43 6 016,594.73 6 016,61 7.99 6 016,641.02 506, IZ 6 506,156.45 506,145.98 506,155.57 506,165.07 506,174.63 506,184.13 506,195.52 506,205.14 506,232.02. 506,241.52 506,251.07 506,260.73 5~,270.3~0 506,2:7 9.77 508,289.40 506,299.05 506,308.76 LATITUDE 7 0° 27' 20.005, ] 149°56' 59.72C 7 0°27' 2.0.23,2:'1149°56:59.439 ?oo27' 2o.459'1,4~56 s9.~57 70027: 20.685'"i 149056', 58.877 70°27 20.913'1149°56 5B.59~ 70°27'21 140"1149°56',58.316. 70° 27'21.'$66:] 149°56.58.04(: 7 0° 2 7:2 I. 59~J 149°56:57.756 70° 2.7,22.2.77~ 149°56, 56.906 70°27 22.504"] 149°56 56.6Z'/ 70°2:7'22 750"1149° 56',56.3,45, 70° ' Z'959' 149o56.56.06 I_. ___27 2 . 7clo~?' ~'~ 186"1149°56'55.779..I 70 27,23.639,',1~49 --v0 e ' ' 0 ' · 70o?_7 24.094 '[149<'56 54.647 LO___N_G_I T U D._~_.~E ~ 49o57'oo.ooo'1 i296' 12732 1250, 1227 1204', 1181 111158' II IZ' 019 996', 97~ 950', 927, 904 881' 858' I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADG;: BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF ~/8/87 Dist. FE.L. 1741' 1732' 1722', 1715 1594 1684' 1675' 1665', 16~6, 1626 16171 1607 1598' 1586 1578 1569 1559 O.G.Elev. 25.1' 23.2' 23.$', 23.4 23.4', 23.3 23.2: 23. , 21.7, 2t.5 2:!.4' 21.2' 21.1 20.9 20.9 20.9 20.8' ~d Elev. 26.6' 26.6' 26.91 26.8 26.8** 26.7 26 26.4', 26.5, 2.6,5 26.4~ 26.3 26.4' 26.4' 26.5' 26.5* 26.6' ARCO Alaska Inc. D.S.$M WELL CONDUCTOR AS-BUILT MEMORAIV UM Stat of Alaska ALASK~ .~ZL AND GAS CONSERVATION CO~.~SSION TO: C, V. Chat~e~n/~, DATE: March 26, 1987 Chairman F~ tE NO.' D. ADA. 16 THRU: FROM: L°nnie C Smith 7 ?'~ Commissioner / Doug Amos Petroleum Inspector TELEPHONE NO.: SUBJECT: BOP Test ARCO KRU 3M-5 Permit No. 87-25 Kuparuk River Field Friday~ March 20, 1987: I traveled this date from SAPC Sag Delta ~7 .... i~-t~n to ARCO ~U 3M-5 well to witness the BOP test at Doyon Rig #9. The testing commenced at 5:00 p.m., and was concluded at 6:20 p.m. There were no failures, and I filled out an AOGCC BOP inspection report which is attached. In summary, I witnessed the successful BOP test at ARCO KRU 3M-5 well on Doyon Rig Attachment STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector ~O~f ~V ~05 Operator A/Z~P /~ Location: Sec Z~ T/~ RS~ M ff,MM~ Drilling Contractor ~'?~A/, Ri Location, General ~...Well Sign O~ General Housekeeping O~ Rig ~ Reserve Pi~ ~ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams ~, ~, Blind Rams Choke Line valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Y Well Y/- 5 Representative__ 4~ '/Casing Set ACC~ATOR SYST~ Full Charge Pressure -~DCD psig,, ,-- -- -- Pressure After Closure /~z~).O... psig., ~ , , Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: ~ N ~ f_'~:~ ~' .-' 2 t 'c;3 .z0o Controls: Master , ,, ~p~ Remote min ~.~sec. min ~ sec. Blinds switch cover Kelly and Floor Safety Valves Upper Kelly / o.~T-est Pressure Lower KellM / Z.-~Test Pressure Ball Type / z~Test Pressure ! Inside BOP / z-~'~fest Pressure Choke Manifold / ~J"Test Pressure No. Valves ./-~ ~ No. flanges ~_~ ~" Adjustable Chokes / Hvdrauically,.operated choke. / Test Time / hrs. days and Inspector/ Test Results: Failures ~/~z~ Repair or Replacement of failed equipment to be made within Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector '>~arch 10, 1987 Telecopy: (907) 276-7542 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box ].00360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3M-5 ARCO Alaska, Inc. Permit No. 87-25 Sur. Loc. 1204'FNL, 1703'FEL, Sec. 25, T13N, R8E, UM. Btmho!e Loc. 1764'FSrL, 1008'FEL, Sec. 30, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling, field work, please notify this office 24 hours prior to com~aencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF ~E COI~4ISSION dlf Enclosure cc.- Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA Ot,._ AND GAS CONSERVATION CON .... tSSION PERMIT TO DRILL 20 AAC 25.005 t la. Type of workRe. EntryDrill '~ DeepenRedrill-i~l lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 63', PAD 26' feet Kuparuk River Field Kuparuk River 0il Pool 3. Address 6~ ~P.rop~e._rt.y~D. esig.n .atio~n_ P.O. Box 100360 Anchorage, AK 99510-0360 AUL :,'b..~Z1 ALE Zb57 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.O25) 1204'FNL, 1703'FEL, Sec.25, T13N, R8E, UM Kuparuk River Unit Statewide 9A,t top ~of productive interval 8. Well number Number 173 FNL 1270'FEL, Sec.30, T13N, RgE, UM 3M-5 ' #8088-26-27 At total depth 9. Approximate spud date Amount 1764'FNL, 100~'FEL, Sec.30, T13N, RgE, UM 03/15/87 $500,000 12. Distance to nearest 13. Distance t.o nearest well 14. Number of acres in property 15. Proposed depthIMD and TVD) property line ~A~-~,~ 91 55 'MD 1204'@ Surface feet 25' ~ Surface feet 2560 (6440'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure/see 2o AAC 25.035 (e)(2)) Kickoff depth600 feet Maximum hole angle 51 0 Maximum surface 2020 psig At total depth (TVD) 3156 psig 18. Casing programl Settin~ Depth size Specifications Top Bottom Ouantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 cf 12-1/4" 9-5/8" 36.0# J-55 BTC 4356' 35' 35' 4391' 3413' 1135 sx AS II I & HF-EF:W 325 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC 9121' 34' 34' 9155' 6440' 200 sx Class G(minimurr HF-EFW T0C 5 0' above top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor R. ECEIVED Surface RECE!~'/~ D Intermediate "" 1987 Production MAI::~ ,z~ Liner Alaska 0It ~, (~s C(~Rs, c0mmissi0li Perforation depth: measured Anchorage Alaska 0ii & ~as Guns. Commissl0rl true vertical Anchorage 20. Attachments Filin, g fee/~ Property plat [] BOP Sketch/)~ Piverter Sketch ~' Drilling program~- Drilling fluid pro~m,i;~Timevs depth plot [] Refraction analysis [] Seabed report [] 20AAC 25.050 requirements 21.1 hereby certify': '~ / '-'~at ~he foregoing is t,~e and correct to the best of my knowledge // 'oriel Drilling Engineer Date;~_.~/~' Signed ' /¢~,~.~¢// /~/~_~~-~'~ Title R eg, ' ' ./ ' ~'(,'/ / .... CommissionUseOnly (HARRY) PD2/012 Permit Number ..., ~_ I APl number I Approval date J See cover letter ,~¢"7 -.~.} [ 50-- ~:, ~"" -; ~ ? ¢ .~,, [ 03 / 10 / 8 7 Jfor other requirements Conditions of approval Samples required [] Yes ,~No Mud Icg require¢ ~ Yes "ij~ No Hydrogen sulfide measures [] Yes ]~ No D, irectional survey required '~,Yes [] No/ ' Required working pr~gs.s, ure for BO~ []2M.; J~ 3M; [] 5M; [] 10M; [] 15M Other: ~~/~ by order of Approved by ~,~ ~ ,,./,. t _~//'~ Comm,ssioner the commission Date Form 10-401 Rev. 12-1-85 Sub :ate iM~CO i&LASKA. ])NC. ; PAD 3~. WELL ;.~0, 5 PR.I:~POSED ..,__UP_~.~.U_K___~_[_:E__L:D..?L_.N_O_RTH S._LjO..PE,' ALASiKA ............................. -- l I ' ' t 900- f ' /'50 - i ~'I.000 i650 R -- t :550! KUPARUK RIVER UNIT 20' DIVERTER SCHEMATIC DESCRIPTION 1, 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD 3, FMC DIVERTER ASSEM§LY WITH TWO 2-1/16" 2000 PSi BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/lO" OUTLETS S. 1 O" HCR BALL VALVES W/10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINT[NANCE & OPERATION 2 i i 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS, 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALV~.E.., TO,ACHIEVE; D9~NWIND DIVERSION. ~ '"~ .! UNDER ANY CIRCUMSTANCES JG 11-3-86 7 6 il-- DIAGRAM #1 13-5/8" 5000 PSI RSRRA BOP STACK I. 16= - 2000 PSI TAI~CO STARTING FEAD 2. I1' - 3000 PSI CASING ~ 3. i1' - 3000 PSI X 13-5/8= - 5000 PSI SPACER ~ 4. 13-5/8' - 5000 PSI PIP~ ~ 5. 15-5/8" - 5000 PSI DRILLING SPOOL W/CH~ A~ KILL LII~ 6. I~r-5/B" - ~ PSI ~ R~ W/PIF~ R/~ ON TOP, 7. 1~-5,/8" - 5000 PSI AI~ ACQ.IVLJLATOR C,ApAC[T¥ TEST I. CHECK AI~ FILL ACOI~TDR RES~OIR TO PR~ ~ WITH HY~IC FLUID. ~. ~ TI~, ~ ~ ~ ~TS SIXThlY 4. ~~ ~ ~ ~T, ~ A~~ L~ LIMIT IS 45 ~~ ~I~ TI~ ~ I~ ~I ~I~ 5 4 2 15-5/8" BOP STACK TEST I. FILL BOP STAC:K AI~ ~ MAI~F~ WITH ARCTIC DIESEL. 2. CHECK THAT ALL LOCK ~ ~ IN ~ELLFEAD ARE FULLY RETRACTED. SEAT ~ PLUG IN WITH RUNqlNG JT ~ RUN IN L~ SCI~5~B. LIthE VALVES ADJACEN~ TO BOP STA(X. ALL OTHER VALVES A~D Q. IO~S 8-10JI.D BE OPEN. 4. PRE~ UP TO 250 PSI ~ HOLD FDR I OMIN. IN- ~ PRESSURE TO 30130 PSI ~ HOLD FOR I0 MIN. BLFFn PRE~ TO 0 PSI. LIllE VALVES. CLOSE TOP PIPE RAMS ~ HC~ VALVES ON KILL A~D CHCKE LI~ES. TEST TO 250 PSI ~ 30(X) PSI AS IN STEP 4. 7. C~IhIJE TESTING ALL VALVES, LI~ESo A~ Q-K2KES WITH A 2_,50 PSI LOW /~ ~)00 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSE]RE TEST ANY NOT A FULL CLOSING POSITIVE SEAL O-I~. (]q_Y ~ION TEST CHOKES THAT DO NOT FULLY CLOSE. 8. OPEN TOP PIPE RA~ ~ CLOSE BOTTO~ PIPE R/~. TEST BOTTCM PIPE R/~ TQ 250 PSI AI~ 3K)O0 PSI. 9. OPEN BOTTCM PIPE RAMS, BACK OUT RUNNING JT AN) I0. CLOSE BLIhD RAMS ~ TEST TO 250 PSI AhD 5000 PSI. I1. OPEN BLIND RAMS AAD RETRIEVE TEST PLUG. MAKE 513RE MANIFO_D ~ LI~ES ARE FULL OF NON-FREEZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAI~DPIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, AhD INSIDE BOP TO 2_50 PSI AhD ~3. RECO~ TEST I~FC~V~TZON ON acc~xrr P~-V~ TEST FO~M, SION, AND S~D TO DRILLING SU~.RVZS~. ~4. PERFO~ ~~rE aOPE TEST AFTER NIPPLING UP A~ r'~ r'~ ~'~Y ~ER FUNCTIONALLY C~W. RATE SOP[ DAILY. 510084001 REV. 2 MAY 15,1985 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drillin~ Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & 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 (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. LWK5 / ih In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic ~p~ck upon completion of the fluid disposal. ~i ,, ~, ~i,~'~ GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. I0. Run and cement 7" casing. Pressure test to 3500 psiS. 11. Dow~squeeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubins, trip in hole to plus back total depth. Circulate hole with clean brine and trip out of hole standins rubens back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE _ SHAKERS -~., DEiI~SSER ] , I'IUD CLEANER STIR ~. iI"IUD CLEANER ,, TYPICAL MUD SYSTEI"I SCHEI"IATIC L~4 / ih CHECK LIST FOR NE~ W~.L PERMITS ~ APPROVE DATE (1) Fee ~ 3-G-~? (2) Loc (3) Admin '~~- - (9 ~ 13)¢ 9. 10. (i0 and I3) . 12. 13. (4) Casg ~.~.~ ~-~-~9~ (14 ~ 22) (23 thru 28) (6) OTHER (29 ~' 31) (6) Add: 1 Is the permit fee attached - 2. Is well to be located in a defined pool ....................... Is well located proper distance from other wells ................. · Is sufficient undedicated acreage available in this pool ....... I s well to be deviated and is wellbore plat included .......... Is operator the only affected party ........................... 8. Can permit be approved before fifteen-day wait ................. Does operator have a bond in force .................................. Is a conservation order needed ...................................... ,, Is administrative approval ~needed ................................... Is the lease n,~her appropriate ......................... Does the well have a unique name ~ 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cemmnt cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............ ~ Is old wellbore abandommmt procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required .......................... - ............. Is the dz-illing fluid program schm~mtic and list of equi~t adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~o psig .. Does the choke m~n~fold comply w/API RP-53 (May 84) .................. Is the presence of ~S gas probable ................................. For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones .... " 31. If an offshore loc., are survey results of seabed conditions {~'g;~gd--/~"~ ,,, 32. Additional requirm~=nts ............................................. Geology: WWB~ rev: 01/28/87 6.011 INITIAL GEO. UNIT DN/OFF POOL CLASS STATUS AREA- NO. SHORE 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 roadability 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. LIS TAPE VERIFICATION LISTING CP OlO.H02 VERIFICATION LISTING PAGE i ~ REEL HEADER ERVICE NAME :EDIT ATE :87/04/ 1 RIGiN : EEL NAME :72232 ONTINUATION ~ :01 REViOUS REEL : OMMENTS :LIS TAPE, ARCO KUP~RUK 3M-5, API ~ 50-029-21706 ~ TAPE HEADER $$ ERViCE NAME :EOZT ATE :87/04/ 1 RIGIN :7223 APE NAME : ONTINUATiON ~ :01 REVIOUS TAPE : OMMENT$ :LIS TARE, ARCO KUPARUK 3M-5, API# 50-029-21706 ~ FILE HEADER ~ ILE NAME :EOIT .001 ERVICE NAME : ERSION ~ : ATE : AXIMUM LENGTH : 1024 iLE TYP'E : REVIOUS FILE : .'~.~ INFORMATION RECORDS ~.~ NEM CONTENTS UNIT TYPE CATE SIZE CODE mm~m mlmm mmmm N : ARCO ALASKA, iNC. 000 000 018 065 N : 3M-5 000 000 004 065 N : KUPARUK 000 000 008 065 ANG: SN 000 000 002 065 OWN: 13N 000 000 003 065 ECT: 25 000 000 002 065 OUN: NORTH SLOPE 000 000 012 065 TAT: ALASKA 000 000 006 065 TRY: USA 000 000 00~ 065 NEM CONTENTS UNIT TYPE CATE SiZE CODE RES: E 000 000 001 065 ~ COMMENTS" .... .,..,.o,..~. ,.,..,..,..,...,..,..,- ,.,: ,.,..~. ,,,. ., ........ ,..,.., .... . .... . .,. VP OIO.H02 VERIFICATION LISTING PAGE Z SCHLUMBERGER ALASKA COMPUTING CENTER OMPANY = ARCO ALASKA I~C ELL : 3M-~ IELD = KUPARUK ~UNTY = NORTH SLOPE TATE = ALASKA D8 NUMSER AT AKCC: 72232 UN #1~ DATE LDGGEO: 23-MAR-87 DP: RiCK KRUWELL ASING ASING YPE FLUID ENSITY ISCOSITY H LUIO LOSS ATRIX SANDSTONE : 16.000" @ 115' - BIT SIZE : 24" 70 115' : 9.625" @ 4351' - BIT SIZE : 12'.25" TO 4351' BIT SIZE = 8.5" TO 9110' = LSNO-POLYHER : 9.9 LB/G RM : 4.13 @ 67 DF : 37 S RMF = 3.9 @ 67 DF = 8.5 RMC = 4.Z @ 67 DF = 4.6 CS RM AT BHT = 2.011 @ 145 DF OTE: DATA OF FORMATION DENSITY AND COMPENSATED NEUTRON ARE DISCONTINUOUS OVER THESE ZONES 8260' TO 6850', 673.8' TO 490I', 4802' TO 4324' /P OiO.H02 VERIFICATION LISTING PAGE 3 THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS SCHLUMBERGER LOGS INCLUDED wi'TH THIS' MAGNETIC TAPE: DUAL INDUCTION SPHERICALLY FOCUSED LOG (OIL) DATA AVAILABLE: 8986' TO 4350' FORMATION DENS!'TY COMPENSATED LOG (FDN) DATA AVAILABLE: 8962' TD 4802' COMPENSATED NEUTRON LOG (FON) DAT~ AVAILABLE: 8947' TD ~802' GAMMA RAY IN CASING (GR,CSG) DA'TA AVAILABLE: 4348' TO 273~' DATA FORMAT RECORD ~:~ NTRY BLOCKS TYPE SIZE REPR CODE ENTRY CP OiO.H02 VERIFICATION LISTING PAG~ 4 ~TUM SPECIFICATION NEM SERVICE SERVICE ID ORDER EPT FLU LO OIL LM DiL P DIL R OIL ENS OIL R FDN ALI PON HOB PON RHO FDN RAT FDN NRA FDN PHI FDN PHI PON CNL PON CNL FDN ENS FDN R CSG ENS CSG DATA EPT P ALI NRA CNL 2 9 16 0 EPT P ALI NRA CNL 'BLOCKS - UNIT API APZ API LOG 'TYPE CLASS FT O0 000 O0 OHMM O0 220 O1 OHMM O0 120 46 OHNM O0 120 44 MV O0 010 Oi GAPi O0 310 O1 L~ 00 635 21 GAP! O0 310 O1 IN O0 280 O1 G/CB O0 350 02 G/C3 O0 356 O1 O0 420 O1 O0 000 O0 PU 00~ 890 O0 PU O0 8~0 O0 CPS O0 330 31 CPS O0 330 30 LB O0 635 21 GAPI O0 310 01 L8 O0 635 21 EPT P ALI NRA CNL 9001.5000 SFLU -22.5781 GR 1.5340 RHO6 0.0000 NPHi 0,0000 TENS ,~PT P ALI 9000.0000 SFLU -22.3438 GR 1.5840 RHO6 0.0000 NPHI 0.0000 TENS 8900.0000 SFLU -24.8594 GR 8.5781 RHOB 3.0234 NPHI 729.5000 TENS 8800.0000 SFLU -~6.8~94 GR 8.6484 RHO~3 29.8406 0.0000 -1.9844 -0.2930 2304.0000 29.8406 0.0000 -1.9844 -0.2930 3054.0000 3.0086 97.1250 2.4961 35.5469 5908.0000 4.7628 93.3125 2.4023 AP1 MOD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ILD TENS DRHO DPHI GR ILO TENS DRHC DPHI GR ILO TENS DRHO DPHI GR TENS DRH3 66 66 73 65 66 66 0 ! 60 . lin 1 0 FiLE NO. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SiZ 4 4 4 4 4 SPL REPR PROCESS CODE (OCTAL) i 68 00000000000000 1 68 00000000000000 1 68 00000000000000 t 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 i 68 00000000000000 1 68 00000000000000 1 68 00000000000000 i 68 00000000000000 1 68 00000000000000 I 68 OOOO0000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 42.5241 ILM 2304.0000 GR -6.9258 NRAT 280.8531 NCNL -999.2500 TENS 77.8693 iLM 3054.0000 GR -6.9258 NRAT 280.8531 NCNL -999.2500 TENS 3.0461 ILM 5908.0000 GR 0.0532 NRAT 9.3367 NCNL -999.2500 TENS 4.2909 iLM 5448.0000 GR 0.0552 NRAT 10.3871 0.0000 0.0000 0.0000 -999.2500 10.3871 0.0000 0.0000 0.0000 -999.2500 3.0844 97.1250 3.0879 2206.0000 -999.2500 4.3038 93.3125 3.4258 CP OlO.H02 VERIFICATION LISTING PAGE 5 ~RA 3.6699 NPHI 'NL 543.5000 TENS EPT 5700.0000 SFLU ) -42.4685 GR ~LI 8.3672 RH08 ~RA 2.9707 NPHI :NL 902,5000 'TENS EPT 8600.0000 SFLU ~ -31.7500 GR ~LI 9.0391 RHGB NRA 3.5996 NPHi :NL 498.7500 TENS EPT 8500.0000 SFLU P -29.8750 GR ~LI 8.7656 RHO~ NRA 3,888? NPHt CNL 437,5000 TENS EPT 8400.0000 SFLU P -34.1250 GR ALI 8.9766 RHFj6 NRA 4.4688 NPHI CNL 440.7500 TENS EPT 8300.0000 SFLU P -37.5000 GR ALI 8.8125 RHO5 NRA 3,4570 NPHI CNL 542.5000 TENS EPT 8200.0000 S. FLU P -28.1094 GR ALI -999.2500 RHD5 NRA -999.2500 NPHI CNL -999.2500 TENS EPT 8100.0000 SFLU P -48.0000 GR ALI -999.2500 RH05 NRA -999.2500 NPHI CNL -999.2500 TENS EPT 8000.0000 SFLU P -43.0000 GR ALi -999.2500 RH05 NRA -999.2500 NPHI CNL -999.2500 TENS EPT 7900.0000 SFLU P -52.7500 GR ALI -999.2500 RH05 41.6016 DPHi 5448.0000 GR 26.3458 ILO 66.6250 TENS 2.3872 DRHO 32.2'754 OPHI 5340,0000 G2 2.4188 ltd 112.2500 TENS 2. 359~+ DRHO 45.3613 DPHI 5160,0000 GR 1.5522 ILO 118.0000 TENS 2.3379 DRHO 46.0938 DPHI 5188.0000 GR 2.4835 iLO 105.1i50 TENS 2.4219 DRM3 46.8750 DPHI 4964.0000 GR 4.38-44 ILO 116.7500 TENS 2.5742 DRHO 44.9219 DPHI 5000.0000 GR 3.9439 ILO 234.3750 TENS -999.2500 DRHO -999.2500 DPHi -999.2500 GR 4.2661 ILO 125.3125 TENS -999.2500 DRHO -999.2500 DPHi -999.2500 GR 3.7540 ILD 117.5000 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR 3.4876 iLO 119.5825 TENS -9~9.2500 ORHS 15.0150 NCNL -999.2500 TENS 21.3~10 ILM 5340.0000 GR 0.0264 NRAT 17.1484 NCNL -999.2500 TENS 2.2296 ILM 5160.0000 GR 0.0435 NRAT 17.6219 NCNL -999.2500 TENS 1.4744 ILM 5188.0000 GR 0.0366 NRAT 18.9238 NCNL -999.2500 TENS 2.5162 ILM 4964.0000 GR 0,0049 NRAT 13.834.4 NCNL -999.2500 TENS 3.6406 ILM 5000.0000 GR 0.0684 NRAT 4.6023 NCNL -999.2500 TENS 3.2175 ILM 5160.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 3.5413 iLM 4904.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 3.7069 ILM 4840.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 3.6675 ILM 4752.0000 GR -999.2500 NR~T 1995,0000 -999.2500 22.4811 66.6250 2.8809 2682.0000 -999.2500 2.2610 112.2500 3.6621 1796.0000 -999.2500 1.5339 118.0000 3.6797 1702.0000 -999.2500 2.5351 105.1250 3.7383 1971.0000 -999.2500 3.7169 116.7500 3.6211 1876.0000 -999.2500 3.2964 -999.2500 -999.2500 -999.2500 -999.2500 3.5831 -999.2500 -999.2500 -999.2500 -999.2500 3.6886 -999.2500 -999.2500 -999.2500 -999.2500 3.6899 -999.2500 -999.2500 tP OlO.H02 VERiFiCATiCN LISTING P4GE 6 ~RA -999.2500 NPHI ;NL -999.2500 TENS EPT 7800.0000 SFLU ~ -38.0000 GR ~tI -999.2500 RHOS 4RA -999,.2500 NPHI :NL --999.2500 TENS EPT 7700.0000 SFLU ~ -40.5000 GR ~LI -999.2500 RHO~ 4RA -999.2500 NPHI :NL -999.2500 TENS EPT 7600.0000 SFLU ~ -41.5000 GR %LI -999.2500 RHO~ ~RA -999.2500 NPHI ~NL -999.2500 TENS EPT 7300.0000 SFLU ~ -46.6250 GR ~LI .-999.2500 RHOB ~RA -999.2500 NPHI CNL -999.2500 T~NS EPT 7400.0000 SFLU P -48.3750 GR ALI -999.2500 RHO$ NRA -999.2500 NPHI CNL -999.2500 TENS EPT 7300.0000 SFLU P -45.3750 GR ALI -999.2500 RHOB NRA -999.2300 NPMi CNL -999.2500 TENS EPT 7200.0000 SFLU P -~3.5000 GR ALI -999.2300 RHD~ NRA -999.2500 NPHi CNL -999.2500 TENS EPT 7100.0000 SFLU P -41.0938 GR ALI -999.2500 RH08 NRA -999.2500 NPHI CNL -999.2500 TENS EPT TO00.O000 SFLU P -39.3750 GR ALI -999.2500 RH05 -999.2500 DPHZ -999.2500 GR 4.3778 ILD 93.6250 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR 2.8337 ILD 109.5625 TENS -999.2500 DRHO -999.2500 DPHi -999.2500 G2 3.6692 ILD 90.0000 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR 4.9777 ILD 101.9375 TENS -999.2500 DRHO -999.2500 OPHi -999,2500 GR 4.6678 ILD 90.6250 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 6R 3.9896 ILD 101.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR 3.3886 ILO 110.0000 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR 3.3691 ILD 102.3125 TENS -999.2500 ORHO -999.2500 DPHi -999.2500 GR 2.8433 ILO 102.3750 TENS -9~9.2500 DRMO -999.2500 NCNL -999.2500 TENS 4.6059 ILM 4932.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 3.2315 !LM 4544.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 3.9090 ILM 4564.0000 GR -999.2500 NRAT -999.2500 NCNL -999,2500 TENS 5.0261 ILM 4644.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 4.3897 ILM 4612.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 4.4068 ILM 4404.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 3.6356 ILM 4392.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2300 TENS 3.6325 ILM 4308.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 2.9459 ILM 4224.0000 GR -999.2500 NRAT -999.2500 -999.2500 4.5834 -999.2500 -999.2500 -999.2500 -999.2500 3.2253 -999.2500 -999.2500 -999.2500 -999.2500 3.8511 -999.2500 -999.2500 -999.2500 -999.2500 4.9013 -999.2500 -999.2500 -999.2500 -999.2500 4.4522 -999.2500 -99'9.2500 -999.2500 -999.2500 4.3351 -999.2500 -999.2500 -999.2500 -999.2500 3.6209 -999.2500 -999.2500 -999.2500 -999.2500 3.6038 -999.2500 -999.2500 -999.2500 -999.2500 2.9534 -999.2500 -999.2500 IP OlO.H02 VERIFICATION LISTING ~RA -999.2500 NPHI :NL -999.2500 TENS EPT 6900.0000 SFLU ~ -35.2500 GR ~LI -999.2500 RHO~ ~RA -999.2500 NPHI ~NL -999.2500 TENS ~PT 6800.0000 SFLU ~ -41.5000 GR ~LI 9.9453 RH08 ~RA 3.3086 NPHI :NL 580.5000 'TENS 5PT 6'700.0000 SFLU ~ -31.6250 GR ~LI -999.2500 RH08 ~RA -999.2500 NPHI 2NL -999.2500 TENS EPT 6600.0000 SPLU ~ -33.3750 GR ALi -999.2500 ~RA -999.2500 NPHi SNL -999.2500 TENS EPT 6500.0000 SFLU P -35.4063 GR AL1 -999.2500 RHOB NRA -999.2500 NPHI CNL -999.2500 TENS EPT 6400,0000 SFLU P -36.0938 GR ALI -999.2500 RHO3 NRA -999,2~00 NPHI CNL -999.2500 TENS EPT 6300.0000 SFLU P -36.3438 gR ALI -999.2500 RHO~ NRA -999.2500 NPHi CNL -999.2500 TENS EPT 6200.0000 SFLU P -33.4375 GR ALI -999.2500 RHO5 NR4 -999.2500 NPHi CNL -999.2500 TENS EFT 6100.0000 SFLU P -36.3750 GR AL1 -999.2500 RH3~ -999.2500 OPHI -999.2500 GR 117.8125 T~NS -999.Z500 GR 3.~608 ILO 118.3750 TENS 2.3613 DRHO 38.1348 OPHI 3960.0000 GR Z.550T ILO i16,1250 TENS -999,2500 DRHD -999,2500 DPHI -999,2500 GR 2.2556 ILO 104.0625 TEN~ -999.2500 DRHD -999,2500 OPHI -999,2500 GR ~.5945 ILD 108,5625 TENS -999.2500 OReO -999.2500 DPHI -999.2500 GR 3.1787 ILD I00.0000 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR 3.1496 iLD 109.8125 TENS -999.2500 DRHO -999,2500 DPHI -999,2500 GR 2.6549 ILO 95.0000 TENS -999.2500 DRHO -999.2500 OPHt -9~9.2500 GR 5.5915 iLD 73.9375 T~NS -999.2500 DRHO -999.2500 NCNL -999.2500 TENS' 2.9401 ILM 4200.0000 GR -999.2500 NRAT -999,2500 NCNL -999,2500 TENS 3.4670 ILM 3960.0000 GR 0.0327 NRAT 17.5035 NCNL -999.2500 TENS 2.3977 ILM 4168.0000 GR -999.2500 NRAT -999,2500 NCNL -999.2500 TENS 2,2530 ILM 4144,0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS' 2,6652 ILM 4144.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 3.3477 ILM ~108.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 3.5020 ILM 4054,0000 GR -999.2500 NRAT -999.2500 NCNL -999.,2500 TENS 3.1051 iLM 4070.0000 GR -999.2500 NRAT -999,2500 NCNL -999.2500 TENS 5,2236 ILM 4260,0000 GR -999.2500 NRAT PAGE -999.2500 -999.2500 2.9419 -999.2500 -999.2500 -999.2500 -999.2500 3.5064 118.3750 3.3418 1921.0000 -999,2500 2.4030 -999.2500 -999.2500 -999.2500 -999.2500 2.2659 -999.2500 -999.2500 -999,2500 -999.2500 2.6896 -999.2500 -999.2500 -999.2500 -999.2500 3.2913 -999.2500 -999.2500 -999.~500 -999.2500 3.4207 -999.2500 -999.2500 -999.2500 -999.2500 2.9700 -999.2500 -999.2500 -999.2500 -999.2500 5.0580 -999.2500 -999.2500 CP OlO.H02 VERiFiCATION LISTING P~GE 8 -999.2500 NoHI -999. -999.2500 TENS .-999. ~PT 6000.0000 5FLU 3. P -36.8437 GR 96. ~LI -999.2500 RH,S~ -999. NRA -999.2500 NPHI -999. CNL -999. 2500 TENS -999. EPT 5900.0000 SFLU 3. P -38.0000 GR 94. ALI -999.2500 RHO~ -999. NRA -999.2500 NPHI -999. CNL -999.2500 TENS -999. EPT 5800.0000 SFLU 4. P -47.6250 GR 122. ALI -999.2500 RH05 -999. NRA -999.2500 NPHI -999. CNL -999.2500 TENS -999. EPT 5700.0000 SFLU Z. P -30.8437 GR 104. ALI -999.2500 RH03 -999. NRA -999. 2500 NPH:I -999. CNL -999.2500 TENS -999. EPT 5600.0000 SFLU 2. P -34.7188 GR 101. ALi -999.2500 RHD5 -999. NRA -999.2500 NPHI -999. CNL -999.2500 TENS -999. EPT 5500.0000 SFLU Z. P -25.7500 GR 89 . ALI -999.2500 RHO5 -999. NRA -999.2500 NPHi -999. CNL -999.2500 TENS -999. EPT 5400.0000 SFLU 2. P -25.2500 GR 97. ALI -999.2500 RHD~ -999. NRA -999.2500 NPHZ -999. CNL -999.2500 TENS -999. EPT 5300.0000 SFLU 2. P -26.3438 GR 98. ALI -999.2500 RHOB -999. NRA -999.2500 NPHI -999. CNL -999.2500 TENS -999. EPT 5200.0000 SFLO 2. P -28.2187 GR 106. ALi -999.2500 RH~5 -999. 2500 2500 0864 1250 2500 2500 2500 0040 &375 2500 2500 2500 5304 8125 2500 2500 2500 3358 7500 2500 2500 2500 6052 9375 2500 2500 2500 5463 8750 2500 2300 2300 8079 3750 250O 2500 2500 8351 3125 2500 2500 2500 9795 1875 250O DPHi GR iLO TENS DPHI GR ILD TENS DRHO DPHI GR ILO TENS DRHO DPHi GR iLD TENS DRHO DPH:I GR iLD TENS DRHO DPHI GR ILO TENS DRHO DPHI GR iLO TENS DRHO OPHi GR ILD TENS DRHD DPHI GR ILD TENS DRHO -999.~300 NCNL -999.2500 TENS 3.3729 !LM 3994.0000 GR -999.2500 NRAT -999.2500 NCNL -999,2500 'TENS 3.1395 ILM 3970.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 4.9081 ILM 3614.0000 GR -999.2300 NRAT -999.2500 NCNL -999.2500 TENS 2.6049 ILM 3574.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2300 TENS 3.0973 iLM 3700.0000 GR -999.2.300 NRAT -999.2500 NCNL -999.2500 TENS 2.8812 ILM 3560.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 3.3159 ILM 3410.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 3.2543 ILM 3474.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 3.4550 ILM 3334.0000 GR -999.2500 NRAT -999.2500 -999.2500 3.2761 -999.2500 -999.2500 -999.2500 -999.2500 3.0227 -999.2500 -999.2500 -999.2500 -999.2500 4.7665 -999.2500 -999.2500 -999.2500 -999.2500 2.5193 -999.2500 -999.2500 -999.2500 -999.2500 2.9297 -999.2500 -999.2500 -999.2500 -999.2500 2.7843 -999.2500 -999.2500 -999.2500 -999.2500 3.1608 -999.2500 -999.2500 -999.2500 -999.2500 3.1226 -999.2500 -999.2500 -999.2500 -999.2500 3.2852 -999.2500 -999.2500 IP 010,H02 VERiFiCATION LISTING PAGE 9 ~RA -999.2500 NPHi :NL -999.2500 TENS ~PT 5100,0000 SFLU ~ -37,7185 GR ALI -999,2500 RHO5 ~RA -999,2500 NPHI 2NL -999.2500 TENS EPT 5000.0000 SFLU ~ -33,1875 GR ~Li -999,2500 RH05 ~RA -999.2500 NPHI ~NL -999.2500 TENS EPT 4900,0000 SELU P -31,4688 GR ~LI 9,1484 RHO~ NRA 3.8770 NPHI CNL 538,5000 'TENS EPT 4800,0000 SFLU P -35.,9687 GR ALI -999,2500 RHDS NRA -999,2500 NPHI CNL -999,2500 TENS EPT 4700,0000 SFLd P -32,2500 GR ALI -999,2500 RHO~ NRA -999,2500 NPHZ CNL -999,2300 TENS EPT 4600,0000 SFLU P -31,4375 GR ALI -999,2500 RHC5 NRA -999.2500 NPHI CNL -999,2300 TENS EPT 4500,0000 SFLU P -35.6563 GR ALI -999,2300 NRA -999,2500 NPHI CNL -999.2500 TENS EPT 4400,0000 SFLU P -30,5938 GR ALi -999,2500 RHQ5 NRA -999.2500 NPHI CNL -999.2500 TENS EPT ~300.0000 SFLj P -~99.2500 GR AL! 9a9,2500 RH~'' -999,2500 DPHI -999,2500 GR 4,5374 iLD 90,8750 TENS -999,2500 DRHO -999,2500 DPHI -999.2500 GR 3,5729 ILO 96,9375 TENS -999,2500 ORHO -999,2500 DPHI -999,2500 GR 5,8664 ILO 90,6875 TENS 2,2793 DRHO 39,5508 DPHI 3254.0000 GR 4,1217 ILD 102,2500 TENS -999,2500 ORHD -999.2500 DPHi -999,2500 GR 3.2877 ILO 99.3125 TENS -999.2500 DRHD -999.2500 DPHI -999.2500 GR 2,7998 ILD 99.3125 TENS -999,2500 DRH'O -999,2500 DPHI -999,2500 GR 5.0507 iLD 106.7500 TENS -999.2500 DRHO -999.2500 OPHI -999.2500 GR 3.5~04 ILD 85.6250 TENS -999,2500 DRHO -999,2500 DPHI -999.2500 GR -999.2500 -999,2500 YENS -999,2300 DRHO -999,2500 NCNL -999,2500 TENS 4,9994 !LM 3304,0000 GR -999,2500 NRAT -999,2500 NCNL -999,2500 TENS 4,0166 ILM 3334,0000 GR -999.2500 NRAT -999.2500 NCNL -999,2500 TENS 4,9012 ILM 3254,0000 GR 0,0269 NRAT 22,4746 NCNL -999,2500 TENS 4.2590 ILM 3044.0000 GR -999,2500 NRAT -999.2500 NCNL -999.2500 TENS 3,7962 ILM 3044,0000 GR -999,2300 NRAT -999,2500 NCNL -999.2500 TENS 3,8420 ILM 3110,0000 GR -999,2500 NRAT -999,2300 NCNL -999,2500 TENS 5.7334 ILM 3010.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 4,1804 !LM Z784,0000 GR -999,2500 NRAT -999,2500 NCNL 63.7500 TENS -999,2500 iLM -999.2500 GR -999.2300 NRAT -999.2500 -999.2500 4.8070 -999.2500 -999.2500 -999.2500 -999.2500 3.8567 -999.2500 -999. 2500 -999.2500 -999.2500 4.4118 90.6875 3.3535 2088.0000 -999.2500 4.1632 -999.2500 -999.2500 -999.2500 -999.2500 3.6457 -999.2500 -999.2500 -999.2500 -999.2500 3.5892 -999.2500 -999.2500 -999.2500 -999.2500 5.4856 -999.2500 -999.2500 -999.2500 -999.2500 3.9204 -999.2500 -999.2500 -999.2500 2130.0000 -999.2500 -999.2500 -999.2500 /P OlO.H02 VERIFiCATiON LISTING ~RA -999.2500 NPHI ;NL -999.2500 TENS ~PT 4200.0000 S~LU ~ -999.2500 GR ~LI '-999.2500 RH06 ~RA -999.2500 NPHi $NL -999.2500 TENS :PT 4100.0000 SPLU P -999.2500 GR ~LI -999.2500 ~RA -999.2500 . NPHI CNL -999.2500 TENS EPT 4000.0000 SFLU P -999.2500 GR ALI -999.2500 RH~5 NRA -999.2500 NPHI CNL -999.2500 TENS EPT 3900.0000 SFLU P -999.2500 GR ALI -999.2500 RHO5 NRA -999.2500 NPHI CNL -999.2500 TENS EPT 3800.0000 SFLU P -999.2500 GR ALI -999.2500 RH06 NRA -999.2500 NPHi CNL -999,2500 TENS EPT 3700,0000 SPLU P -999.2500 GR ALI -999.2500 RH06 NRA -999.2500 NPHZ CNL -999.2500 TENS EPT 3600.0000 SFLU P -999.2500 GR ALI -999.2500 RHOB NRA -999.2500 NPHI CNL -999.2500 TENS EPT 3500.0000 SFLU P -999.2500 GR ALI -999.2500 RHG~ NRA -999.2500 NPHI CNL -999.2500 TENS EPT 3400.0000 SFLU P -999.2500 GR ALi -999.2500 -999.2500 DPHi -999.2500 GR -999.2500 !LD -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR -999,2500 ILD -999.2500 TENS -999.2500 ORHO -999.2500 DPHI -999.2500 GR -999.2500 ILD -999.2500 TENS -999.2500 DRHO -999.2500 OPHI -999.2500 GR -999.2500 ILD -999.2500 T~N$ -999.2500 ORHO -999.2500 OPHI -999.2500 GR -999.2500 ILO -999.2500 TENS -9~9.2500 DRHO -999.2500 DPHI -999.2500 GR -999.2500 ILD -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR -999.2500 ILD -999.2300 TENS -9~9.2500 DRHO -999.2500 DPHI -999.2500 GR -999.2500 ILO -999.2500 TENS -999.2500 ORHO -999.2500 DPH~ -999.2500 GR -999.2500 ILD -999.2500 TENS -999.2500 DRHO -999.2500 NCNL 56.1250 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 55.0000 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 52.1250 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 57.2500 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 47.5000 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 44.1250 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 50.0313 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 54.2500 TENS -999.2500 -999.2500 GR -999.2500 NRAT -999.2500 NCNL 64.0000 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT PAGE 10 -999.2500 2870.0000 -999.2500 -999.2500 -999.2500 -999.2500 2790.0000 -999.2500 -'999.2500 -999 · 25 O0 -999.2500 2710.0000 -999.2500 -999.2500 -999.2500 -999.2500 2620.0000 -999.2500 -999.2500 -999.2500 -999.2500 2604.0000 -999.2500 -999.2500 -999.2500 -999.2500 2644.0000 -999.2500 -999.2500 -999.2500 -999.2500 2590.0000 -999.2500 -999.2500 -999.2500 -999.2500 2560.0000 -999.2500 -999.2500 -999.2500 -999.2500 2484.0000 -999.2500 -999.2500 -999.2500 IP OlO,H02 VERIFICATION LISTING PAGE ~RA -999.2500 NPHi 'NL -999,2500 TENS EPT 3300,0000 SFLU ~ -999,2500 ~LI -999,2500 ~RA -999.2500 NPHI 2NL -999,2.500 TENS EPT 3200.0000 SFLU P -999,2500 GR ALI -999.2500 RH06 NRA -999,2500 NPHi CNL -999.2500 TENS EPT 3100,0000 SFLU P -999,2500 GR ALI -999.2500 RHO6 NRA -999,250'0 NPHi CNL -999.2500 TENS EPT 3000.0000 SFLU P -999,2500 GR ALI -999,2500 RHO6 NRA -999,2500 NPHI CNL -999,2500 TENS EPT 2900.0000 SFLU P -999,2500 GR ALI -999.2500 RH06 NRA -999.2500 NPHi CNL -999,2500 'TENS EPT 2800.0000 SFLU P -999.2500 GR ALI -999,2500 RHOB NRA -999,2500 NPHi CNL -999,2500 TENS EPT 2731.5000 SFLU P -999,2500 GR ALI -999.2500 RH05 NRA -999.2500 NPHI CNL -999,2500 TENS -999.2500 OPHI -999,2500 GR -999.2500 ILO -999.2500 TENS -999.2500 -999.2500 DPHi -999.2500 GR -999.2500 ILO -999,2500 TENS -999,2500 ORHO -999,2500 OPHI -999.2500 GR -999.2500 ILO -999,2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR -999,2500 ILO -999,2500 TENS -999,2500 DRHO -999,2500 DPHI -999.2500 GR -999.2500 ILD -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999,2500 GR -999.2500 iLO -999,2500 TENS -9~9,2500 DRHO -999,2500 DPHI -99~,2500 GR -999.2500 ILO -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999,2500 GR * FILE TRAIL:R ~'~' ILE NAME :EOIT .001 ERVICE NAME : ERSION m : ATE : AXiMUM LENGTH : 1024 ILE TYP~ : EXT FILE NAME : -9'99,2500 NCNL 39.0625 TENS' -999.2500 ILM -999,2500 GR -999.2500 NRAT -999,2500 NCNL 42.4063 TENS -999,2500 iLM -999,2500 GR -999,2500 NRAT -999,2500 NCNL ~8.9~75 TENS -999,2500 ILM -999,2500 GR -999.2500 NR~T -999.2500 NCNL 18,2500 TENS -999,2500 ILM -999,2500 GR -999,2500 NRAT -999,2500 NCNL 25.4063 TENS -999,2500 ILM -999,2500 GR -999.2500 NRAT -999.2500 NCNL 45.4375 TENS -999,2500 ILM -999,2500 GR -999,2500 NRAT -999,2500 NCNL 32.5313 TENS -999,2500 ILM -999,2500 GR -999.2500 NRAT -999.2500 NCNL 36.0625 TENS -999.2500 2424.0000 -999..2500 .-999,2500 -999.2500 -999,2500 2420,0000 -999,2500 -999,2500 -999,2500 -999,2500 2370,0000 -999,2500 -999,2500 -999,2500 -999,2500 Z224,0000 -999.2500 -999.2500 -999.2500 -999.2500. 2254,0000 -999.2500 -999.2500 -999.2500 -999.2500 2270.0000 -999.2500 -999.2500 -999.2500 -999.2500 2250.0000 -999.2500 -999.2500 -999.2500 -999.2500 2080,0000 ~P OlO.H02 VERIFICATION LISTING PAGE I2 TAPE TRAILER ERVICE NAME :EDIT ITE :87/04/ ~, iGI N :7223 kPE NAME : }NTINUATI@N ~ :01 ~XT TAPE NAME : )MMENTS :LIS TAPE~ ARCO KUPARUK 3M-S~ APi# 50-029-21706 ',~ REEL TRAILER ..... ~RVICE NAME :EDIT ~TE :87/04/ 1 ~ IGiN : ~EL NAME :72232 DNTINUATIDN # :O1 =XT REEL NAME : DMMENTS :LIS TAPE~ ARCO KUPARUK 3M-5~ API# 50-029-21705